ML101590080
| ML101590080 | |
| Person / Time | |
|---|---|
| Site: | Brunswick  |
| Issue date: | 05/03/2010 |
| From: | NRC/RGN-II |
| To: | Progress Energy Carolinas |
| References | |
| 50-324/10-301, 50-325/10-301 | |
| Download: ML101590080 (199) | |
Text
PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION SIMULATOR SCENARIO 2010-1 NRC Exam Scenario #1
Appendix D D Scenario Outline Form ES-D-1 Facility: Brunswick Scenario No.: 2010-1 #1 Op-Test No.: Draft Examiners: Operators:
Initial Conditions: Plant is operating max power MOC. PT-02.3.1A is in progress with the one hour wait complete. Torus-DW Vacuum Breaker D indication unavailable. RHR SW Pump 2A is under clearance.
Turnover: Complete PT-02.3.1A.
Event MaIf. No.
Malf. Event Event No. Type*
Type* Description 1
1 N-BOP PT-02.3.1AAlternate Vacuum Breaker Testing PT-02.3.1A - Alternate method N-SRO 2 ESO22F ES022F I-RO Inadvertent RCIC initiation (TS)
ISRO I-SRO 3 EEO43F EE043F R-RO Switchyard Line trip requiring Power reduction R-SRO 4 K4521A C-BOP RBCCW pump trip with failure of standby to auto start Off C-SRO 5
5 ESOI3F ES013F C-RO Blown HPCI logic fuse (TS)
C-SRO 6 EEO2OF EE020F C-RO SAT trip; manual scram fails requiring ARI C-SRO 6 DGOO5F DG005F 1-BOP I-BOP DG 4 failures (Cont)
(Con't) I-SRO 7 NBOO9F NB009F M-AlI M-AII Small break LOCA 7 ESO44F ES044F
, ESO45F ES045F CRO C-RO LP ECCS initiation logic failure (Con t)
(Con't) ESO46F ES046F C-SRO 8 NA Emergency depressurization
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Page 2 of 34 Page2of34
SCENARIO DESCRIPTION The plant is operating at maximum power, Middle of Cycle.
I Event 1 RHR SW Pump 2A is under clearance. Suppression Chamber to Drywell Vacuum Breaker D D indication is unavailable. PT-02.3.1A, Vacuum Breaker Position Check Alternate Method is in progress. The one hour wait is complete. The crew will complete PT-02.3.1A.
Event 2 RCIC will inadvertently initiate. The crew should respond per OAOP-03.0 and trip RCIC.
Event 3 3 230 kV Line 30 will trip. The Load Dispatcher will request power be reduced to <800 MWe. Power must be reduced using ENP-24.5.
Event 4 The B RBCCW pump will trip with the standby pump failing to auto start. OAOP-16.0 should be entered and the standby pump started to recover system pressure.
Event 5 5 The HPCI logic power fuse will blow requiring HPCI AOP to be secured per the APP and declared Inoperable. With RCIC also Inoperable, Tech Specs requires a a plant shutdown.
Event 6 The SAT will trip resulting in loss of Recirculation Pumps requiring a manual scram.
Manual scram push button B B will fail. Rods can be inserted using ARI. Off-site power is lost when the turbine trips. Diesel Generator #3 will start, tie to E3, then trip on over current. Diesel Generator #4 will fail to auto start and tie, but can be manually auto started and manually tied to energize E4. The crew will wiN respond per AOP-36.1 and EOP-01-RSP.
EOP-01 -RSP. Bus E3 cannot be cross-tied due to the electrical fault, but 480V E7 can be cross-tied to E8. SRVs will be available for pressure control. RCIC can be restarted with an initiation signal following trip to provide inventory makeup to the RPV. CRD flow can be maximized (1 pump) and SLC can be aligned for demin water injection (1 pump until E7 is cross-tied, then both).
Event 7 A small Recirculation line break will occur. Available injection sources will be unable to stabilize RPV level. RPV level will drop to LL3 resulting in actuation of ADS timers.
The crew may allow ADS to automatically initiate, or manually initiate ADS when level drops below TAF. Low pressure ECCS initiation logic will fail at LL3 requiring manual actions to start available pumps and align injection when RPV pressure drops below 400 psig.
Event 8 8 When the RPV has been depressurized and RPV level restored to the normal band, the scenario may be terminated.
Page Page3of343 of 34
OBJECTIVES SRO 344205B402, Direct Direct Shift Response To A Moderator Temperature Decrease Decrease Per Per AOP-AOP 03.0 344237B402, Direct Actions For A Loss of Any 4KV Buses Per AOP-36.1 AOP-36. 1 344231 B502, Direct Actions For A Reactor Scram With MSIVs Closed And Reactor Power Less Than 4% Per EOP-01-RSP 344217B502, Direct Actions To Control RPV Level Per EOP-01-RVCP 344218B502, Direct Actions To Control Reactor Pressure Per EOP-01-RVCP 344220B502, Direct Actions To Emergency Depressurize The RPV Per EOP-01-RVCP 3442 14B502, Direct Actions To Control Primary Containment Pressure Per EOP 344214B502, PCCP 344215B502, Direct Actions To Control Primary Containment Temperature Per EOP PCCP 344216B502, Direct Actions To Control Suppression Pool Temperature Per EOP PCCP RD RO 202202B101, 202202B 101, Decrease Reactor Recirculation Pump Speed/Reactor Power Using The Manual Control Station Per OP-02 21 7200B401, Restart The RCIC System After Auto Initiation And Turbine Trip Per OP-217200B401, OP 16 217204B401, Shutdown The RCIC System with an Automatic Initiation signal present Per OP-16 262002B401, Respond To A Loss Of Off-Site Power Per AOP-36.1 262007B401, Crosstie Emergency 480 VAC Buses Per AOP-36.1 264009B401, Manually Start A DG With An Auto Start Signal Present With A Failure Of The DC DG To Start 209007B501, Manually Operate Core Spray To Maintain Reactor Water Level 203006B501, Manually Operate LPCI To Control Reactor Water Level 200049B501, Spray The Drywell Per EOP-0 1-SEP-02 EOP-01-SEP-02 200062B501, 200062B501, Spray The Suppression Pool Per EOP-01-SEP-03 205014B101, 205014B1 01, Start Start Up Up RHR InIn Suppression Pool Cooling Mode Per OP-17 Page Page 44 of of 34 34
SIMULATOR SETUP Initial Conditions IC-13 E ven tT*
Event Triggers nggers Event Trigger Description 0 Normal Ops (Vacuum Breaker PT) 11 Manually Initiated (Inadvertent RCIC Initiation) 2 Manually Initiated (230 kV Line Trip) 3 Manually Initiated (2B RCC Pump Trip) 4 Manually Initiated (HPCI Bus A Logic Fails) 5 Manually Initiated (SAT Trip) 6 Manually Initiated (Small Break LOCA) 7 DGOO5F)(K4G14AB8)
Auto Initiated (DG4 Auto Mode Start Depressed, deletes DG005F)(K4G14ABS) 8 S Trip)(Q4226UR8)
Auto Initiated (DG3 to E3 Breaker Red=True, activates DG# Trip)(Q4226URS)
Malfunctions Event Sys Tag Title Value Activate Deactivate (Ramp) Time Time A DG DGOO5F DG005F DG4 Auto Start Fail NA o0 SEC NA A ES ESO44F ES044F Core Spray B B Auto Start Fail NA 0 SEC OSEC NA A ES ESO45F ES045F RHR A Auto Start Fail NA 0 SEC OSEC NA A ES E5046F ES046F RHR B Auto Start Fail NA 0 SEC OSEC NA El E1 ES ESO22F ES022F Inadvertent RCIC Start NA 0o SEC NA E2 EE EEO43F EE043F 230 kV Line 30 Trip NA 0OSEC SEC NA E4 ES ESOI5F ES015F HPCI PowerSupply Power Supply Failure NA OSEC NA E5 EE EEO2OF EE020F SAT Relay Failure NA 0OSEC SEC NA E6 NB NBOO9F NB009F Small Recirc Line Rupture 10%
10% 0o SEC NA 5 MIN 5
E8 ES DG DGO26F DG026F DG3 Differential Fault NA 55 SEC NA Page 55 of 34
Switch Event Panel Tag Title Value Activate Deactivate A XU-2 K2503A Rx Manual Scram BB OFF 0o SEC NA A XU2 K4522A RBCCW Pump C Auto Off 0o Sec NA E3 XU2 K4521A RBCCW Pump B B Off On 0o Sec NA Lamps Lamps Event Panel Tag Title Value Activate Deactivate (Ramp) Time Time A XU-2 Q4B212R4 NSW Pump B B On Red ON 33 XU2 Q4521 Q4521LG4LG4 RBCCW Pump B B Off G Off A P601 Q1D23SWN RHRAInitSig RHR A Init Sig White OFF A P601 Q1J39SWN RHR 2 Init Sig White OFF A XU-2 Q48O4DGP Q4S04DGP SP-DW Vac Bkr D D Grn Gm OFF A XU-2 Q4S04URP Q48O4URP SP-DW Vac Bkr D D Red OFF A P601 Q1C22SWL Init Sig Seal In -White White OFF A P601 Q1J32SWL mit Sig Seal In -White Init White OFF Remote Functions Event System Tag Title Status Act/Ramp Act.lRamp A ED IABKCFI5 IABKCF15 DC Control Fuses RHR SW 2A OUT A ED IABKCFI3 IABKCF13 DC Control Fuses NSWNSW2B 2B OUT 10 CA IABSGO2A IABSG02A RB Purge Fan 2A Bkr In 11 RD RDVFO34 RDVF034 Charging Water Isol Valve F034 1.0 Over 5 sec 12 SW VHSW146L CSW to RBCCW Hxs V146 Open 13 ED ZIEDHO8 ZIEDHOS Pnl 2AB to Alternate Alt 1 mm 1 min 13 ED ZIEDHXO PnI 32AB to Alternate Pnl Alt mm 2 min 13 ED ZIEDH11 PnI 2AB-RX to Alternate Pnl Alt mm 3 min 14 RP IAEPAMGA RPS MG Set AEPA Bkrs Set 14 RP IARPSA Restart RPS MG Set A Reset 5 sec.
15 ED IARKA1O IARKA10 E8-E7 A X-Tie Bkr ES-E7 AlO 10 In mm 2.5 min 15 ED IARKAX5 E7-E8 AX5 X-Tie Bkr E7-ES In mm 5 min 16 EP IACS993P DW Clr ND A/D Override Stop 16 EP IACS994P DW Clr B/C Override Stop Page6of34 Page 6 of 34
SPECIAL INSTRUCTIONS Ensure simulator exam security measures in place.
OPT-02.3.IA as necessary to increase drywell pressure to between Perform actions of OPT-02.3.1A 1 .0 psig using nitrogen injection with the suppression chamber being vented.
0.5 and 1.0
(@ 60 0PT-02.3.1A to last drywell pressure check (@
Secure nitrogen injection and mark up OPT-02.3.1A minutes).
Ensure CAC 4409/4410 in service.
Advance all chart recorders to indicate steady state conditions.
Place all SPDS displays to the Critical Plant Variable display (#100).
Ensure appropriate keys have blanks in switches.
Exit shutdown screen on RWM and place the RWM key in the key locker.
Reset alarms on SJAE, MSL, and RWM NUMACs.
Ensure reference material is in appropriate location.
Verify any log books have blank sheets only and procedures are not marked.
Load scenario file if available.
Load malfunctions/overrides if scenario file is unavailable.
mfd:dgOO5f (if scenario file is unavailable)
In command line type trc:7, mfd:dg005f Place red cap on RHR SW Pump A.
Verify U2CO_C099, Avg Hotwell Temp <115°F, or start the third condensate pump.
lC-13 @
Ensure OENP-24.5 for IC-13 @ P603.
Page7of34 Page 7 of 34
SHIFT BRIEFING Plant Status The plant is operating at maximum power, Middle of Cycle.
Equipment Out of Service RHR SW Pump 2A is under clearance for breaker repair and is expected to be returned to service in two hours.
Suppression Chamber to Drywell Vacuum Breaker D position indication is unavailable.
OPT-02.3.IA, Suppression Chamber To Drywell Vacuum Breaker Position Check OPT-02.3.1A, Alternate Method, is in progress to comply with LCO 3.6.1.6.
CAC-Pl2685-1 (XU-51) is being used to monitor drywell pressure.
CAC-PI-2685-1 No other equipment is out of service Plan of the Day Maintain maximum power.
OPT-02.3.IA is complete up to the last pressure reading at the 60 minute time period.
OPT-02.3.1A When shift turnover is complete, take the final drywell pressure reading and complete OPT-02.3.1A.
Page8of34 Page 8 of 34
TRAINING INFORMATION SCENARIO TRAINING INFORMATION Instructor Notes Instructor Notes designed to meet the requirements of an examination scenario for Initial This guide is designed License as outlined in NUREG-1 021, 021, Rev.9, Supp.1 ES-301 and Appendix D.
During the execution of this scenario, the students should be rated on the performance of the objectives, compliance with general simulator performance standards, and for overall team skills in accordance with TAP-409 and NUREG-1021, ES-302.
Common Student Problems/Errors None Simulator Deficiencies There are no known simulator deficiencies applicable to this scenario.
Critical Tasks (Critical Tasks are identified to ensure scenario validity and do not constitute pass/fail criteria for Initial License.)
- Insert control rods
- Manually start and tie Diesel generator #4
- Restore and maintain RPV level above LL4.
Page 99 of Page of 34
EVENT 1 1 VACUUM BREAKER TEST The crew will complete shift turnover and perform OPT-02.3.1A.
Objectives:
SCO - Directs performance of OPT-02.3.1A to be completed.
RO - Completes OPT-02.3.1A.
Success Path:
Drywell pressure remains constant indicating all vacuum breakers closed.
Simulator Operator Actions:
D l&C, spare limit switches for vacuum breaker D D If asked as I&C, D are unavailable.
D When requested, initiate Trigger 10 to turn Purge Fan A breaker ON.
D D When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Normal Ops - Perform Vacuum Breaker OPT-02.3.1A.
SRO Time Action Notes Direct PT-02.3.1A to be completed.
Determine acceptance criteria is met May direct venting of the DW after 20-10) completion of the PT. (lAW 20P-1 0)
RO Time Action Notes Plant Monitor May be asked to perform IV for steps in OPT-02.3.1A.
Page 10 of 34 100f34
(Contd) VACUUM BREAKER TEST I (Cont'd)
EVENT 1 BOP Time Action Notes 0PT-02.3.1A Complete OPT-02.3.1A Records the 60 minute interval reading (Step 7.9.7)
Record final pressure reading Compute ratio (Final reading divided by Initial reading)
Compare ratio obtained in Step 7.10.2 to 0.5 and check ratio greater than 0.5 space Close TORUS PURGE EXH VL VLV, V, CAC-CAC V8 VB Close TORUS PURGE EXH VL VLV, CAC V, CAC-V7 Momentarily place control switches for both Purge Exhaust Fans in OFF Dispatch ACAO to confirm Purge Exhaust Fan A(B) M-BF V-RB (K-A(8) Suction Valve, M-BFV-RB (K BFV-RB), indicates closed at MCC Dispatch ACAO to confirm Purge Exhaust Fan A(B)
A(8) Discharge Valve, J-BF V-RB J-BFV-RB (L-BFV-RB), indicates closed at MCC Ensure breaker for the following Purge Exhaust Fan is closed:
A PURGE EXHAUSTFAN EXHAUST FAN Close PURGE EXHAUST FANS SUCTION VAL VE, I-BF VALVE, V-RB
/-BFV-RB 11 of 34 Page 11
EVENT 1I (Cont'd)
(Contd) VACUUM BREAKER TEST contd BOP cont'd Close PURGE EXHAUST FANS INBOARD EXHAUST HEADER ISOLATION VALVE, N-BFV-RB Close PURGE EXHAUST FANS OUTBOARD EXHAUST HEADER ISOLATION ISOLA TlON VALVE, A-BFV-RB Open SBGT TRAIN A REACTOR BUILDING SUCTION VALVE, VA-D- VA-D BFV-RB Open SBGT TRAIN B REACTOR BUILDING SUCTION VALVE, VA-H- VA-H BFV-RB Ensure the suppression pool oxygen concentration is less than 4% oxygen Ensure the required information has been recorded on the cover page Notifies the Unit SCO when this test is complete SAT Page 1212 of 34
EVENT 22 EVENT INADVERTENT RCIC INADVERTENT RCIC INITIATION INITIATION The crew The crew will will respond to an inadvertent to an inadvertent RCIC RCIC initiation.
initiation.
Objectives:
SCO - Direct shift response to aa moderator temperature decrease.
5CC -
Shutdown the RCIC system with an automatic initiation signal present.
RO - Shutdown Success Path:
RCIC RC IC shutdown and Technical Specifications reviewed.
Simulator Operator Actions:
o When the directed by the lead examiner, initiate Trigger I1 to inadvertently start L
RCIC.
o If RCIC has been running for >5 minutes, and crew has not recognized RCIC L
running, call control room as AC AO and ask why RCIC is running.
o If asked as l&C LI I&C to investigate, acknowledge the request o If asked as NE to monitor thermal limits, acknowledge the request.
El o If asked as chemistry for Rx Coolant Sample, acknowledge the request.
LI o When directed by the lead examiner, proceed to the next event.
LI Required Operator Actions Tech Specs - 3.5.3 RCIC System Condition A Verify HPCI is OPERABLE and restore RCIC to OPERABLE status within 14 days.
SRO Time Action Notes Direct entry into OAOP-03.0.
OAOP-03.O.
Direct RCIC operation to be terminated.
May contact NE to monitor thermal limits due to the cold water injection from RCIC.
Contact I&C l&C to investigate RCIC logic.
Tech Spec 3.5.3 RCIC System Determine Condition A applies Required Action A.1, Al, Immediately verify HPCI is OPERABLE Required Action A.2, Restore RCIC to OPERABLE within 14 days Page 13 Page of 34 13 of 34
EVENT 2 (Cont'd)
(Contd) INADVERTENT RCIC INITIATION RO Time Action Notes Recognize and report RCIC injection OAOP-03.O Enter and announce OAOP-03.0 Verify inadvertent initiation by two independent indications and trip RCIC.
Depress TURBINE TRIP, E51-S17, push button to trip the RCIC turbine Monitor reactor power and thermal limits.
A-03 3-5, RCIC TURBINE STM LINE DRN POT LEVEL HI will annunciate requiring the operator to perform the following if it has been in for 5 minutes:
Close TURBINE TRIP & THROTTLE VL4 E51-V8, motor operator.
VLV, BOP I Time I Action Time Action Plant Monitor Notes I Notes Page 14 of 34
EVENT 3 SWITCHYARD TRANSMISSION LINE 30 TRIP The crew will respond to a trip of Transmission Line 30 and reduce power to less than 800 MWe as directed by the Load Dispatcher.
Objectives:
seo SCO - Direct power reduction in accordance with ENP-24.5 to 800 MWe using recirc.
RO - Decrease reactor recirculation pump speed/reactor power.
Success Path:
Power is reduced to less than 800 MWe.
Simulator Operator Actions:
LI When the directed by the lead examiner, initiate Trigger 2 to trip transmission line D
30.
LI If asked as Outside AD, D AO, acknowledge request to investigate switchyard alarms.
LI If asked as TB AD, D AO, inform crew that the PSS system is in service.
Li If asked as the Load Dispatcher, inform the crew that there is a problem on the D
line and that Unit 2 should be reduced to 800 MWe (Net). Auto reclosures for Line 30 are to be placed in Manual. No estimate at this time of the duration of the down power.
LI If contacted as the RE for power reduction guidance, inform crew to use ENP-24.5 D
guidance.
LI If contacted as the RE to monitor power reduction, inform crew that you will D
monitor core performance on the computer.
D LI If contacted as the RE for guidance on operation above the MELL line, inform crew to take the appropriate actions per ENP-24.5 to get below or on the MELLL.
D LI When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity - Reduces reactor recirculation pump speeds to reduce to power less than 800 MWe.
SRO Time Action Notes Notify Load Dispatcher of transmission line failure.
Direct power reduction to <800 MWe.
BOP Time Action Notes Plant Monitor May request Outside AC AO to investigate alarms in the switchyard.
Page 15 of 34
(Contd) SWITCHYARD TRANSMISSION LINE 30 TRIP EVENT 3 (Cont'd)
RO Time Action Notes Perform power reduction using reactor recirculation pump speed controller to less than 800 MWe.
May reference 20P-02 section 7.1 Request peer checker /I reactivity team.
Reduces power using ENP-24.5 using recirculation flow to 800 MWe.
Reduce flow on one RR Pump (2%) at a time to stay within
(-2%)
(3.5x1 066 Mlbs mismatch criteria (3.5x10 MIbs jet pump flow).
Continues alternating Recirc pump reductions until 800 MWe.
Verifies operation on the Power to Flow map.
Recognizes operation above the MELLL line and informs SCO.
Inserts control rods using ENP-24.5 to get below the MELLL line.
Turns control rod power on.
Selects control rod (22-19) in accordance with ENP-24.5 sheet.
May also insert 30-35, 30-19, or 22-35. (in this order 30-35,30-19, in order to establish aa margin to the MELLL line)
Continuously drives selected rod in using RMCS.
Page Page 1616 of 34
EVENT 4 RBCCW PUMP TRIP The crew will respond to a trip of the 2B RCC pump and pressure will lower. C RCC Pump will fail to auto start and the low pressure alarm will be received. Starting the 2C RCC pump will restore pressure to normal.
Objectives:
5CC - Directs BOP to enter and execute OAOP-16.0:
SCO OAOP-16.O: RBCCW System Failure OAOP-16.O to respond to the 2C Pump failure to start BOP - Refers to 2-UA-3 2-5 and OAOP-16.0 Success Path:
Starting the 2C RCC pump will restore pressure to normal.
Simulator Operator Actions:
LI At the discretion of the lead evaluator, initiate Trigger 3 to trip the 2B RCC D
Pump.
LI If directed as the RB AO D AC to investigate RCC low pressure, report RCC Pump 2B Motor is hot to the touch, breaker is tripped.
LI If contacted as the RB AO, D AC, inform the control room prestart checks of the 2C RCC pump are complete.
D l&C acknowledge the request.
LI If directed to investigate as I&C LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Component failure - starting 2C RCC pump.
SRO Time Action Notes Directs BOP operator to enter Annunciator response for 2-UA-3 2-5, RBCCW PUMP DISCH HEADER PRESS LOW, and refers to OAOP-16.0.
OAOP-16.O.
Directs start of 2C RBCCW pump.
Directs Maintenance to investigate 2C RBCCW pump auto start failure.
Notifies Maintenance of 2B RBCCW Pump trip.
Page 17 17 of 34
(Contd) RBCCW PUMP TRIP EVENT 4 (Cont'd)
RO Time Action Notes I Time IAction Plant Monitoring I Notes BOP Time Action Notes Manually starts 2C RBCCW Pump.
Refers to Annunciator Response UA-3 2-5, RBCCW PUMP DISCH HEADER PRESS LOW.
OAOP-16.O May Reference OAOP-16.0 Dispatches AC AO to investigate cause of 2B Pump trip.
Places 2B RBCCW Pump switch to OFF.
Verifies RBCCW System is operating normally.
Page 18 of 34
EVENT 5 HPCI POWER SUPPLY FUSE The crew will respond to a HPCI power supply fuse blowing which will require HPCI AOP to be secured per the APP and declared Inoperable. With RCIC also Inoperable, Tech Specs will require a plant shutdown.
Objectives:
SCO - Determines HPCI TS call.
Success Path:
Securing of HPCI AOP and TS 3.5.1 declaration.
Simulator Operator Actions:
LI When directed by the lead evaluator, initiate Trigger 4 to activate HPCI power D
supply failure.
AC to investigate, report all circuit breakers in DC Panel 4A are LI If asked as AO D
closed.
LI If asked as I&C to investigate, report fuse E41-F25 in panel P601 is blown D
(blows again if replaced).
LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Tech Specs - 3.5.1 ECCS Operating Condition D D Verify RCIC is OPERABLE and restore HPCI to OPERABLE status within 14 days Condition II Be in Mode 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and reduce reactor steam dome pressure to <150 psig within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br />.
Page 19 of 34
(Contd) HPCI POWER SUPPLY FUSE EVENT 5 (Cont'd)
SRO Time Action Notes Direct actions of 2APP-A-01 (2-5) HPGI HPCI FIC POWER LOSS.
FIG pull-to Direct HPCI AOP to be placed in pull-to-HPCI FIG lock per A-01 2-5, HPGI FIC POWER LOSS.
Contact I&Cl&C to investigate HPCI power supply failure.
Tech Spec 3.5.1 ECCS Operating Determine Condition 0 D applies Acflon D.l, Immediately Required Action 0.1, verify RCIC is OPERABLE D.2, Restore HPCI to Required Action 0.2, OPERABLE within 14 days.
Determine condition II applies, Be in Mode 3 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and reduce reactor steam dome pressure to <150 psig within 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> BOP ITime Time Action I Action Plant Monitoring Notes I Notes RO Time Action Notes Diagnose and report HPCI power supply failure Perform actions for A-01 2-5, HPCI FIC HPGI FIG POWER LOSS Place HPCI AOP in pull-to-lock.
pull-to-Iock.
Page 2020 of 34
EVENT 6 LOSS OF SA SATISCRAM TlSCRAM The SAT will trip resulting in loss of Recirculation Pumps requiring a manual scram. This will start all DGs except DG4. Manual scram push button B will fail. Rods can be inserted using ARI. Off-site power is lost when the turbine trips. Diesel Generator #3 will tie to E3, then trip on over current. Diesel Generator #4 will fail to auto start and tie, but can be manually auto started (control room manual mode) and manually tied to energize E4. The crew will respond per AOP-36.1 and EOP-01-RSP. SRVs SRV5 will be available for pressure control. RCIC can be restarted with an initiation signal following trip to provide inventory makeup to the RPV. CRD flow can be maximized (1 pump) and SLC can be aligned for demin water injection (1 pump until E7 is cross-tied, then both).
Objectives:
SCO - Directs actions for a Reactor Scram, LPC, and OAOP-36.1.
RO - Insert a reactor scram with no recirc pumps running.
BOP - Start DG4, tie to E4 and perform OAOP-36.1 actions.
Success Path:
Start and tie DG4 to E4. Rods inserted with ARI.
Simulator Operator Actions:
oLI When directed by the lead evaluator, initiate Trigger 5 to activate SAT failure.
oLI If contacted as load dispatcher, report line crews are being dispatched to investigate.
oLI If asked as Outside AO, acknowledge request to monitor DGs.
oLI If asked to perform actions to maximize CRD flow with 11 pump per SEP-09, wait 4 minutes and report the actions complete.
o If requested to open CRD charging header isolation valve, initiate Trigger 11, LI wait 2 minutes and report actions complete.
oLI If asked as Unit 11 for status of the air system, report 11 D is carrying the load.
oLI If asked to transfer RCC to CSW, initiate Trigger 12, wait 55 minutes and report actions complete.
o If requested to transfer 2AB, 32AB and 2AB-RX, initiate Trigger 13 and after 33 LI minutes report transfers complete (each one will sequence on every 1 1 minute).
o If asked to restart RPS, initiate Trigger 14, LI 14, wait 33 minutes and report actions complete.
oLI If requested to perform field actions for UAT back-feed, acknowledge the request.
LIo When directed by the lead examiner, proceed to the next event.
Required Operator Actions Insert control rods.
Start DG4 and tie to E4.
Page 21 of 34
(Contd) LOSS OF SAT I SCRAM EVENT 6 (Cont'd)
SRO Time Action Notes Direct insertion of manual scram due to loss of the recirc pumps.
Enter and direct EOP-01-RSP.
May enter LPC.
AR!.
May direct Initiation of ARI.
Direct entry into OAOP-36.1 for loss of E31E7 Off-Site Power and loss of E3/E7 Directs a pressure band of 800-1000#
Direct reactor water level band of 170-200 inches.
CRD (SEP-09)
RCIC When suppression pool temperature reaches 95°F or DW temperature reaches 150°F, enter EOP-02-PCCP.
Direct RHR Loop B to be placed in suppression pool cooling.
Page 22 of 34
(Contd) LOSS OF SAT I SCRAM EVENT 6 (Cont'd)
RO Time Action Notes Recognize failure of manual scram channel B Initiates AR!
Perform immediate actions for Reactor scram After steam flow is less than 3 x 1 66 x 10 lb/hr, place the reactor mode switch to Ib/hr, shutdown When APRM downscale trip, then Trip the main turbine Ensure the master reactor level controller setpoint is +170 inches Operate SRVs as directed to stabilize pressure and control pressure as directed by the SCO.
Start RCIC following turbine trip with initiation signal per the OP.
Ensure the E51-V8 (valve position) and E51-V8 (motor operator) are closed Place RCIC flow control in MANUAL (m) and adjust output to 0%.
Jog open E51-V8 until the turbine speed is controlled by the governor Fully open E51-V8 Slowly increase turbine speed until flow rate of at least 120 gpm Ensure E51-F019 is closed with flow above 80 gpm Page 23 of 34
EVENT 6 (Cont'd)
(Contd) LOSS OF SAT I SCRAM (Contd)
RO (Cont'd)
Slowly adjust flow rate using RCIC flow control in Auto (A)
Ensure Barometric Cndsr Vacuum Pump has started Start CRD per SEP-09 (RO should perform Hard Card then dispatch an AO AC for procedure actions.
SEP-09 Hard Card Actions Ensure CRD Flow Control, C12-FC-R600, in MAN Close in-service Flow Control Vlv, Cl 2-FOO2A(FOO2B)
C12-F002A(F002B)
Start a CRD pump.
Throttle the following valves to maintain charging water header pressure greater than or equal to 1000 psig but as low as possible:
- In-service Flow Control Vlv, C12-012-FOO2A(F002B)
F002A(F002B)
- Drive Pressure Vlv, C12-PCV-F003 SEP-09 Procedure Actions AC to perform SEP-09 for Dispatch AO one CRD with the Reactor Building Accessible.
Throttle the following valves to maintain charging water header pressure greater than or equal to 800 psig but as low as possible:
- In-service Flow Control Vlv, C12-FOO2A(FOO2B)
F002A(F002B)
VIv, C12-PCV-F003
- Drive Pressure Vlv,
- Charging Water Header Throttle Valve, C12-F034 Cperate RCIC/CRD to restore/maintain Operate Reactor water level +170-200 inches Page 24 of 34
EVENT 66 (Cont'd)
EVENT (Contd) LOSSLOSS OF OF SAT I SCRAM RO (Cont'd)
RO (Contd)
Place RHR Place RHR Loop Loop B B into into suppression suppression pool cooling.
Open SW-V105 Close SW-V143 If LOCA signal is present place RHR SW Booster Pumps B & 0D LOCA override switch to manual override Start RHR SW Pmp El l-PDV-F068B Adjust E11-PDV-F068B (1 pump 2000 - 4000 gpm)
(2 pumps 5000 - 8000 gpm)
CIg Wtr to Vital Hdr Supply Clg Verify spray logic is made up Start Loop B RHR Pmp Open E11-F028B Ell-F028B El11-F024B Throttle E l-F024B (1 pump 6000 - 10000 gpm) 6000-11500 (2 pumps 6000 - 11500 gpm)
Throttle El l-F048B E11-F048B Page Page 2525 of of 34 34
(Contd) LOSS OF SAT I SCRAM EVENT 6 (Cont'd)
BOP Time Action Notes Diagnose failure of DG4 to auto start Start and manually tie DG4 to E4.
Depresses the AUTO Start pushbutton.
Places the DG4 to E4 control switch to close.
Determine trip of DG3 is due to electrical fault.
OAOP-36. 1.
Announce and enter OAOP-36.1.
Determine UA UATT back-feed available and direct field actions.
Ensure NSW 2B running, start CSW 2B and 2C.
Start Control Room and Battery Room HVAC.
Restore Drywell cooling (Dispatch an ACAO to transfer RCC to CSW header).
Direct RPS to be restarted.
Close SW-V3 for suppression pool cooling when required.
34, Page 26 of 34
EVENT 7 SMALL BREAK LOCA A small Recirculation line break will occur. Available injection sources will be unable to stabilize RPV level. RPV level will drop to LL3 resulting in actuation of ADS timers. The crew may allow ADS to automatically initiate, or manually initiate ADS when level drops below TAF. Low pressure EGGS ECCS initiation logic will fail at LL3 requiring manual actions to start available pumps and align injection when RPV pressure drops below 400 psig. Bus E3 cannot be cross-tied due to the electrical fault, but 480V E7 can be cross-tied to E8.
Objectives:
SCO - Directs actions for a Reactor Scram, LPG, SGO LPC, and OAOP-36.1.
RO - Insert a reactor scram with no recirc pumps running.
BOP - Start DG4, tie to E4 and perform OAOP-36.1 actions.
Success Path:
Start and tie DG4 to E4. Rods inserted with ARI.
Simulator Operator Actions:
LI When directed by the lead evaluator, initiate Trigger 6 to activate small break D
LOCA.
LOGA.
SLC suction to demin water, initiate Trigger 9, wait two LI If requested to transfer SLG D
minutes and report actions complete.
LI If requested to perform actions for E7 D E7-E8
-E8 cross-tie per OAOP-36.1, Initiate Trigger 15 and wait 5 minutes and report breakers are racked in.
D LI If requested to stop drywell coolers, initiate Trigger 16.
LI If asked as I&G D I&C to investigate EGGS ECCS logics, acknowledge request D
LI When directed by the lead examiner, proceed to the next event.
Required Operator Actions Page 27 of 34
EVENT 7 (Cont'd)
EVENT (Contd) SMALL BREAK BREAK LOCA LOCA SRO Time Action Notes Notes Recognize rising drywell temperature and pressure, diagnose as LOCA.
Enter and direct EOP-01-RVCP, if not already in.
Direct reactor water level band of 170-200 inches.
CRD (SEP-09)
RCIC (LEP-Ol)
SLC (LEP-01)
Direct initiation of suppression chamber spray.
Direct drywell spray when suppression chamber pressure >11.5>1 1.5 psig.
Direct E7-E8 cross-tied.
Informs crew on decision of inhibiting or not inhibiting ADS Direct LL3 actuations verified Directs Low Pressure ECCS pumps be started Page 28 Page 28 of of 34 34
EVENT 77 (Cont'd)
EVENT (Contd) SMALL BREAK BREAK LOCALOCA RO RO Time Time Action Notes Notes Recognize rising drywell temperature and pressure, diagnose as LOCA Perform LEP-01 for SLC injection with demin water AC to perform infield Dispatch an AO actions.
When in field actions complete, starts B SLC Pump.
Initiate suppression chamber spray per SEP-03.
If necessary, then place Loop B 2/3 CORE HEIGHT LPCI INITIATION E11-CS-518B, OVERRIDE SWITCH, E11-CS-S18B, in Manual Overrd.
If the CTMT SPR OVRD light for the Loop B B CONTAINMENT SPRAY VALVE CONTROL SWITCH, 11-CS-S 17B is not on, then E11-CS-S17B E
momentarily place Loop B CONTAINMENT SPRAY VALVE Ell-CS-SI7B, CONTROL SWITCH, E11-CS-S17B, to Manual Ensure at least one RHR Loop B B Pump is operating Ensure TORUS DISCHARGE ISOL VLV, El l-F028B, is open E11-F028B, OpenTORUS SPRAY ISOL VLV, Open.TORUS El l-F027B.
E11-F027B.
Page Page 29 29 of of 34 34
(Contd) SMALL BREAK LOCA EVENT 7 (Cont'd)
RO (Cont'd)
(Contd)
Initiate drywell spray per SEP-02 Ensure WELL WATER TO VITAL HEADER VLV, SW-V141, is closed Ensure both reactor recirculation pumps are tripped Place all drywell cooler control (L/O) switches to OFF (LlO)
May request Drywell Cooler override switches to STOP.
Confirm the following:
- Drywell pressure and drywell SAFE temperature are in the "SAFE" region of the DSIL graph.
- Suppression pool water level is below +21 inches.
Open Loop B DRYWELL SPRAY ISOLVLV, INBD ISOL E11-FO2IB VLV, E11-F021 B Throttle open Loop B DRYWELL SPRAY OTBD ISOL VLV, E11- Eli FO16B, to obtain between 8,000-F016B, 10,000 gpm flow Inhibits ADS if directed by SCO Start all available low pressure ECCS pumps at 400 psig in reactor:
2B CS 2B RHR 2C RHR 2D RHR 2DRHR Page 30 of 34
(Contd) SMALL BREAK LOCA EVENT 7 (Cont'd)
BOP Time Action Notes Cross-tie E7-E8 when directed by SCO.
Units Obtain permission from both Units' SCO to close the 480V E bus cross-tie breakers Dispatch AO to Rack in the 480V Crosstie breakers.
Place SUB E7 480V Main Breaker, breaker AZI, AZ1, in trip.
Place BUS E3 TO SUB E7, breaker AJO in trip.
Place and hold BUS E7 TIE TO BUS E8, breaker AX5 and Al 0 in close A 10 until both cross-tie breakers indicate closed.
Page 31 of 34 of34
EVENT 8 REACTOR DEPRESSURIZATION Depressurization may be automatic or manually performed when level drops below TAF.
Objectives:
SCO - Directs actions Emergency Depressurization and restoration of reactor water level.
SGO RO - Performs action for emergency Depressurization and restoration of reactor water level.
Success Path:
1 70-200 inches.
Restore reactor water level to 170-200 Simulator Operator Actions:
oEl If requested to re-align SLG SLC to the boron tank, wait 4 minutes and modify SL_IASLCTST, NORM Remote Function SL_IASLGTST, oEl When RPV level is being controlled >+170",
+170, the scenario may be terminated oEl When directed by the lead evaluator place the simulator in FREEZE.
Required Operator Actions Restore and maintain RPV level above LL4 SRO Time Action Notes Determine ED is required.
Direct placing 7 ADS valve switches to open.
LPCI Direct re-alignment of RHR for LPGI injection ECCS injection Direct low pressure EGGS valves opened Direct RPV level be restored and maintained +170-200 inches Direct Alternative Source Term CREV, SEP-11) actions (SLC, GREV, SEP-Il)
Page 32 of 34
EVENT 8 (Cont'd)
(Contd) REACTOR DEPRESSURIZATION RO/BOP Time Action Notes Places 7 ADS valve control switches Re-align RHR for LPCI injection.
Ensures Drywell Sprays / SP Sprays /I Torus Cooling removed from service Manually perform any failed LPCI initiation actions Open 2B CS injection valve Open 2A RHR Loop Injection Valve Open 2B RHR Loop Injection Valve Close Recirc Discharge and Discharge Bypass valves Operate LP ECCS to restore and maintain RPV level 170-200 inches.
/eve/170-200 Re-align SLC for SLC Tank Injection (Alternate Source Term Action)
Start CREV (Alternate Source Term Action)
SEP-I I Perform SEP-11 (Alternate Source Term Action)
Page 33 of 34
Simulator Operator Activities:
WHEN directed by the lead examiner, place the simulator in FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER Page 34 of 34
BRUNSWICK NUCLEAR PLANT BRUNSWICK NUCLEAR PLANT c
C Continuous Progress Energy Use DATE COMPLETED _ _ _ _ _ _ _ _ __ FREQUENCY:
UNIT UNIT PWR,_ _ _ _ GMWE_____________
% PWR___________ GMWE,_ _ __ A.
A. When the position indicator of any Drywell -
SUPERVISOR _ _ _ _ _ _ _ _ _ _ __
SUPERVISOR______________________________________ Suppression Chamber vacuum breaker is REASON FOR TEST (check one or more): inoperable, perform as below:
Routine surveillance
_W/O # _ _ _ _ _ _ _ _ _ _ _ __ -
- At least once per 14 14 days W/O #___________________________
Other (explain)___________________________________
Other (explain)_ _ _ _ _ _ _ _ _ __ -
- Within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after any discharge of steam to the suppression chamber from any source
- Within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> following an operation that causes any of the vacuum breakers to open.
open, PLANT OPERATING MANUAL VOLUME X PERIODIC TEST UNIT o
0 OPT-02.31 OPT -02.3.1 a SUPPRESSION POOL TO DRYWELL VACUUM BREAKER POSITION CHECK (AL TERNA TE METHOD)
REVISION 19 OPT-02.3.la IOPT-02.3.1a Rev. 19 Page 11 of 15/15
1.0 PURPOSE 1.1 This test is the alternate method performed to determine the operability of the suppression pool to drywell vacuum breakers in conformance with the requirements specified in Technical Specifications Section SR 3.6.1.6.1.
1 .2 1.2 This test involves observation of differential pressures between the drywell and suppression pool to verify proper position.
2.0 REFERENCES
2.1 Technical Specification 2.2 FSAR, Section 6.2 2.3 1 (2)OP-1 0, Standby Gas Treatment System Operating Procedure 1
2.4 1 (2)OP-11, 1 (2)OP-1 1, Radiation Monitoring System Operating Procedure 2.5 1 1 (2)OP-24, Containment Atmosphere Control System 2.6 OOP-40, Auxiliary Steam System 2.7 System Description SD-24, Containment Atmospheric Control System 3.0 PRECAUTIONS AND LIMITATIONS 3.1 Drywell pressure should be maintained between -0.5 psig (-14 in. H 0 2
H ) and 2 0) 1.65 psig (46 in. HO 2
H 2 0).
).
3.2 1 .7 psig (47 in. H If drywell pressure increases to greater than 1.7 2 H ), a reactor 02 0),
SCRAM will occur.
3.3 This procedure establishes nitrogen flow to the Drywell without a a vent path.
There is a potential to cause rapid increases in Drywell pressure.
4.0 PREREQUISITES 4.1 No other testing or maintenance is in progress that will adversely affect the performance of this test.
4.2 SBGT System is aligned for standby in accordance with 1 1(2)0 P-I o.
(2)OP-1 0.
4.3 An auxiliary steam supply is available and ready to supply steam.
OPT-02.3.la IOPT-02.3.1a Rev. 19 Page 2 2 of 151 15
4.0 PREREQUISTIES Initials 4.4 MAIN STACK RADIATION MONITOR, D12-RM-4599-1, is in service in accordance with 1 1 (2)OP-11, (2)OP-1 1, and CAC PURGE VENT ISOL OVRD, CAC-CS-5519, is in OFF on Panel XU51. XU5I.
4.5 A Purge Exhaust Fan is available to vent the suppression chamber.
5.0 SPECIAL TOOLS AND EQUIPMENT NOTE: If an inch of water test gauge is used, pressure values are in parenthesis. If different data points are desired, convert psig to inches of H 0 2
H2 0 by dividing the psig value by .0361 to get inches of water.
5.1 0-100 inch water test gauge or a 0-15 psig test gauge if required.
5.1.1 Test gauge identification number N/A 5.1.2 Test gauge calibration date N/A 5.1.3 Test gauge calibration due date N/A 6.0 ACCEPTANCE CRITERIA This test may be considered satisfactory when the following criteria are met:
6.1 A vacuum breaker is verified in the closed position by establishing a differential pressure between the drywell and suppression pool.
6.2 The differential pressure between the drywell and suppression pool remains 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> without greater than one-half the initial differential pressure for 1 nitrogen makeup.
7.0 PROCEDURAL STEPS Initials 7.1 OBTAIN permission from the Unit sea SCO to perform this test. RO 7.2 ENSURE prerequisites listed in Section 4.0 are met. RO 7.3 ENSURE the required data has been recorded in Section 5.0. RO OPT-02.3.laa 1OPT-02.3.1 Rev. 19 Page 3 of 15115
7.0 PROCEDURE STEPS Initials 7.4 Drywell Pressure Indicator, CAC-PI-2685-1, CONFIRM Orywell CAC-Pl-2685-1, is R~
RO operable OR test gauge installed at CAC-PSH-2684 INSTRUMENT DRAIN VALVE, CAC-IV-696 CA C-I V.696 (drywell X57D).
penetration X570).
7.4.1 IF a test gauge was installed, THEN UNLOCK AND NA OPEN CAC-PSH-2684 INSTRUMENT DRAIN VALVE, CAC-IV-696.
7.5 VENT the Suppression Chamber using the Purge Exhaust RO Fans as follows:
7.5.1 OBTAIN permission from E&RC to vent Primary RO Containment through the Purge Exhaust Fans.
7.5.2 OPEN the following valves:
- 1. PURGE EXHAUST FANS SUCTION VALVE, RO I-BF V-RB.
I-BFV-RB.
- 2. PURGE EXHAUST FANS INBOARD EXHAUST RO N-BF V-RB.
HEADER ISOLATION VALVE, N-BFV-RB.
7.5.3 CLOSE the following valves:
- 1. VA-D-BF V-RB.
Reactor Building SBGT Inlet Valve, VA-D-BFV-RB. RO
- 2. VA -H-BF V-RB.
Reactor Building SBGT Inlet Valve, VA-H-BFV-RB. RO 7.5.4 OPEN PURGE EXHAUST FANS OUTBOARD RO EXHAUST HEADER ISOLA ISOLATION TlON VALVE, A-BF V-RB.
A-BFV-RB.
7.5.5 OPEN the following breaker for the selected Purge Exhaust Fan.
- 2. PURGEEXHAUSTFAN, PURGE EXHAUST FAN, MCCI(2)XH MCC 1(2)XH NA B-PS-EF-RB Compt. EK3 OPT-02.3.la IOPT-02.3.1a Rev. 19 15 Page 4 of 151
7.0 PROCEDURE STEPS Initials 7.5.6 7.S.6 PLACE the control switch for the selected Purge RO Exhaust Fan in either SLOW or FAST.
7.5.7 7.S.7 CONFIRM Purge Exhaust Fan A(S) A(B) Suction Valve, RO (K-BF V-RB), indicates open at M-BFV-RB (K-BFV-RB),
MCC 11 (2)XG Compt. EH6 (MCC 11 (2)XH Compt. EM2).
7.5.8 7.S.8 CONFIRM Purge Exhaust Fan A(S) A(B) Discharge Valve, RO (L-BF V-RB),, indicates open at MCC 11(2)XG J-BFV-RB (L-BFV-RB) (2)XG EH5 (MCC 11(2)XH Compt EHS (2)XH Compt. EM EMI).
1).
7.5.9 7.S.9 OPEN TORUS PURGE EXH VL V, GAG-V7.
VLV, CAC-V7. RO 7.5.10 7.S.10 OPEN TORUS PURGE EXH VLV, GAG-VB. CAC-V8. RO NOTE: Venting maintains the suppression pool at atmospheric pressure and is required for the duration of this test to ensure drywell pressure is equivalent to the differential pressure between the drywell and the suppression pool.
CAUTION IF drywell pressure increases to greater than 1.7 psig (47 in. H20),0), THEN a reactor 2
H SCRAM will occur.
7.6 PERFORM the following to increase drywell pressure to 0
2 H
1 .0 psig (27.7 in. H 1.0 ) on indicator identified in Step 7.4.
20)
NOTE: IF the CAC inerting system is not available, THEN the drywell may be pressurized using the CAD System in accordance with 1 I (2)OP-24, Containment Atmosphere Control System. IF the CAD System is used, THEN CAD tank level must remain greater than 43S0 4350 gallons.
7.6.1 OPEN INERTING N2 INLET VLV, CAC-VS8. CAC-V58. RO 7.6.2 OPEN INERTING N2 INLET VLV, CAC-V4. RO 7.6.3 OPEN OWDW N2 INLET VALVE, CAC-V6. RO OPT-02.3.laa
\ OPT-02.3.1 Rev. 19 Page5of15 Page S of 1S\
7.0 PROCEDURE STEPS Initials 7.6.4 ENSURE STEAM TO CAC VAPORIZER, 2-HS-V502, RO is open.
CAUTION Cryogenic liquids will cause severe burns if they contact the skin. To prevent injury when working with these liquids, the following precautions should be followed:
- 1. Ventilate the area - do not breathe the vapor.
- 2. Do not catch and confine bleedoff in a closed container.
- 3. Wear loose fitting gloves and outer garments, non-porous preferred.
- 4. Do not touch uninsulated pipes with bare skin.
7.6.5 ENSURE auxiliary steam supply is in operation and is RO ready to supply steam for inerting.
NOTE: 1-AS-V437 is located on the 21' 21 elevation in the equipment laydown area near the sump.
7.6.6 OPEN DRAIN VALVE TO SUMP, 1-AS-V437, to drain RO the auxiliary steam line between the auxiliary boiler and the Augmented Off-Gas Building.
7.6.7 WHEN sufficient time has passed for the line to be RO drained and steam can be heard passing through the drain line, THEN CLOSE 1-AS-V437.
NOTE: Steam pressure to the Inerting Vaporizer can be controlled by either 2-AS-PC V-3103. 1-AS-PCV-3103 1-AS-PC V-3103 OR 2-AS-PCV-3103.
1-AS-PCV-3103 1-AS-PC V-3103 is normally in service.
7.6.8 IF it is desired to control the steam pressure to the 1-AS-PC V-3103, THEN Inerting Vaporizer by using 1-AS-PCV-3103, PERFORM the following:
- 1. ENSURE INLET ISOLATION VALVE TO RO 1-AS-PC V-3103, 1-AS-V408, is open.
1-AS-PCV-3103, OPT-02.3.la
\ OPT-02.3.1a Rev. 19 15 Page 6 of 15\
7.0 PROCEDURE STEPS Initials
- 2. ENSURE OUTLET ISOLA TlON TION VAL VALVE VE TO RO 1-AS-PC 1-A V-3103, S-PC V-31 03, 1-HS-V501, is open.
7.6.9 IF it is desired to control the steam pressure to the Inerting Vaporizer by using 2-AS-PCV-3103, 2-AS-PC V-3103, THEN PERFORM the following:
- 1. INLETISOLATION CLOSE INLET ISOLATION VALVE TO RO 1-AS-PC 1-A V-3103, S-PC V-31 1-AS-V408.
03, 1-AS-V40B.
- 2. ENSURE OUTLET ISOLATION ISOLA TION VALVE TO RO V-3 103, 2-A S-PC V-31 2-HS- V500, is open.
03, 2-HS-V500,
- 3. SLOWLY OPEN INLET ISOLATION ISOLA TION VALVE TO RO 2-AS- V408.
2-A S-PC V-3 103, 2-AS-V40B.
2-AS-PCV-3103, NOTE: 2-HS-V503 has two control switches, one on Unit 1 1 RTGB and one on Unit 2 RTGB.
7.6.10 OPEN AUXSTEAM AUX STEAM SPL SPLYTOY TO PURGE VAP, RO 2-HS- V503.
2-HS-V503.
CAUTION 2-CA C-HIC-2695 can occur with pressures greater Damage to AIR CONTROLLER, 2-CAC-HIC-2695 than 15 psig.
7.6.11 ADJUST LN2 VAPORIZER STEAM INLET CONTROL RO VALVE, 2-CAC-HV-2695, air signal as necessary, 2-CA C-HIC-2695.
using 2-CAC-HIC-2695.
OPT-02.3.la IOPT-02.3.1a Rev. 19 Page7of15 Page 7 of 151
7.0 PROCEDURE STEPS Initials CAUTION IF nitrogen temperature leaving the vaporizer is maintained above 150°F, THEN damage to the polyethylene pipe may occur.
NOTE: 2-CAC-HV-2683 has two control switches, one on Unit 1 1 RTGB and one on Drywell pressure Unit 2 RTGB. The control switch for the unit increasing Orywell should be used to open the 2-CAC-HV-2683.
NOTE: 2-CA C-HV-2683 will auto close on the following signals:
2-CAC-HV-2683
- Drywell pressure high Orywell 1 .25 psig 1.25
- Nitrogen temperature low 10°F (measured at inerting vaporizer outlet) 7.6.12 ADJUST air pressure to LN2 VAPORIZER N2 INLET RO
!...!.R=O_
CONTROL VALVE, 2-CAC-HV-2683, to 0 psig, using 2-CA C-HIC-2683.
2-CAC-HIC-2683.
7.6.13 ENSURE Unit 1 I control switch for PURGE VAP LN2 RO VL INLET VL V, 2-CAC-HV-2683, 2-CA C-H V-2683, is in NEUT.
7.6.14 ENSURE Unit 2 control switch for PURGE VAP LN2 ~ RO VLV, INLET VL V, 2-CAC-HV-2683, is in NEUT.
7.6.15 MOMENTARILY PLACE Unit 1 1(2)
(2) control switch for RO LN2 INLET VLV, 2-CAC-HV-2683, in PURGE VAP LN2INLET OPEN.
OPT-02.3.la IOPT-02.3.1a Rev. 19 Page 8 of 151 15
7.0 PROCEDURE STEPS Initials CAUTION Steam should be admitted to the vaporizer before nitrogen is admitted to prevent cold nitrogen gas from entering the containment and prevent rupturing the nitrogen line.
CAUTION The following steps have the potential to cause a rapid increase in Drywell pressure.
7.6.16 OPEN CAC INERTING VESSEL NITROGEN OUTLET RO VALVE, 2-CAC-HV44.
VALVE,2-CAC-HV44.
7.6.17 SLOWLY INCREASE LN2 flow by increasing the air RO signal to LN2 VAPORIZER INLET CONTROL VALVE, 2-CAC-HV-2683, using 2-CAC-HIC-2683.
NOTE: When establishing the desired flow rate, consideration should be given for initial drywell pressure, recognizing pressure can increase rapidly with a high flow rate. Past experience has shown 1000 to 2000 scfm is adequate.
When drywell pressure is 1.0 psig (27.7 in. H 02 0),
2 H ), the CAC INERTING VESSEL NITROGEN OUTLET VALVE, 2-CAC-HV44, 2-CA C-H V44, should be closed quickly to stop the pressure increase.
7.6.18 ESTABLISH a flow rate less than or equal RO to 4000 scfm as indicated on CAC-FI-2568-2 or CA C-FI-2567- 1.
CAC-FI-2567-1.
7.6.19 IF purge vaporizer outlet line ices up, THEN CLOSE RO CAC INERTING VESSEL NITROGEN OUTLET VALVE, 2-CAC-HV44, and correct any problems before opening the valve to continue.
OPT-02.3.la IOPT-02.3.1a Rev. 19 Page9of15 Page 9 of 151
7.0 PROCEDURE STEPS Initials 7.7 WHEN drywell pressure is 1.0 psig (27.7 in. H 02 0),
2 H ), THEN STOP drywell pressurization as follows:
7.7.1 CLOSE CAC INERTING VESSEL NITROGEN RO OUTLET VALVE, 2-CAC-HV44, AND WAIT 5 minutes to allow the liquid nitrogen to vaporize.
7.7.2 PLACE Unit 1 1 Control Switch for PURGE VAP LN2 RO INLET VL VLV, V, 2-CAC-HV-2683 in CLOSED.
7.7.3 PLACE Unit 2 Control Switch for PURGE VAP LN2 ~RO INLET VL V, 2-CAC-HV-2683 in CLOSED.
VLV, 7.7.4 CLOSE INERTING N21NLETN2 INLET VALVE, CAC-V58. RO 7.7.5 CLOSE INERTING N2 INLET VALVE, CAC-V4. RO 7.7.6 CLOSE OW DWN2 INLET VALVE, CAC-V6.
N21NLET RO 7.7.7 CLOSE AUX STEAM SPL SPLYY TO PURGE VAP, RO 2-I-IS- V503.
2-HS-V503.
7.7.8 CLOSE LN2 VAPORIZER STEAM INLET CONTROL RO 2-CA C-HV-2695.
VALVE, 2-CAC-HV-2695.
7.7.9 MONITOR purge vaporizer to ensure CAC INERTING RO VESSEL NITROGEN OUTLET VALVE, 2-CAC-HV44, is not leaking by its seat.
7.7.10 IF CAC INERTING VESSEL NITROGEN OUTLET RO VALVE, 2-CAC-HV44, is leaking by its seat, THEN OPEN AUX STEAM SPL SPLY Y TO PURGE VAP, 2-HS-V503, AND LN2 VAPORIZER STEAM INLET CONTROL VALVE, 2-CAC-HV-2695.
7.8 OBSERVE drywell pressure indicator identified in Step 7.4 RO for 5 minutes to confirm that drywell pressure has stabilized.
OPT-02.3.la IOPT-02.3.1a Rev. 19 15 Page 10 of 15/
7.0 PROCEDURE STEPS Initials CAUTION IF containment temperatures change OR any evolution occurs which has the potential
!F for changing drywell or suppression pool temperature, THEN this test is invalid and should be performed after conditions stabilize.
7.9 RECORD the following data at 10-minute intervals for 11 hour1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />.
Date: _Today_____
_Today Time Started: _60 minutes ago ago_______
Drywell Pressure Time (Minutes) 0 2
H Reading (psig) or (in. H )
2 O) 7.9.1 o 0 (Initial) 1.1 7.9.2 10 1.1 7.9.3 20 1.1 7.9.4 30 1.1 7.9.5 40 1.1 7.9.6 50 1.1 7.9.7 60 (Final)
IOPT-02.3.1 OPT-02.3.laa Rev. 19 15 Page 11 of 151
7.0 PROCEDURE STEPS Initials 7.10 CONFIRM final drywell pressure reading is at least greater than one half the initial pressure by dividing the final pressure by the initial pressure as follows:
7.10.1 RECORD final pressure reading.
0)final 2
H psig (in. H20)final 7.10.2 COMPUTE ratio.
- 0) initial 2
H psig (in. H20) 7.10.3 COMPARE ratio obtained in Step 7.10.2 to 0.5 AND CHECK appropriate space:
Ratio greater than 0.5.
Ratio less than 0.5.
7.11 SECURE Suppression Chamber venting as follows:
7.11.1 CLOSE TORUS PURGE EXH VL VLV, CAC-V8.
V, GAG-VB. I/
Ind.Ver.
7.11.2 CLOSE TORUS PURGE EXH VL VLV, CAC-V7.
V, GAG-V7. I/
I nd.Ver.
Ind.ver.
7.11.3 MOMENTARILY PLACE control switches for both Purge Exhaust Fans in OFF:
7.11.4 CONFIRM Purge Exhaust Fan A(B) A(S) Suction Valve, I/
M-BF V-RB (K-BFV-RB),
M-BFV-RB (K-BF V-RB), indicates closed at Ind.Ver.
Ind.ver.
MCC 1 1(2)XG (2)XG Compt. EH6 (MCC 1 1(2)XH (2)XH Compt. EM2).
7.11 .5 7.11.5 CONFIRM Purge Exhaust Fan A(S) A(B) Discharge Valve, /I (L-BF V-RB), indicates closed at J-BFV-RB (L-BFV-RB), Ind.Ver.
Ind.ver.
MCC 1 1(2)XG (2)XG Compt. EH5 (MCC 1 1(2)XH (2)XH Compt. EM1).
OPT-02.3.la IOPT-02.3.1a Rev. 19 l2of Page 12 of 15115
7.0 7.0 PROCEDURE STEPS PROCEDURE STEPS Initials Initials 7.11 .6 7.11.6 ENSURE breakers breakers for the following Purge for the Purge Exhaust Exhaust Fans Fans are are closed:
closed:
1.
- 1. EXHAUST FAN, PURGE EXHAUSTFAN, MCCI(2)XG MCC 1 (2)XG /
A-PS-EF-RB Compt. EG7 Ind.Ver.
Ind.ver.
- 2. PURGE EXHAUSTFAN, EXHAUST FAN, MCCI(2)XH MCC 1 (2)XH N/f-\
N/A B-PS-EF-RB Compt. EK3 EK3 ind.Ver.
Ind.ver.
7.11 .7 7.11.7 CLOSE the following valves:
1.
- 1. EXHAUST FANS SUCTION VALVE, PURGE EXHAUSTFANS I/
I-BFV-RB.
I-BF V-RB. lnd.Ver.
Ind.ver.
- 2. PURGE EXHAUST FANS INBOARD EXHAUST /
HEADER ISOLATION VALVE, N-BF V-RB.
N-BFV-RB. Ind.Ver.
Ind.ver.
- 3. PURGE EXHAUST FANS OUTBOARD EXHAUST I/
HEADER ISOLATION VALVE, A-BF V-RB.
A-BFV-RB. Ind.Ver.
Ind.ver.
7.11.8 OPEN the following valves:
- 1. SBGT TRAIN A REACTOR BUILDING SUCTION /I VAL VALVE, VA-D-BF V-RB.
VE, VA-D-BFV-RB. lnd.Ver.
Ind.ver.
- 2. SBGT TRAIN B REACTOR BUILDING SUCTION /I VAL VALVE, VA-H-BF V-RB.
VE, VA-H-BFV-RB. Ind.Ver.
Ind.ver.
7.12 IF required, THEN CLOSE AND LOCK CAC-PSH-2684 NA INSTRUMENT DRAIN VALVE, CAC-IV-696. Ind.Ver.
Ind.ver.
7.13 IF required, THEN REMOVE the test gauge installed in NA Step 7.4. Ind.Ver.
Ind.ver.
7.14 ENSURE the suppression pool oxygen concentration is less than 4% oxygen.
7.15 ENSURE the required information has been recorded on the cover page.
7.16 NOTIFY the Unit SCO500 when this test is complete or found to be unsatisfactory.
OPT-02.3.la IOPT-02.3.1a Rev. 19 Rev. 19 Page 13 Page of 15/
13 of 15
ATTACHMENT 1 1 Page 1 1 of 11 Certification and Review Form General Comments and Recommendations:
Initials Name (Print)
Performed by:
Performed by:
Exceptions to satisfactory performance: _________________________________
Corrective action required: _________________________________________
Test procedure has been satisfactorily completed:
Unit SCO:
Signature Date Test procedure has NOT been satisfactorily completed:
Unit SCO:
Signature Date Test has been reviewed by:
Shift Manager: _____________________________
Shift Signature Date OPT-02.3.la IOPT-02.3.1a Rev. 19 Page14of15 Page 14 of 151
REVISION
SUMMARY
Revision 19 incorporates TS Amendments 251 and 279 which requires a vacuum breaker position check within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> following an operation that causes any of the vacuum breakers to open, replaced Shift Superintendent with Shift Manager Revision 18 deletes actions to operate 1-AS-V432. This valve has been changed to a a normally open valve, it will no longer need to be operated to drain the aux. steam line.
Revision 17 implements Tech Spec Amendments 223 (U1) (UI) and 248 (U2) by changing the frequency from 2 hrs. to 6 hrs. after any discharge of steam to the suppression chamber from any source.
Revision 16 incorporates ESR 00-00283 which designates CAC-IV-696 CAC-lV-696 as a locked closed valve. The procedure now requires unlocking and opening this valve when using a test gauge, then restoring it to locked closed. This revision also improves the test gauge selection to include use of a 0-15 psig gauge instead of a 0-30 psig gauge.
Inches of water values were provided for specified psig values and a conversion factor provided if additional values are desired. A step was added to ensure the test gauge is valved in if used.
Revision 15 contains several enhancements to make the PT more consistent with OP-24 for establishing nitrogen flow to the drywell and adds a note to clarify expected system response.
Revision 14 implements Tech Spec Amendments 203(U1) and 233(U2) by changing the reference and frequency. Adds term "Alternate Alternate Method" Method to title for clarification and includes minor OAP-05 format changes.
OPT-02.3.la IOPT-02.3.1a Rev. 19 lSof Page 15 15 of 151
PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION SIMULATOR SCENARIO 2010-1 NRC EXAM SCENARIO #2
II Appendix 1\
D Scenario Outline Form ES-D-1 Facility: BRUNSWICK Scenario No.: 2010-1 ##2 2 Op-Test No.: DRAFT Examiners: Operators:
(SRO)
(RO)
(BOP)
Initial Conditions: The plant is operating at 100% power with Condensate Pump 2C out of service for maintenance. CWIP 2B needs to be removed from service to support motor oil replacement.
Turnover: Reduce reactor power to 90% to support shifting CWIPs lAW 20P-29.
Event MaIf. No.
Malf. Event Event Description No. Type*
Type*
1 1 N/A R-RO Power reduction to support removal of CWIP 2A R-SRO 2 N/A N-BOP Shift CWIPs to remove 2B from service.
N-SRO 3 ES014F -RO I-RO Inadvertent HPCI initiation (TS) l-SRO I-SRO 4 K4B39B C-BOP 2A CSW pump trip (TS)
ZUAI 761 ZUA1761 c-SRO C-SRO ZUA118 5 K4B41A 1-BOP I-BOP 2C CSW pump auto start failure l-SRO I-SRO 6 RWO13F RW013F M-AlI M-AII RWCU leak in reactor building 77 ft.
7 EEO3OM EE030M C-BOP Loss of MCC 2XC C-SRO 8 RWO16F RW016F C-RO 2-G31-F004 motor overload C-SRO 9 N/A M-AlI M-AII Manual reactor Scram prior to MSOT/L 10 10 K41 01 B K4101B C-BOP BOP bus 2D fault fail to transfer c-SRO C-SRO 11 11 ESO41 ES041F F 1-RO I-RO RCIC auto start failure l-SRO I-SRO 12 12 ZUAI214 ZUA1214 SRHR water level Hi-HI (2 areas above Max Safe Operating Water Level)
Emergency Depressurization required 13 13 RPV depressurized with level in the normal normal band.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
SCENARIO DESCRIPTION The plant is operating at 100%
The 100% power with Condensate Pump 2C out of service for maintenance. CWIP 2B 2B needs to be be removed from service service to support support motor motor oil replacement.
replacement.
Event 11 Reduce reactor power to 90% to support CWIP shift lAW 20P-29 (third Condensate Pump is not available, power reduction required).
Event 2 Shift CWIPs lAW 20P-29, Section 8.14 Event 3 HPCI will inadvertently initiate. The crew will respond per AOP-03.0 and terminate HPCI operation.
Event 4 CSW Pump 2A will trip. CSW header pressure will lower below 40 psig.
Event 5 CSW Pump 2C will fail to auto start. The crew will respond per AOP-19.0 and manually start CSW Pump 2C. CSW header pressure will recover.
Event 6 A line rupture will develop in the RWCU system in the 77' 77 elevation.
Event 7 MCC 2XC will de-energize due to fault (loss of power to G31-F001)
Event 8 G31-F004 will thermally trip. OAOP-05 will be entered and the Reactor Building temperatures and water levels will rise requiring a a manual manua scram.
Event 9 Manual Scram prior to reaching the Maximum Safe Operating Temperature or Level.
Event 10 When the turbine is tripped, BOP Bus 20 2D will fail to auto transfer to the SAT. DG3 will auto start and energize E3. DG1 will auto start on Loss BOP Bus 20 2D with UAT de-energized. Loss of BOP Bus 20 2D will require entry into OAOP-36.1 and causes a leve will drop due to the inventory loss through loss of FW injection. Reactor water level the leak.
Event 11 If level drops to the LL2 initiation, RCIC will fail to auto initiate, but can be manually started. With RCIC injection maximized, LEP-01LEP-Ol alternate coolant injection systems, along with SEP-09 CRD flow maximized (RB inaccessible) RPV level will be maintained above TAF.
Event 12 Area temperatures and water levels will rise. South Core Spray will exceed Max Normal, then Max Safe Operating Water Level. Then South RHR will exceed Max normal then Max Safe Operating Water Level. The crew is directed to consider anticipating emergency depressurization as soon as EOP-03-SCCP directs inserting aa manual scram. If the crew does not anticipate emergency depressurization (rapid depressurization to the main condenser) a second area will exceed Max Safe.
Operating Water Level requiring Emergency Depressurization.
Event 13 13 Once the reactor is depressurized and RPV level is being maintained +170-200, +170-200", the scenario may be terminated.
OBJECTIVES OBJECTIVES SRO SRO
- 1. 3442078502,
- 1. 344207B502, Direct Direct Actions To Control Control Secondary Secondary Containment Area Temperatures Per EOP-03-SCCP 344208B502, Direct Actions To Control Secondary Containment Area Radiation
- 2. 3442088502, Levels Per EOP-03-SCCP
- 3. 3442098502, 344209B502, Direct Actions To Control Secondary Containment Water Level Per EOP-03-SCCP 344233B502, Direct Actions To Anticipate Emergency Depressurization Per EOP-
- 4. 3442338502, EOP 01 -RVCP 01-RVCP
- 5. 3442178502, 344217B502, Direct Actions To Control RPV Level Per EOP-01-RVCP 344227B502, Direct Actions To Control An Unmonitored Radioactive Release With
- 6. 3442278502, The Release Rate Less Than That Requiring An Alert Declaration Per EOP-04-RRCP RO 217003B101, Manually Startup the RCIC System Per OP-16
- 1. 2170038101, 200065B501, Monitor Reactor Water Level Instrumentation Per EOP Caution 11
- 2. 2000658501, 200601B401, Respond to radioactive spills, high radiation and airborne activity per
- 4. 2006038501, 20021 9B501, Rapidly Depressurize the Reactor Using the 8ypass
- 8. AOP-03.0 C. AOP-05.0 D. AOP-19.0 E. AOP-36.1 F. 01-50 G. EOP-01-RSP H. EOP-01-RVCP I. EOP-02-PCCP J.
J. EOP-03-SCCP K. EOP-04-RRCP L. EOP-LEP-01 EOP-LEP-01 M. EOP-01-SEP-09 EOP-01-SEP-09 N.
N. Conduct Conduct Of Operations Manual Manual 0.
O. Technical Specifications Specifications P.
P. Plant Emergency Procedures Procedures Q. Annunciator Panel Procedures Procedures
SIMULATOR SETUP A. Initial Conditions
- 2. Rx Pwr 100%
- 3. Core Age EOC B. E ven tT*
Event Triggers riggers Event Trigger Description 0
0 Normal Operation (Reduce reactor power and shift CWIPs)
I 1 (ESOI4F HPCI Inadvertent Initiation)
Manually Initiated (ES014F 2 Manually Initiated (CSW Pump A trip)
Auto Initiated (CSW Pump C fails to auto start) 3 Manually Initiated (RWCU Rupture) 4 Auto initiated (Loss of MCC 2XC - G31-FOO1)
- G31-F001) 5 5 Auto Initiated (G31-F004 Green = F004)
= TRUE, overrides on FOO4)
Auto Initiated (Loss of BOP bus 2D fail to transfer)
Auto Initiated (S RHR Flood Hi-Hi Alarm)
C. Malfunctions Malfunctions Summary MaIf ID MalflD Mult Description Current Target Rmptime Actime Dactime Trig ID 10 Value Value ESO14F ES014F HPCI Inadvertent Initiate FALSE TRUE 1 1
RWO13F RW013F RWCU BRK TRIANGLE ROOM 77' 77 50% 10 MIN 3 ESO4I F ES041F RCIC FAILURE TO AUTO START TRUE TRUE RWOI5F RW015F 2-G31-FOO1 Fails to Isolate 2-G31-F001 TRUE TRUE RWOI6F RW016F 2-G31-F004 Fails to Isolate TRUE TRUE Remotes Summary ID Remf 10 Mult Description Current Target Rmptime Actime Trig ID 10 Value Value ZVRWOO4M G31-F004 G31-FOO4 EEO3OM EE030M MCC 2XC Bus Failure 4
SIMULATOR SETUP D. Overrides Switches Tag 10 ID Description Position! Actual Override Rmptime Actime Dactime Trig Target Value Value K4B41A CONV HDR SW PMP C DISCH CONY D1SCH VLVS AUTO ON OFF K41O1B K4101B SATINCL1NETOBUS2DON SAT INC LINE TO BUS 20 ON NORMAL ON OFF K41O1B K4101B SATINCL1NETOBUS2DON SAT INC LINE TO BUS 20 ON CLOSE OFF OFF K4101B SATINCL1NETOBUS2DON SAT INC LINE TO BUS 20 ON TRIP OFF ON K4B39 CONV HDR SW PMPA CONY PMP A DISCH D1SCH VLVS START OFF OFF 2 K4B39 CONV HDR SW PMPA CONY PMP A DISCH D1SCH VLVS STOP OFF ON 2 Lamps ID Tag 10 Description Position! Actual Override Rmptime Actime Dactime Trig Target Value Value Q141ORRK Q1410RRK RWCUVLVG31-FO04RED RWCU VLV G31-F004 RED ON/OFF ON!OFF ON ON Q141OLGK Q1410LGK RWCUVLVG31-FOO4GREEN RWCU VLV G31-F004 GREEN ON/OFF ON!OFF OFF ON 2 Q4B391 G4 Q4B391G4 CONV SW PMP A PMP OFF GREEN CONY ON/OFF ON!OFF ON OFF 10 SEC Annunciator Summary Activate Deactivate Trig Event Panel Tag Title Value (ramp Time (sec) Time (sec) rate)
P601 ZA255 OUTSD OUTBD NSSS Vlv Ovid OvId ON o 0 SEC NA 5 XU-3 ZUA1214 S RHR Flood Hi-Hi S ON OSEC 0 SEC NA 6 E. Materials ENP-24 for IC-13
F. Special Instructions
- 1. Ensure "Exam Exam In Progress" Progress Stop Signs posted at all simulator entrances.
- 2. Advance all chart recorders to indicate steady state conditions.
- 3. Place all SPDS displays to the Critical Plant Variable display (#100).
- 4. Ensure appropriate keys have blanks in switches.
- 7. Ensure reference material is in appropriate location.
- 8. Verify all log books have blank sheets only.
- 9. Place red cap on Condensate Pump 2C and ensure Unit Trip Load Shed plaque is updated for the current line-up.
@ P603.
IC-i 3 @
- 11. Ensure ENP-24 for IC-13
- 12. Ensure Hotwell Temperature is below 115°F (C099) to allow 2 Condensate pump operation. (OP-32 P&L)
- 13. Load scenario file, 2010 Scenario 2.scn, if required.
SHIFT BRIEFING BRIEFING Plant Status Plant Unit 2 is operating at 100% power, Middle of Cycle.
Equipment Out of Service Condensate Pump 2C is under clearance for pump impeller replacement and is expected to remain out of service for five days.
No other equipment is out of service pay Plan of the Day CWIP 2B needs to be removed from service to support motor oil replacement.
Reduce reactor power to 90% to support shifting CWIPs.
SCENARIO TRAINING INFORMATION A. IInstructor nstructor Notes
- 1. This guide is designed to meet the requirements of an examination NUREG-1 021, Revision 9, ES-scenario for Initial License as outlined in NUREG-1021, 301 and Appendix D.
- 2. During the execution of this scenario, the students should be rated on the performance of the objectives, compliance with general simulator performance standards, and for overall team skills in accordance with TAP-409 and NUREG-1 021, ES-303.
B. Common Student Problems/Errors None C. Simulator Deficiencies There are no known simulator deficiencies applicable to this scenario.
D. CREW CRITICAL TASKS pass/fall (Critical Tasks are identified to ensure scenario validity and do not constitute pass/fail criteria for Initial License.)
- 1. Manually scram the Reactor before an area reaches Maximum Safe Operating value.
- 2. Depressurize the RPV by performing or anticipating Emergency Depressurization.
- 3. Maintain RPV level above LL4
EVENT 1I EVENT SHIFT TURNOVER, SHIFT TURNOVER, REDUCE REDUCE POWER POWER Reduce reactor Reduce reactor power power to 90% to support CWIP CWIP shift shift lAW lAW 20P-29 20P-29 (third (third Condensate Condensate Pump Pump isis not not available, power reduction power reduction required).
required).
Objectives:
SCO - Directs power to be reduced in order to shift CWIPs.
RO - Performs power reduction in accordance with ENP-24.5.
Success Path:
Power reduced to less than or equal to 90% power.
Simulator Operator Actions:
o Li If contacted as the NE for power reduction guidance, inform crew to use ENP-24.5 guidance.
o Li If contacted as the NE to monitor power reduction, inform crew that you will monitor core performance on the computer.
o Li If contacted as the Load Dispatcher, acknowledge report that Brunswick Unit 2 will be lowering power.
oLi If contacted as the NE for guidance on operation above the MELL line, inform crew to take the appropriate actions per ENP-24.5 to get below or on the MELLL.
oLi When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity Manipulation - Reduce Power to 90% to support CWIP shift.
SRO Time Action Notes Directs power to be reduced in accordance with ENP-24.5 using recirculation flow in order to swap CWIPs.
Directs RO to insert control rods to get below the MELL line.
May direct OGP-12 reference due to control rod movements.
I EVENT 1 SHIFT TURNOVER, REDUCE POWER RO Time Action Notes May reference 20P-02, Section 7.1 Request peer checker /I reactivity team.
Reduces power lAW ENP-24.5 using recirculation flow to 90% power.
Reduce flow on one RR Pump
(--2%) at a time to stay within
(-2%)
66 Mlbs (3.5x10 mismatch criteria (3.5x10 MIbs jet pump flow).
Continues alternating Recirc pump speed reductions until 90% power.
Verifies operation on the Power to Flow map.
Recognizes operation above the MELLL line and informs SCO.
Inserts control rods using ENP-24.5 to get below the MELLL line. (Should only need to insert one control rod 22-19)
Turns control rod power on.
Selects control rod (22-19) in accordance with ENP-24.5 sheet.
May also insert 30-35, 30-19, or 22-
- 35. (in this order in order to establish a margin to the MELLL line)
Continuously drives selected rod full in using RMCS.
BOP Time I Time I Action Action Monitors the plant.
I Notes Notes
EVENT 2 CWIP SHIFT Shift CWIPs lAW 20P-29, Section 8.14 Objectives:
SCO -
BOP - Performs CWIP shift in accordance with 20P-29, Section 8.14.
Success Path:
20 CWIP in service and 2B CWIP shutdown with the CW 2C CWISOL ISOL VALVES MODE SELECTOR in position C.
Simulator Operator Actions:
oLI If contacted as E&RC, acknowledge CWIP pump shift.
oLI If contacted as Radwaste, acknowledge CWIP pump shift.
oLI If contacted as Outside AO, AC, report prestart checks satisfactory for CWIP 2C.
oLI If contacted as Outside AOAC to monitor circulating water traveling screen differential pressure, acknowledge request.
oLI If contacted as Unit One, report 3 CWIP and 3 CWOD CWCD pumps in service on U1. Ui.
oLI When 2C CWIP is started, contact BOP as Outside AC AO to report 2C 20 CWIP satisfactory start and normal traveling screen differential pressures.
oLI When directed by the lead examiner, proceed to the next event.
Required Operator Actions Normal Operation - 20P-29, Section 8.14 (Shifting Circulating Water Intake Pumps).
SRC SRO Time Action Notes Directs placing 2C 20 CWIP in service and shutting down 2B CWIP.
Directs RO to monitor the plant.
RO Time Action Notes Monitors the plant.
Monitors reactor recirculation pump speed during CWIP start.
2 CWIP SHIFT EVENT 2 BOP Time Action Notes 2OP-29, Section 8.14 (Shifting Obtains 20P-29, Circulating Water Intake Pumps).
Reviews 20P-29 precautions and limitations:
Change in CWIP combination and circulating pump mode switch shall be recorded in the log. (P&L 3.9)
The time four CWIPs are in operation during pump swaps should be limited to approximately two minutes. (P&L 3.20)
Verifies Circulating Water System operation 3 sets of intake and discharge pumps operating.
(May call U1UI to verify U1 UI Circ Water alignment)
Verifies mean sea level greater than 0 feet indicated on INTAKE/DISCHARGE SCW-LR CANAL LEVEL recorder, SCW-LR-285/CW-LR-761, or Computer Point, L125.
Notifies Radwaste of pending CWIP shift to ensure proper operation of Chlorination System.
Recognizes power reduction to 90% is required and is met.
Ensures RW Radioactive Release is not occurring and that routine CWIP shift will not impact release.
EVENT 2 CWIP SHIFT BOP Time Action Notes Ensures RO monitors reactor recirculation pump speeds during CWIP start.
Places CWCWISOL ISOL VALVES MODE SELECTOR switch in position D.
Monitors water box outlet valve positions. (4 Pump Only light lit)
Starts 2C CWIP.
Makes PA announcement Contact OS AO for proper start Stops 2B CWIP Makes PA announcement Contact OS AO for proper stop Ensures condenser vacuum is being maintained in the normal operating range.
Places CWISOL VALVES MODE SELECTOR switch in position C.
Monitors water box outlet valve positions (April requires "e")
C)
May use PPC Screen # 405 LOCA Load Shed should already be enabled on 2A CWIP and was not Enabled for 2C CWIP Informs SRO CWIP shift is complete, 2B CWIP is shutdown.
EVENT 3 EVENT INADVERTENT HPCI INADVERTENT HPCI INITIATION INITIATION HPCI will inadvertently HPCI inadvertently initiate.
initiate. The crew crew will respond respond per per AOP-03.0 AOP-03.O and terminate HPCI HPCI operation.
Objectives:
2AOP-03.O entry SCO - Directs 2AOP-03.0 Address Technical Specifications for HPCI inoperability RO - Diagnose inadvertent HPCI initiation and terminate HPCI operation.
Success Path:
HPCI operation terminated and TS addressed Simulator Operator Actions:
oD When directed by lead examiner, initiate Trigger 1I to initiate HPCI.
oD If contacted as I&C l&C to investigate, acknowledge the request oEl If contacted as NE, positive reactivity event and thermal limits will be evaluated.
oi If contacted as Chemistry for Reactor Coolant Sample for fuel failure, acknowledge the request o When directed by the lead examiner, proceed to the next event.
El Required Operator Actions 2AOP-03.O, Positive Reactivity Addition and terminate HPCI Instrument Failure - Enter 2AOP-03.0, operation.
SRO Time Action Notes 2AOP-03.O Direct entry into 2AOP-03.0 Direct termination of HPCI operation Direct reduction of reactor power if necessary Directs BOP to monitor the plant.
Contact I&C to investigate HPCI failure May May contact Chemistry to sample Rx Coolant for fuel failure.
Refer to Tech Spec Spec 3.5.1.
3.5.1. Determine Actions Dl D1 (Immediately verify RCIC operability) operability) and and D2 D2 (Restore HPCIHPCI within 14 days) 14 days) apply.
EVENT3 EVENT 3 INADVERTENT HPCI INITIATION RO Time Action Notes Notes Diagnose and report inadvertent HPCI Diagnose HPCI initiation AOP-03.O, Positive Enter and announce AOP-03.0, Reactivity Addition Verify by two independent methods the initiation is not valid or adequate core cooling is ensured Terminate HPCI operation i.Depress and hold the HPCI turbine trip push 1.Depress button.
2.When HPCI Turbine Speed is 0 RPM, and the HPCI Turbine Control Valve, E41-V9 is closed, place the HPCI Auxiliary Oil Pump Control Switch in the Pull To Lock position.
3.When the HPCI Turb Brg Oil Press Lo annunciator (A-01 4-2) is alarming, release the HPCI turbine trip push button.
4.Verify the HPCI Turbine Stop Valve, E41-4Verify V8, and HPCI Turbine Control Valve, E41-V9, remain closed and the turbine does not restart.
Responds to the following alarms: A-iA-1 HPCIFLOWLO 1-4 HPCI FLOWLO 3-5 HPCIISOL HPCI ISOL TRIP S/GSIG A INITtA INITIATED TED 4-i 4-1 HPCI TURB TRIP SQL ENER SOL 3-i HPCI TURB TRIP 3-1 5-3 HPCI VACUUM TANK LVL HI Notifies SRO HPCI operation has been terminated and whether injection did or did not occur.
(Flow indication on flow controller with injection valve open == Injection)
Notifies the duty Reactor Engineer.
BOP Time Action Notes Monitors the plant and Reduces power if directed by SCO May May announce AOP-03.O, AOP-03.0, Positive Reactivity Addition, entry Monitors for power oscillations LPRMs, SRM5,SRMs, SRM Period, APRMs
EVENT 4/5 415 2A CSW PUMP TRIP/2C TRIP! 2C CSW PUMP AUTO START FAILURE CSW Pump 2A will trip on over current. CSW header pressure will lower below 40 psig. CSW Pump 2C20 will fail to auto start. The crew will respond per AOP-1 AOP-19.0 9.0 and manually start CSW Pump 2C. CSW header pressure will recover.
Objectives:
Soc SCO Directs OAOP-19.0 entry Address Technical Specifications for CSW pump inoperability BOP Diagnose CSW pump failures and manually start 2C 20 CSW pump.
Success Path:
20 CSW manually started restoring CSW header pressure.
2C Simulator Operator Actions:
oLi When directed by lead examiner, initiate Trigger 2 to initiate 2A CSW pump trip.
oLI If contacted as I&C, l&C, Maintenance, or OS AO to investigate, acknowledge the request oLI When directed by the lead examiner, proceed to the next event.
Required Operator Actions Component & Instrument Failure - Enter OAOP-19.0, Conventional Service Water System Failure and manually start 2C20 CSW pump.
SRO Time Action Notes Direct entry into OAOP-19.0, Conventional Service Water System Failure 20 CSW pump Direct manually starting 2C Contacts maintenance for 2A CSW trip 20 CSW auto start failure.
and 2C Refer to Tech Spec 3.7.2 Service Water BASES: The SW System is considered (SW) System and Ultimate Heat Sink OPERABLE when it has two OPERABLE CSW pumps (specifically the CSW 2A and CSW 2C (UHS). pumps), three site NSW pumps (any combination Determine Actions C1 Cl (Immediately Verify 1 and Unit 2 NSW pumps), and an of Unit 1 the one OPERABLE CSW pump and one OPERABLE flow path capable of taking suction OPERABLE Unit 2 NSW pump are from the intake structure and transferring the water to the ECCS equipment and the DGs. For a CSW powered from separate 4.16 kV pump to be considered OPERABLE, it must be emergency buses) capable of supplying the CSW header and the NSW header. The CSW 2A and CSW 2C pumps and must be OPERABLE to ensure that two pumps can supply the CSW header with one specific postulated single failure, Loss of Division II power.
02 (Restore required CSW pump to C2 This failure disables both the flow path from the OPERABLE status within 7 days) apply. NSW header to the RHRSW pumps and it disables the CSW 2B pump.
415 EVENT 4/5 2A CSW PUMP TRIP/2C TRIP! 2C CSW PUMP AUTO START FAILURE RO Time Action I Time IMonitors Action the plant Notes I Notes BOP Time Action Notes Acknowledges & reports UA-01 annunciator:
CONVHDR 1-9 CONV SERVWA HDR SERV TER PRESS-LOW WATER Diagnose and report trip of CSW Pump 2k 2A.
Enter and announce OAOP-19.0, Conventional Service Water System Failure Contacts Outside AO AC to investigate Contacts I&C to investigate Contacts Maintenance to investigate Recognizes 2C CSW pump auto start failure and manually starts pump.
Note: Pump may be manually started lAW APPorAOP.
APP or AOP.
If conventional service water header pressure remains below 40 psig for 70 seconds, then the SW-V3 & V4 close to a throttled position. (Reduced TBCCW cooling, AOP-17.0 entry)
Note: If SW-V3 or V4 throttles, CSW header will restore. Once 2C CSW pump is started, these valves are re-opened lAW AOP-1 AOP-19. 9.
EVENT 6/7/8 61718 RWCU Leak - 77' 77 RB, MCC 2XC LOSS, G31-F004 FAILURE A line rupture will develop in the RWCU system in the 77' 77 elevation. MCC 2XC will de-energize due to fault (loss of power to G31-F001) and G31-F004 will thermally trip. OAOP-OS 0AOP-05 will be entered and the 77' 77 elevation temperature and radiation levels will rise requiring a manual scram.
(SOUTH CS RM FLOOD LEVEL HI alarms 10 minutes, followed by SOUTH CS RM FLOOD LEVEL HI-HI at 14 SOUTHRHRRMFLOODLEVEL minutes, and SOUTH RHR RM FLOOD LEVEL HI at 17 minutes without cooling down.)
Objectives:
SCO Directs OAOP-S.O 0AOP-5.0 entry Directs EOP-03-SCCP entry Directs Reactor Scram with Unisolable Primary leak in Secondary Containment BOP AOP-05 actions Perform AOP-OS RO Diagnose RWCU rupture and isolation failure Success Path:
Manual reactor scram inserted prior to reaching Max Safe Operating Temp or Level Simulator Operator Actions:
oLi When the crew has stabilized the plant after the CSW failure and directed by lead examiner, initiate Trigger 3 to start the RWCU rupture oLi When Rx Bldg ARM alarms, report as RBAO steam on SO' 50 elevation and you have left the building o If requested to close PIV-33, wait 3 minutes and report closed oLi If contacted as Engineering, Chem, HP, Maintenance, I&C, l&C, OSAO, acknowledge report oLi When directed by the lead examiner, proceed to the next event.
Required Operator Actions Major - Enter OAOP-05.0, OAOP-OS.O, Radioactive Spills, High Radiation, And Airborne Activity and upon recognition of RWCU isolation not available insert reactor scram.
SRO Time Action Notes Direct entry into AOP-05.0 AOP-OS.O Enter and direct EOP-03-SCCP Direct verification of auto actions RB Vent Exh rise above 4mrlhr 4mr/hr - RB HVAC isolations and SBGT auto start.
Direct evacuation of the reactor building Diagnose leak from RWCU and direct RWCU isolation
EVENT 6/7/8 EVENT 61718 RWCU RWCU Leak - 77' RB, Leak77 RB, MCC MCC 2XC 2XC LOSS, LOSS, G31-F004 G31-F004 FAILURE FAILURE SRO Time Action Notes Direct RHR room coolers be started Direct service water aligned to the vital header Evaluate Level instrument operability using Caution 1I mop with Temperature on Range.-- N026s inop (Wide Range the Reactor Building 50' 50 above 140°F)
Contact engineering to perform EQ evaluation Direct Direct manual manual Scram Scram prior prior toto Max Max Safe Safe Temperature or Level.
RO Time Action Notes Monitors the plant Diagnose RWCU leak and attempt to manually isolate, Recognize and report RWCU inboard valve failure - Loss of MCC 2XC inability to isolate RWCU Recognize and report RWCU outboard valve failure and inability to isolate RWCU A-2 5-5 OTBD NSSS VALVES MTR OVERLOAD Align service water to the vital header (SW-V1 17 or SW-V1 (SW-V117 SW-V111) 11) if not already done BOP Time Action Notes Notes Acknowledge and report UA-03 UA-03 2-7 AREA RAD RX BLDG HIGH
EVENT 6/7/8 EVENT 61718 RWCU Leak Leak - 77' 77 RB, RB, MCC 2XC LOSS, LOSS, G31-F004 FAILURE BOP BOP Time Action Notes Enters and announce AOP-05.0 entry Evacuates the U2 Reactor building.
Sounds RB evacuation alarm Verifies Secondary Containment and Group 6 isolation and SBGT initiation if Rx Bldg Vent exhaust Hi-Hi rad alarms I Directs PIV-33 to be closed Ensures the RHR room coolers are running May Align service water to the vital (SW-V1 17 or SW-V111) header (SW-V117 SW-V1 11) if not already done due to FAN CLG UNIT CS PUMP RM A INL PRESS LO annunciator Monitors Reactor Building pressure, reports if pressure goes positive.
(Blue bar annunciator RX BLDG STA STATIC TIC PRESS DIFF-LOW)
Acknowledges & reports UA-17 3-2 SUB E7 FOR FDR TO MCC-2XC BKR TRIP 00 1-50.3 for loss of loads.
- 1. May refer to 001-50.3
- 2. Should not direct Auxiliary Operator to the Reactor Building to check for fault(s) in MCC-2XC.
- 3. May direct Auxiliary Operator to Substation E7, Breaker AYO, to check for fault(s).
- 4. May contact maintenance to investigate.
Notifies E&RC to perform the following as necessary:
- Area radiation survey
- Air sampling
- Smear survey
- Post the affected area as necessary
- Control access to reduce exposure and contamination.
Recognize and report to SRO alarms A-2 A-26-8 6-8 RB 50/20 50120 ft Temp Hi.
UA-122-3 UA-12 2-3 SOUTH CS RM FLOOD LEVEL HI UA-121-3 UA-12 1-3 SOUTH CS RM FLOOD LEVEL HI-HI
EVENT 9/10/11 EVENT 9110111 REACTOR SCRAM, REACTOR SCRAM, RCIC RCIC Failure, Failure, 202D Bus Bus A Manual A Manual Scram Scram isis inserted inserted prior prior to to reaching reaching thethe Maximum Maximum Safe Safe Operating Operating Temperature Temperature or or Level. When Level. When the the turbine tripped, BOP turbine isis tripped, BOP BusBus 2D2D will will fail fail to to auto auto transfer transfer to the SAT.
to the SAT. DG3DG3 will will auto start and energize E3.
and energize E3. DG1 DGI will autoauto start start on on Loss Loss BOPBOP Bus Bus 2D 2D with UAT UAT de-energized.
de-energized.
Loss of BOP Loss BOP Bus Bus 2D will require require entry entry into into OAOP-36.1 0AOP-36.1 and and causes aa loss loss of FW FW injection.
injection.
Reactor water level Reactor level will drop due to the inventory inventory loss loss through the leak.
leak. IfIf level drops to the LL2 LL2 initiation, RCIC initiation, RCIC will failfail to auto initiate, to auto initiate, but but can can bebe manually manually started.
started. With With RCIC RCIC injection injection maximized, LEP-01 maximized, LEP-01 alternate alternate coolant coolant injection injection systems, systems, along along with with SEP-09 SEP-09 CRD CRD flow flow maximized (RB inaccessible) RPV level will be maintained above TAF.
Objectives:
Objectives:
Directs manual Reactor SCO - Directs
- Reactor Scram Enters RSP, Enters RSP, RVCP BOP - Diagnose Bus 2D fails to transfer Enters AOP-36. 1.
RO - -
Diagnose RCIC auto start failure Execute AOP and EOP actions as directed by SRO Perform SCRAM actions Control reactor parameters post SCRAM Success Path:
Maintain RPV water level above LL4 and depressurizing the RPV.
Simulator Operator Actions:
oLi If contacted as I&C, Maintenance, or OS AO AC to investigate, acknowledge the request LIo If contacted as AC AO for SEP-09 or LEP-01, LEP-Ol, wait 2 minutes and report Reactor Building is inaccessible per RP.
o contacted as AC Li If AO to restart RPS A, wait 2 minutes and initiate batch file to restart RPS A RPSA oLi If contacted as Unit 1I SRO to perform PEP-3.4.7, acknowledge request.
o When directed by the lead examiner, proceed to the next event.
Li Required Operator Actions Major - Enter RSP and RVCP, perform alternate coolant injection and CRD flow max, anticipate and or ED.
SRO SRO Time Action Notes Notes Before South Core Spray reaches max safe level, safe level, directs aa manual manual reactor scram scram Enters and Enters and directs directs EOP-01-RSP EOP-01-RSP IfIf reactor reactor building building loses loses negative negative pressure, pressure, enter enter and and execute execute RRCP RRCP forfor unmonitored unmonitored release, release, andand request request field field surveys surveys
9110/11 EVENT 9/10/11 REACTOR SCRAM, RCIC Failure, 20 2D Bus SRO Time Action Notes Directs entry into OAOP-36.1 for loss of Bus 2D Determines entry into EOP-01-RVCP is required Directs verification :
- . Group Isolations
- . ECCS Initiations
- . Diesel Generator Auto Starts Directs restoring and maintaining reactor water level between +170 and +200 inches with one or more of the systems listed in Table 1I
- . CRD (SEP-09)
Directs starting RCIC to maintain level May direct utilizing SLC aligned to Demin (LEP-Ol).
Water (LEP-01).
May direct restoring RBHVAC per SEP-SEP 04 Directs commencing normal cooldown not 100°F!
to exceed 100° F / hr Directs Anticipating Emergency Depressurization Cautions not to close MSIVs (Gp1)
(Gpl)
9110111 EVENT 9/10/11 REACTOR SCRAM, RCIC Failure, 20 2D Bus RO Time Action Notes Inserts a manual scram as directed by SRO Performs scram immediate actions:
- 1. Unit 2 Only: After steam flow is less than 3 x 106 Ib/hr, PLACE the reactor mode switch to Ib/hr, SHUTDOWN.
- 2. IF reactor power is below 2% (APRM downscale trip), THEN TRIP the main turbine.
- 3. ENSURE the master reactor level controller
+170.
setpoint is +170".
- 4. IF two reactor feed pumps are running, and
+160 and rising, reactor vessel level is above +160" then trip one.
Maintains RPV level 170-200"170-200 Reports when out of band and actions to address recovery.
Diagnoses loss of Feedwater flow to RPV Diagnoses RCIC failure to auto start Manually starts RCIC to maintain RPV level Performs SEP-09, CRD Flow Maximization with procedure or Hardcard.
May request SLC aligned for DW injection lAW LEP-Ol.
LEP-01.
Rx Bldg is inaccessible.
Recognizes and reports no direct RPV level indication available below 150 150" w/
wi RR pumps operating.
Trips Recirc pumps if directed by SCO Should have tripped at LL2.
Commences normal cooldown not to exceed 100° 100 FF I hr Utilizing BPVs 0
Anticipates ED Opens BPVs with the BPV Opening Jack maintaining Steam Flow below isolation setpoint.
Does not to close MSIVs (Gpl)
(Gp1)
9110111 EVENT 9/10/11 REACTOR SCRAM, RCIC Failure, 20 Bus BOP Time Action Notes Diagnoses loss of Feedwater flow to RPV Enters and announces AOP-36.1 Dispatches an AO to monitor DGs Dispatches an AO to investigate Bus 2D Verifies air compressor alignment May place 2C TBCCW pump in service on U2.
May direct AO to restart RPS MG set.
Verifies CWIPs in service and maintains main condenser available.
SPE and steam seals Recognize and report to SRO alarms A-2 6-8 A-26-8 50/20 ft Temp Hi.
RB 50120 UA-12 2-3 SOUTH CS RM FLOOD LEVEL HI UA-122-3 UA-12 1-3 SOUTH CS RM FLOOD LEVEL UA-121-3 HI-HI May perform SCRAM Hardcard actions.
- 1. Ensure Scram Valves Are Open By Manual 1.
- 2. Control Reactor Pressure Between 800 BOO and 1000 psig 1000
- 3. Control Reactor Water Level Between +170 and
+200 Inches
- 4. Place SULCV in Service
- 5. Insert Nuclear Nuclear Instrumentation
- 6. Ensure Turbine Oil System Operating
- 7. Place Recirc Pump Speed Controllers to 10%
10%
and Ensure Pump Speed Lowers Heater Drain Pumps Tripped B. Ensure Heater 8.
EVENT 12 REACTOR DEPRESSURIZATION Area temperatures and water levels will rise. South Core Spray will exceed Max Normal, then Max Safe Operating Water Level. Then South RHR will exceed Max normal then Max Safe Operating Water Level. The crew is directed to consider anticipating emergency depressurization as soon as EOP-03-SCCP directs inserting a manual scram. If the crew does not anticipate emergency depressurization (rapid depressurization to the main condenser) a second area will exceed Max Safe Operating Water Level requiring Emergency Depressurization.
Depressurization may be Anticipated or manually performed when two area exceed Max Safe.
Objectives:
SCO Directs actions Emergency Depressurization and restoration of reactor water level.
RO Performs actions for emergency Depressurization and restoration of reactor water level.
BOP Monitors and reports RB Flood level alarms.
Success Path:
Restore reactor water level to 170-200 inches.
Simulator Operator Actions:
nstructor Activities Instructor oC If crew decides not to anticipate ED, after S RHR Flood Hi has alarmed, 3 minutes later verify Trigger 6 activates to override S RHR Flood Hi-Hi alarm oC When RPV level is being controlled above 170",170, the scenario may be terminated oC When directed by the lead evaluator, place the simulator in FREEZE.
Required Operator Actions Restore and maintain RPV level above LL4 SRO Time Action Notes If two areas exceed MSOWL, direct emergency depressurization Directs controlling condensate injection when RPV pressure is less than 440 psig.
(may require closing FW isolations due to power loss)
Directs controlling Low Pressure ECCS injection when RPV pressure is less than 400 psig
EVENT 12 EVENT 12 REACTOR DEPRESSURIZATION REACTOR IEPRESSURIZATION SRO Time Action Notes Notes Directs opening 7 ADS valves (ED)
Directs restoring and maintaining RPV level 170-200 inches.
RO/BOP RO/SOP Time Action Notes Recognize/report S RHR Flood level Hi (and Hi-Hi if alarms)
Places 7 ADS valve control switches Operates LP ECCS to restore and level 1 70-200 inches.
maintain RPV /eve/170-200 Termination Cue When RPV water level is being maintained above 170 inches with the reactor depressurized, by direction of the Lead examiner, the scenario may be terminated.
Simulator Operator Simulator Activities:
Operator Activities:
WHEN directed WHEN directed by the lead by the lead examiner, examiner, place place the the simulator simulator in in FREEZE.
FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER
PROGRESS ENERGY CAROLINAS BRUNSWICK TRAINING SECTION SIMULATOR SCENARIO 2010-1 NRC Exam Scenario #3
Appendix D D Scenario Outline Scenario Outline Form ES-D-1 Form ES-D-1 Facility: Brunswick Facility: Brunswick Scenario #: 2010-1 #3 Scenario OP-Test No.:
OP-Test No.: Draft Draft Examiners:
Examiners: Operators:
Operators:
Initial Conditions: The plant is operating at -50% power during startup following a refuel outage. No equipment is out of service Turnover: Following shift turnover, raise power to 60%, perform alternate power verification and prepare to place the second feed pump in service.
Eventent MaIf. No.
Malf. Event Event No. o. Type*
Type* Description 1I N/A R-BOP Raise power to 60%
R-SRO 2 N/A N-SRO Perform verification of Reactor Power level using Alternate N-BOP Indications 3 EEO3OM EE030M C-BOP Main Stack Rad Monitor power failure. (TS)
C-SRO 4 K451 7A K4517A C- BOP C-BOP 2B TCC Pump trip C- SRO C-SRO 5 P2740A1 I P2740A11 C- RO C-RO 2B Recirc Pump speed control failure (TS)
C- SRO C-SRO 6 MSO31 F MS031F 1-BOP I-BOP MTLO controller failure I-SRO 7 MSO17F MS017F M-ALL Turbine high vibration requiring turbine trip and scram resulting in an ATWS ATWS condition requiring entry to LPC.
8 K21 19A K2119A C-RO SLC pumps will not start due to switch failure.
Off C-SRO 99 RDO36F RD036F C-RO Scram discharge volume vents and drains fail closed.
C-SRO 10 10 All Rods In
- (N)ormal, (R)eactivity, (R)eactlvlty, (l)nstrument, (I)nstrument, (C)omponent, (M)ajor (M)aJor Page Page 22 of of 28 28
SCENARIO DESCRIPTION SCENARIO DESCRIPTION Unit 22 is Unit is operating operating atat -50%
50% power power during during startup startup following following aa refuel refuel outage.
outage.
Event 11 Event Continue with Continue with startup startup to to 60%
60% power power using using recirc recirc flow.
flow.
Event 22 Event Performs aa verification of reactor Performs reactor power power level level using using alternate alternate indications indications per per OGP-04 0GP-04 Attachment 1. 1.
Event 3 Event Power to Power Main Stack to the Main Stack Rad Rad Monitor Monitor will bebe lost.
lost. The power power results results in in Group 6 isolation and Secondary containment.
and Secondary containment.
Event 4 Event TCC Pump 2B will trip and TBCCW low low header header pressure will alarm. The crew will respond perper OAOP-17.0 and place 2C TBCCW pump pump in service.
Event 5 2B Recirc Pump control speed will fail resulting in lowering reactor power. The crew will respond per OAOP-03.0 and lock the scoop tube.
Event 6 The main turbine lube oil controller will fail closed causing the lube oil to heat up and vibrations to occur on the main turbine. This will require the main turbine to be tripped
(>12 mils on bearing 1-8 and >10 mils on bearings 9/10) and the reactor to be scrammed.
Event 7 Most control rods will fail to insert on the scram. The crew will respond to the ATWS per EOP-01-LPC.
Event 8 When SLC initiation is attempted, neither SLC pump will start due to switch failure.
The crew will enter LEP-03 and align for alternate boron injection using CRD.
Event 9 9 When scram jumpers are installed the scram discharge vents and drains will fail to open which will result in inability to insert control rods by resetting RPS and inserting additional manual scrams.
Event 10 When level has been lowered and level band has been established, the scram discharge volume vents and drains will be repaired. Control rods can then be inserted by manual scram. When all control rods are inserted and level is being maintained 170 170 to 200 inches the scenario may be terminated.
Page Page 3of28 3 of 28
Simulator Setup Initial Conditions:
IC ENP-24.5 for IC 9 Rx Power 60%
Core Age EOC Events:
I Event#
Event # Trigger Description 3 11 Manual Main Stack Rad Monitor Power Failure 4 2 Manual Trip 2B TBCCW Pump 5 3 Manual MTLO controller failure Turbine high vibration causing the crew to scram the plant with an 6 4 Auto ATWS condition 8 NA SLC switch failure 9 5 Auto Scram Discharge Vents and Drains fail closed Malfunctions Summary Shaded entries arefActive are Active Mult . Current Target Ramp Act. Deact MaIf. ID Malf.ID Description Trig ID 10 Value Value Time Time Time RPOIOF RP010F ATWS 3 ATWS3 True True RDO36F 5 - on RD036F Scram Disc Vol Drn Fails Closed False True Scram MSO31 F MS031 F MTLO Temp Cntrlr Fails False True 3 MSO17F Auto on MS017F 4 Turbine Bearing Vibration 0 5 5 mm 5min UA231-6 MSO17F Auto on MS017F 5 Turbine Bearing Vibration 0 5 mm 5 min UA231-6 Auto on MS017F 6 Turbine Bearing Vibration 0 5 mm 5 min UA231-6 MSO08F MS008F Main Turbine Trip False True 6 RPOO5F RP005F Auto Scram Defeat False True 7 R emo es S Remotes ummary Summary ID Mult. . . Current Target Remote 10 ID Description Trig 10 Value Value EP_IAEOPJPI EP IAEOPJP1 Bypass LL3 Group II Isol Off On 8 MS_VMS5005D MS VMS5005D MVD-5005 Mn Stm Drn Hdr Isolation 0 1 1 9 EP_IACS993U EP IACS993U DW OW CLR A&D Overide - Normal/Run Normal Run 10 10 EP IACS994U DW OW CLR B&C Overide - Normal/Run Normal Run 10 10 EP_1ASW5997 EP IASW5997 SW-V106 LOCA Override Normal Bypass 10 10 EP_1ASW5998 EP IASW5998 SW-V103 LOCA Override Normal Bypass 10 10 ED_IAUPB2A6 ED IAUPB2A6 UPS 2A to Sample Detection Skid Closed Open 1 1
SL_IALEPO3 SL IALEP03 Alt == Sub Pump / Hose Lineup Normal Alt 11 Page4of28 Page 4 of 28
Switches SWI't Ches SSummary ummary Target Override Switch ID ID Description Description .. Trig Position Position Value K4517A K4517A Pump B TBCCW Pump B On Off Off 2 Q4517LG4 TBCCW Pump B Green On/Off OnlOff Off Off 2 K2119A K2119A S/BLig SIB Pump A-B Liq Pump Stop On On K2119A K2119A 5/BLig SIB LiQ Pump A-B Pump A Off K2119A 5/BL1g SIB Liq Pump A-B PumpAB Off K2119A K2119A S/B Liq SIB Jg Pump A-B Pump B Off K6103B SBGT Sys B Pref Off Auto on RFP A Trip K4313A VIv Auto RFP A Recirc Vlv Close Off
=
(Q43164WY true)
Auto on RFP B Trip K4307A RFP B Recirc Vlv RFP VIv Auto Close Off
=
(Q43104WY true)
Special Instructions:
Ensure ENP-24.5 for IC-9 at P603 panel.
Reduce power to -50%
-50% using recirc flow.
Place 2B TCC pump in service.
Verify APRM GAFs are .:s. < 1.00 Mark-up OGP-04, Attachment 1, for 30, 40 and 50% power.
Computer on the Heat Balance page 1.
Have the computer Page 55 of 28
Shift Briefing Plant Status
-5O% power during startup following a refuel outage.
The plant is operating at -50%
GP-04 is complete up to step 5.2.22.
Equipment Out of Service No equipment is out of service Plan of the Day Raise power to 60%, perform alternate power verification and prepare to place the second feed pump in service.
Page 6of28 6 of 28
Scenario Information Scenario Information Critical Tasks Critical (bolded/italicized in Tasks (bolded/italicized in the the required required operator operator action action statements) statements)
CRD.
- Perform LEP-02, Perform LEP-02, Alternate Rod Rod Insertion Insertion using RMCS.
RMCS.
Page7of28 Page 7 of 28
EVENT 1I SHIFT TURNOVER, RAISE REACTOR POWER TO 60%
The crew will complete shift turnover and raise reactor power power to -60%.
60%.
None.
Malfunctions required: None.
Objectives:
Soc - Directs reactor power to be raised using Recirc pump speed control.
SCO -
RO - Performs power increase using recirc flow control.
Success Path:
60% power.
Power is raised to -60%
Simulator Operator Actions:
o Li If contacted as the RE for power increase guidance, inform crew to raise power using Reactor Recirc flow.
o If contacted as the RE to monitor power increase, inform crew that you will monitor Li core performance.
o Li When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity Manipulation - Raise power 10% using recirc pump speed controls.
SRO Time Action Notes 60%
Directs Power to be raised to -60%
power.
RO Time Action Notes Raises power using recirculation flow to 60% power.
-60%
Raise flow on one RR Pump (-2%) (2%)
at a time to stay within mismatch criteria (7.5x106 MIbs 6
(7.5x10 Mlbs jet pump flow if <than
< than 58 MIbs 3.5x1 06 MIbs Mlbs or 3.5x10 6 Mlbs if> than 58 MIbs).
Mlbs).
Continues alternating Recirc pump increases until power is 60%.
-60%.
Verifies operation on the Power to Flow map.
BOP Time I Time IAction Action Plant Monitoring Plant Monitoring I Notes Notes Page 88 of 28
EVENT 22 EVENT REACTOR POWER REACTOR POWER LEVELLEVEL VERIFICATION VERIFICATION USING USING ALTERNATE ALTERNATE INDICATIONS INDICATIONS Performs OGP-04, Performs OGP-04, Attachment Attachment 1, 1, Verification Verification of Reactor Power of Reactor Power Level Level Using Using Alternate Alternate Indications Indications Malfunctions required:
Malfunctions required: None.
None.
Objectives:
Objectives:
seo Soc - Directs
- Directs Verification of Reactor Reactor Power Power Level Level Using Using Alternate Indications.
Indications.
RO - Performs RO - Performs Verification of Reactor Reactor Power Power Level Level Using Using Alternate Indications Indications lAW lAW OGP-04.
Success Path:
Verification of Reactor Power Level Using Alternate Indications within 5% of Heat Balance.
Simulator Operator Actions:
oLi If contacted as the RE to monitor core performance, inform crew that you will monitor core performance on the computer.
oLi When directed by the lead examiner, proceed to the next event.
Required Operator Actions Normal Operations - Verification of Reactor Power Level Using Alternate Indications lAW OGP-04, Attachment 1.
SRO Time Action Notes Directs Verification of Reactor Power Level Using Alternate Indications.
RO ITime Time I Action Action Plant Monitoring Notes I Notes BOP Time Action Notes Notes Performs GP-04 GP-04 Attachment 11 Obtain valid Heat Heat Balance (Display 820) and record heat balance % %
power in power in Table Table 1.1.
Obtain LPRM Obtain LPRM % % PWR PWR (Display (Display 861) 861)
Filtered Filtered LPRM LPRM Readings Edit, and Readings Edit, and record in in Table Table 1.1.
Goes Goes toto step step 44 to to obtain obtain steam steam flow flow
% power.
% power.
Page9of28 Page 9 of 28
EVENT 22 (Cont'd)
EVENT (Contd) REACTOR REACTOR POWER POWER LEVEL LEVEL VERIFICATION VERIFICATION USING USING ALTERNATE INDICATIONS INDICATIONS BOP (Cont'd)
BOP (Contd)
Time Action Time Notes Notes Perform the following at Perform at the prompt prompt on the ERFIS terminal:
Select Screen 6 by typing 6 Select 11 for Normal FW Heater Lineup Record Steam Flow equivalent %
power on Table 11 (from RE program).
Compare the Heat Balance (%) with the other alternate indications (%).
If the heat balance is greater than all alternate indications (conservative as is) OR One or more alternate indications are within 5% of the heat balance (normal acceptance),
Then Power Ascension may continue.
Page Page 10of28 10 of 28
EVENT 33 EVENT MAIN STEAM MAIN STEAM LINE LINE RAD RAD MONITOR MONITOR FAILURE FAILURE Power to the Main Power Main Stack Stack Rad Rad Monitor Monitor will be lost. The power be lost. power results results in in Group Group 66 isolation, isolation, Secondary containment containment Isolation Isolation but but SBGT SBGT fails to autoauto start.
start. The crew crew must must manually manually start start SBGT to maintain SBGT maintain Secondary Secondary Containment Containment integrity.
integrity.
Malfunctions required:
UPS 2A to Sample Detection Skid breaker open.
Objectives:
SCO - Determine actions required for LCO per Technical Specifications.
BOP - Respond to a process radiation monitoring downscale/inop annunciator.
Success Path:
Technical Specification I TRM
- 3.3.6.1 PCIS Instrumentation, determine Function 2c is inoperable, determine actions A and B apply (single channel), then C and F after 11 hour1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />.
- TRM 3.4 Post Accident Monitoring, determine Function 5 is inoperable and condition A applies
- ODCM 7.2 Gaseous Effluent Monitoring, determine function 11 is inoperable and notify E&RC.
- 3.6.4.3 3.6.4.3 SBGT, Determine Condition A Al, 1, restore in 7 days Simulator Operator Actions:
LI Insert Trigger 1I at the discretion of the lead evaluator.
D D
LI Ensure SBGT start when switches are taken to ON.
LI If asked to investigate, report UPS Panel 2A to the Stack Rad Monitor is tripped.
D LI If contacted as I&C D l&C to investigate, acknowledge the request, if asked do not recommend transfer to the alternate power supply until the cause of the trip is investigated.
LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Tech Spec Declaration - 3.3.6.1 condition A and B, TRM 3.4 condition A, ODCM 7.2, and 3.6.4.3 condition Al.A 1.
Page Page 1111 ofof 28 28
EVENT 3 (cont'd)
(contd) MAIN STEAM LINE RAD MONITOR FAILURE SRO Time Action Notes Direct actions of the APPS for the Main Stack Rad Monitor Direct manual start of SBGT.
I/C to investigate loss of UPS 2A.
Direct IIC Refer to Tech Specs.
3.3.6.1, Determine function 2c is inoperable (Condition A and B),
then C and F after 1 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
TRM 3.4 Determine function 5 is inoperable (Condition A, 31 days)
ODCM 7.2, Determine function 1 1 is inoperable and notify E&RC.
3.6.4.3 SBGT, Determine Condition A Al, 1,
restore in 7 days.
RO Time Action Notes Monitoring Plant Monitoring.
SW-Vl 11 or V117 May open the SW-V111 Vi 17 to supply cooling water to the vital header lAW 2APP-UA-05 1-9 or 2-9.
Page 12 of 28
(contd)
EVENT 3 (cont'd) MAIN STEAM LINE RAD MONITOR FAILURE BOP Time Action Notes Report loss of Main Stack Rad Monitor.
UA-03 5-4, PROCESS OG VENT PIPE RAD HI-HI 6-3, PROCESS SMPL OG VENT PIPE DNSC/INOP 6-4, PROCESS OG VENT PIPE RAD - HI UA-05 3-5, SBGT SYS B FAILURE 4-6, SBGT SYS A FAILURE 6-10, RX BLDG ISOLATED Report TS review for the SCO from the Annunciator reviews.
- . 3.6.4.3
- . 3.3.6.1 Table 3.3.6.1-1, Function 2C
- . ODCM 7.3.2 Table 7.3.2-1 Function 1, 7.3.7, and 7.3.13
- . TRM 3.4, Table 3.4.2 Function 5 Determine SBGT Train B did not auto start and manually start Dispatch AO to investigate UPS 2A condition.
May open the SW-Vi 11 or Vi SW-V111 17 to V117 supply cooling water to the vital header lAW 2APP-UA-05 1-9 or 2-9.
Page 13 13 of 28
EVENT 4 TBCCW PUMP B B TRIP TCC Pump 2B will trip and TBCCW low header pressure will alarm. The crew will respond per OAOP-17.0 and place a TBCCW pump in service Malfunctions required:
Trip of 2B TCC pump Objectives:
SCO - Direct entry into OAOP-1 Soc 7.0.
OAOP-17.0.
RO - Restoration of TOO TCC pressure Success Path:
2C TBCCW pump started and TOO 20 TCC pressures restored to normal.
Simulator Operator Actions:
oLI Insert Trigger 2 at the discretion of the lead evaluator.
oLI If contact as the TB AC, TCC pump is hot to the AO, wait one minute and report that 2B TOC touch and the breaker is tripped.
o LI If contacted as Unit One CRS,ORS, report Unit One is not using the 20 TOO Pump.
2C TCC o
LI Acknowledge request as I&C I&O to do troubleshooting/repair for the 2B TOO TCC Pump.
oLI When directed by the lead examiner, proceed to the next event.
Required Operator Actions SRO Time Action Notes Direct entry into OAOP-17.0.
TOO Pump.
Direct start of a TCC TOO I/O to investigate loss of 2B TCC Direct IIC pump.
RO Time Action Notes I Time ! Action Monitoring Plant Monitoring.
! Notes Page 14 of 28
(Contd)
EVENT 4 (Cont'd) TBCCW PUMP B TRIP BOP Time Action Notes Report loss of 2B TCC Pump and refer to APPs.
2APP-UA-03 (2-4) TBCCW PUMP DISCH HEADER PRESS LOW Enter OAOP-17.0.
OAOP-17.O.
Dispatch AOAC to investigate 2B TCC Pump condition.
May dispatch AOAC to perform prestart checks for 2A or 2C TCC Pump.
Starts a TCC pump. (May start two pumps)
(Depending on the amount of time that no TCC pump is operating, one pump may not immediately restore TCC pressure due to the system loads TCC temperature control valves being wide open.)
If needed, Verify Unit One is not using 2C TOO pump and start pump.
TCC Page 15 15 of 28 28
EVENT 5165/6 MTLO CONTROLLER FAILUREITURBINE VIBRATIONS HIGH Malfunctions Required:
Main Turbine lube oil cooler controller fails closed. When high temperature alarm annunciates activate trigger to accelerate turbine vibrations.
Objectives:
Respond to an abnormal turbine vibration per UA-23 6-1 and UA-23 6-3.
Success Path:
The MTLO MTLC controtler controller on XU-2 indicates 100%
100% output (full closed) and turbine lube oil temperature will rise. Dispatch AC AO and I&C to investigate.
Simulator Operator Actions:
o At the discretion of the lead evaluator, insert Trigger 3 to fail the MTLO controller Li closed.
LIo If asked as the TB T8 AC AO to investigate, report that the temperature control valve to the MTLC is closed. (There is no bypass valve).
MTLO oLI Verify turbine vibrations on 4, 5, and 6 begin to rise after receiving UA-23 1-6.
oLi If asked as I&C to investigate acknowledge the request.
oLi When directed by the lead examiner, proceed to the next event.
Required Operator Actions SRC SRO Time Action Notes Direct actions of APPs.
APP's.
When vibrations rise to above the TSI setpoint, direct manual scram and turbine trip per the vibration APP.
(12 mils on bearings 1-8, 10 mils on bearings 9-10)
(As conservative decision making may insert before setpoint).
RC RO Time Action Notes Monitoring Plant Monitoring.
SRC, insert a When directed by the SRO, manual scram and trip the main turbine.
Recognize and report an A ATWS.
TWS.
Page 16 of 28
EVENT 5/6 EVENT 516 (Cont'd) MTLO CONTROLLER (Contd) MTLO CONTROLLER FAILURE/TURBINE FAILUREITURBINE VIBRATIONS VIBRATIONS HIGH HIGH BOP BOP Time Time Action Action Notes Notes Recognize and Recognize and report report rising rising lube lube oil oil temperatures.
temperatures.
Dispatch TB AO Dispatch AC to investigate investigate TCV.
TOy.
Perform actions of APPs Perform APPs UA-23 1-6 TURB OR RFP 1-6 REP BRG BRG TEMP HIGH HIGH 6-1 TURBINE VIBRATION HIGH 6-3 TSIHIGH VIBRATION TRIP Monitor turbine bearing temperatures and vibrations (PC display 630).
May place the Main Turbine Lube Oil controller in manual and attempt to operate the valve.
Page Page 1717 of of 28 28
EVENT 7/8718 ATWS ACTIONS Most control rods will fail to insert on the scram. The crew will respond to the ATWS A TWS per EOP-EOP O1-LPC. When SLC initiation is attempted, neither SLC pump will start due to switch failure. The 01-LPC.
crew will enter LEP-03 and align for alternate boron injection using CRD Malfunctions Required:
Scram discharge volume vents and drain fail closed on the scram.
SLC switch is failed in the off position.
Objectives:
SCO - Direct actions for a reactor scram per EOP-01-RSP.
Direct actions to control reactor power per EOP-01-LPC.
RO/BOP - Perform immediate actions for a reactor scram.
RO/SOP Perform actions for an ATWS EOP-O1-LPC.
ATWS per EOP-01-LPC.
Success Path:
SRVs. Performs actions of LPC, recognizes failure Controls reactor pressure using the SRV's.
of SLC and performs alternate boron injection.
Simulator Operator Actions:
LI If crew does not trip the main turbine by the time SLC initiation is directed, initiate D
Trigger 6 to trip the main turbine.
LI If requested to perform alternate boron injection using CRD, acknowledge the D
request. (will be performed after RPV injection is re-started)
LI Acknowledge request as I&C to investigate failure of SLC.
D LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions SRO Time Action Notes Enter RSP and transition to LPC.
Direct mode switch to shutdown when steam flow << 3 Mlbs/hr.
Direct ARI initiation.
Direct Recirc Pump speeds reduced to 10%.
Direct Recirc Pumps Tripped.
Page 18 of 28
718 EVENT 7/8 ATWS ACTIONS SRO Continued Time Action Notes Direct SLC initiation.
Direct LEP-03, Alternate boron injection.
Direct ADS inhibited.
Direct RWCU isolation.
Direct LEP-02, Alternate Rod Insertion.
BOP Time Action Notes Places ADS in inhibit.
Isolates RWCU.
Closes RWCU Outboard Isol Valve G31 -F004.
G31-F004.
RO Time Action Notes Place mode switch to shutdown when 3x10 6 Ib/hr.
steam flow << 3x10 6 lb/hr.
Initiates ARI.
Places Recirc Pump speeds reduced to 10%.
Trips Recirc Pumps.
Initiates SLC.
Recognizes failure of SLC and reports to SCO.
19 of 28 Page 19
718 EVENT 7/8 ATWS ACTIONS RO (cont'd)
(contd)
Time Action Notes Performs LEP-03, Alternate Boron Injection.
Direct AO to perform LEP-03, Section 1, Alternate Boron Injection using CRD.
Performs LEP-02, Alternate Rod Insertion. (RMCS Section)
Insert IRMs.
When < range 3 on IRMs insert SRMs.
Start both CRD pumps.
Place CRD Flow Controller to Manual.
Throttle open flow controller to establish ~
> 260 drive water psid.
Bypass RWM.
Selects control rods and drives in using Emerg rod in notch override.
Performs alternate rod insertion per LEP-LEP 02 Section 3.
Request jumpers for LEP-02 Section 3.
Page 20 of 28
EVENT 8/9 EVENT 819 ATWS ACTIONS ATWS ACTIONS - CONTINUED
- CONTINUED The crew will The crew will terminate terminate and prevent injection, and prevent injection, re-injection re-injection will will start start when level is when level is at at 90 90 inches inches due due to table 3 conditions to table 3 conditions not met. not met. IfIf RFPs REPs are tripped they are tripped will be they will be unavailable unavailable forfor level control as level control as the the Recirc Valves Recirc Valves will will fail fail in in the closed position the closed position not not allowing allowing the the RFPs REPs to to be be restarted.
restarted. HPCIHPCI will will be be available for available for level level control.
control.
Objectives:
Objectives:
SOC Direct actions to lower reactor vessel level SCO - Direct level when the conditions of of Table 33 are notnot met met per per EOP-01 -LPC.
ROIBOP - Control reactor level during an A RO/BOP ATWS TWS per EOP-01 LPC.
Success Path:
Success Continues actions in the LPC procedure, terminate and prevent prevent injection, injection, drive rodsrods using using RMCS.
Simulator Operator Actions:
oEl If requested to defeat Group II LL3, wait 2 minutes, initiate Trigger 8 and inform the SCO that the jumpers are installed.
o If requested to install LEP-02, Section 3 jumpers, wait until level has been terminated and prevented or 5 minutes whichever is longer, insert Trigger 7 and inform the SCO that the jumpers are installed.
oEl If requested as I&C to investigate the failure of the scram discharge volume vents and drains, acknowledge the request.
oLI If requested to open the MVD-5005, wait 5 minutes, initiate Trigger 9 and inform the control room that the valve is open.
o Li If requested to defeat Drywell Cooler LOCA Lockout, wait three minutes, initiate Trigger 10 and inform the SCO SOC that the jumpers are installed.
o LI When injection to the RPV has been re-established and if requested to line up boron to the CRD system initiate Trigger 11.
LIo When directed by the lead examiner, proceed to the next event.
Page 21 Page 21 of28 of 28
EVENT 8/9 EVENT 819 CONTINUED ATWS ACTIONS - CONTINUED Operator Actions Required Operator SRO SRO Time Time Action Notes Notes Direct Group 1010 switches to override reset.
Direct terminate and prevent HPCI/Feedwater (CSIRHR HPCIIFeedwater (CS/RHR when LOCA signal received).
When level reaches +90 inches, evaluate Table 3:
- . If not met, establishes a level band of LL4 to +90 inches.
SEP Directs Drywell cooling restored per SEP-10.
Evaluate TAF and LL4 indicated levels using Caution 11 graphs.
Direct injection established to maintain RPV level LL4 to 90 inches (should try to keep level above the LL3 setpoint, most likely will establish a level band of 60-90 inches)
Page 22 of 28
EVENT 8/9 EVENT 819 ATWS ACTIONS ATWS ACTIONS - CONTINUED
- CONTINUED RO RO Time Time Action Action Notes Notes Continues to Continues select control to select control rods rods and drive and drive in using in using Emerg Emerg rod in notch rod in notch override.
override.
Monitor APRMs Monitor APRMs for for downscale.
downscale.
Performs LEP-02 Performs LEP-02 Section Section 33 after jumpers installed.
are installed.
Inhibit ARI Inhibit Places ARI Initiation Switch to INOP Places ARI Reset Switch to RESET and maintains for 5 seconds.
Verifies red TRIP light above ARI Initiation is OFF Reset RPS when scram jumpers installed.
Ensures Dish Vol Vent & Drain Test switch is in Isolate.
Confirms Disch Vol Vent Valves V139 and CV-F01 CV-FO1O0 are closed Confirms Disch Vol Drain valves V140 and CV-F011 CV-FO11 are closed.
Resets RPS.
Place Disch Vol Vent & Drain Test switch to Normal Recognize/re Recognize/report port failure of scram discharge volume vents and drains.
Page Page 23 23 of of 28 28
8/9 EVENT 819 ATWS ACTIONS - CONTINUED BOP Time Action Notes Notes Places Group 10 10 switches to override I/
reset Terminate and prevent injection to RPV.
HPCI - Places HPCI Aux Oil Pump to Pull to Lock.
FW- Can be performed a couple of FW -
ways.
- 2. Adjust discharge pressure of pump down to below RPV pressure to prevent injection.
Ensures MSTR RFPT SPIRX SP/RX L VL CTL in manual and LVL SULCV closed.
ECCS - Turns OFF low pressure ECCS pumps if they start.
May place Feedwater in service for level control when directed by the SCO.
REP discharge pressure Raise RFP above RPV pressure Open SULCV to obtain desired level of 28 Page 24 of
819 EVENT 8/9 ATWS ACTIONS - CONTINUED BOP Continued Time Action Notes May place HPCI in service for level ATWS control during A TWS when directed by the SCO.
Place HPCI in manual (M) and adjust output demand to approximately 40% using the manual lever.
Adjust HPCI setpoint to approximately 1000 GPM.
Start auxiliary oil pump.
When HPCI turbine speed stops increasing, then raise HPCI pump flow to approximately 1000 GPM H PCI.
using the manual lever on HPCI.
Ensure E41-F012 is closed when flow has increased above 800 GPM.
Transfer HPCI from Manual (M) TO Auto (A).
Adjust HPCI setpoint to maintain desired reactor water level Page 25 25 of 28 28
EVENT 10 ALL RODS IN When level hashas been lowered and level band band has been established, the scram discharge volume vents and drains will be repaired. Control rods can then be inserted by manual scram. When all 170 to 200 inches the scenario may be control rods are inserted and level is being maintained 170 terminated Malfunctions Required:
Success Path:
When actions are taken to control reactor water level during the AATWS TWS after terminating and preventing, the SDV vents and drains will be repaired and rods can be inserted.
When all rods are inserted and level is being controlled 170 - 200 inches the scenario may be terminated.
Simulator Operator Actions:
o11 When directed by the lead evaluator, delete the following commands:
o RDO36F, Scram Disc Vol Drn Fails Closed El Malfunction - RD036F, o Malfunction - RP010F, RPO1OF, ATWS 3 (Make sure RPS is reset before deleting)
Inform the SCO that a loose wire was found on the SDV vent and drain logic and have been fixed.
oEl If contacted as the RB AOAC to secure Alternate Boron Injection delete remote SL_IALEPO3.
SL_IALEP03.
oEl When directed by the lead examiner, proceed to the next event.
Required Operator Actions SRO Time Action Notes Exit LPC and enter RVCP when all rods are in.
Direct securing Alternate Boron Injection.
Direct level restored to 170 170 - 200 inches after rods are all in.
Page 26 of 28
EVENT 10 EVENT 10 RODS IN ALL RODS IN RO RO Time Action Notes Notes Continues to Continues drive rods to drive rods using using RMCS RMCS Confirms Disch Vol. Vent & Drains are open when reported fixed.
Inserts a scram after discharge volume has drained for -2 2 minutes.
Reports all rods in.n.
AC to secure Alternate Boron Directs AO Injection.
BOP Time Action Notes Maintains reactor pressure as determined by the SCO.
Maintains level as directed by the SCO.
Restores level to 170 - 200 inches after all rod inserted.
Increases RCIC controller to 500 gpm.
Increases HPCI controller to raise reactor water level.
Raises feedwater flow to raise reactor water level, if REPs RFPs were not tripped.
Page Page 27 27 of of 28 28
Simulator Operator Activities:
WHEN directed by the lead examiner, place the simulator in FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER Page 28 of 28
PROGRESS ENERGY PROGRESS ENERGY CAROLINAS CAROLINAS BRUNSWICK TRAINING SECTION BRUNSWICK SECTION SIMULATOR SCENARIO SIMULATOR 2010-1 NRC Exam Scenario #3
Appendix D Appendix D Scenario Outline Scenario Outline Form Form ES-D-1 ES-D-1 Facility: Brunswick Facility: Brunswick Scenario #:
Scenario #: 2010-1 2010-1 #3#3 OP-Test OP-Test No.:
No.: Draft Draft Examiners:
Examiners: Operators:
Operators:
Initial Conditions:
Initial The plant isis operating at -50%
50% power during startup following a refuel outage. No equipment is out of of service Turnover: turnover, raise power to 60%, perform alternate power Following shift turnover, verification and prepare prepare to place the second feed pump pump in in service.
Event Malf. No. Event Event No. Type*
Type* Description 11 N/A R-BOP Raise power to 60%
R-SRO 2 N/A N-SRO Perform verification of Reactor Power level using Alternate N-BOP Indications 3 EEO3OM EE030M C-BOP Main Stack Rad Monitor power failure. (TS)
C-SRO 4 K4517A C- BOP C-BOP 2B TCC Pump trip C- SRO C-SRO 5 P2740A1 I P2740A11 C- RO C-RO 2B Recirc Pump speed control failure (TS)
C- SRO C-SRO 6 MSO31 F MS031F 1-BOP I-BOP MTLO controller failure I-SRO 7 MSO17F MS017F M-ALL Turbine high vibration requiring turbine trip and scram resulting in an ATWS condition requiring entry to LPC.
8 K21 1 9A K2119A C-RO SLC pumps will not start due to switch failure.
Off C-SRO 99 RDO36F RD036F C-RO Scram discharge volume vents and drains fail closed.
C-SRO 10 10 All Rods In In
- (N)ormal, (R)eactivity, (R)eactlvlty, (l)nstrument, (I)nstrument, (C)omponent, (M)ajor (M)aJor Page Page 22 of of 28 28
SCENARIO DESCRIPTION SCENARIO DESCRIPTION Unit 22 is Unit is operating operating at -50% power at -50% power during during startup following aa refuel startup following refuel outage.
outage.
Event 11 Event Continue with Continue with startup startup to to 60%
60% power power using using recirc recirc flow.
flow.
Event 22 Event Performs aa verification of Performs of reactor reactor power power level level using using alternate alternate indications indications per per OGP-04 OGP-04 Attachment 1. 1.
Event 3 Event Power to the Main Power Main Stack RadRad Monitor will be Monitor will be lost.
lost. The power power results results in in Group Group 6 isolation and and Secondary Secondary containment.
containment.
Event 4 Pump 2B will trip and TBCCW low TCC Pump low header pressure will alarm. The crew will respond per OAOP-17.0 and place 2C TBCCW pump in service.
Event 5 2B Recirc Pump control speed will fail resulting in lowering reactor power. The crew will respond per OAOP-03.0 and lock the scoop tube.
Event 6 The main turbine lube oil controller will fail closed causing the lube oil to heat up and vibrations to occur on the main turbine. This will require the main turbine to be tripped
(>12 mils on bearing 1-8 and >10 mils on bearings 9/10) and the reactor reactortoto be scrammed.
Event 7 Most control rods will fail to insert on the scram. The crew will respond to the A ATVVS TWS per EOP-01-LPC.
Event 8 When SLC initiation is attempted, neither SLC pump will start due to switch failure.
The crew will enter LEP-03 and align for alternate boron injection using CRD.
Event 9 When scram jumpers are installed the scram discharge vents and drains will fail to open which will result in inability to insert control rods by resetting RPS and inserting additional manual scrams.
Event 10 When level has been lowered and level band has been established, the scram discharge volume vents and drains will be repaired. Control rods can then be inserted by manual scram. When all control rods are inserted and level is being maintained 170 170 to 200 inches the scenario may be terminated.
Page of 28 Page 33 of 28
Simulator Setup Initial Conditions:
IC ENP-24.5 for IC 9 Rx Power 60%
Core Age EOC Events:
Event # Trigger Description 3 11 Manual Main Stack Rad Monitor Power Failure 4 2 Manual Trip 2B TBCCW Pump 5 3 Manual MTLO controller failure Turbine high vibration causing the crew to scram the plant with an 6 4 Auto ATWS A TWS condition 8 NA SLC switch failure 9 5 Auto Scram Discharge Vents and Drains fail closed Malfunctions ~ummary Ma.lfunctions Summary naaea entries are Ikctive ShadedEmfriesare>Active Mult Current Target Ramp Act. Deact MaIf. 10 Malf. ID Description Trig ID 10 Value Value Time Time Time RPOIOF RP010F ATWS 3 ATWS3 True True RDO36F RD036F Scram Disc Vol Drn Fails Closed 5 - on False True Scram MSO31F MS031F MTLO Temp Cntrlr Fails False True 3 MSO17F Auto on MS017F 4 Turbine Bearing Vibration 0 5 5 mm 5min UA231-6 MSOI7F Auto on MS017F 5 Turbine Bearing Vibration 0 5 mm 5 min UA231-6 Auto on MS017F 6 Turbine Bearing Vibration 0 5 mm 5 min UA231-6 MS008F Main Turbine Trip False True 6 RPOO5F RP005F Auto Scram Defeat False True 7 R emo es S Remotes ummary Summary MuIt.
Mult. Current Target ID Remote 10 ID Description Trig 10 Value Value EP_IAEOPJPI EP IAEOPJP1 Bypass LL3 Group II Isol Off On 88 MS_VMS5005D MS VMS5005D MVD-5005 Mn Stm Drn Hdr Isolation 0 1 1 9 EP_1AC5993U EP IACS993U DW OW CLR A&D Overide - Normal/Run Normal Run 10 10 EP_IACS994U EP IACS994U DW OW CLR B&C Overide - Normal/Run Normal Run 10 10 EP_1ASW5997 EP IASW5997 SW-V106 LOCA Override Normal Bypass 10 10 EP_1A5W5998 EP IASW5998 SW-V103 LOCA Override Normal Bypass 10 10 ED_IAUPB2A6 ED IAUPB2A6 UPS 2A to Sample Detection Skid Closed Open 1 1
SL_IALEPO3 SL IALEP03 =
Alt = Sub Pump / Hose Lineup Normal Alt 11 11 Page4of28 Page 4 of 28
SWI*tChes S Swftches Summary ummary Target Override Switch1110 ID Description Trig Value Position K4517A TBCCW Pump B TBCCWPump B On Off 2 Q4517LG4 TBCCW Pump B B Green On/Off OnlOff Off 2 K2119A S/B Liq SIB Lig Pump A-B Stop On K21 I 9A K2119A S/B Liq SIB Lig Pump A-B Pump A Off K2119A S/B Liq SIB Lig Pump A-B PumpAB Off K2119A S/B Liq SIB Lig Pump A-B Pump B B Off K6103B SBGT Sys BB Pref Off Auto on RFP A Trip K431 3A K4313A REP A Recirc Vlv Auto RFP Close Off (Q43164WY =true)
Auto on RFP B Trip K4307A REP B RFP B Recirc Vlv Auto Close Off (Q43104WY =true)
Special Instructions:
Ensure ENP-24.5 for IC-9 at P603 panel.
Reduce power to -50% using recirc flow.
Place 2B TCC pump in service.
Verify APRM GAFs are.:::are < 1.00 Mark-up OGP-04, Attachment 1, for 30, 40 and 50% power.
Have the computer on the Heat Balance page 1.
Page 5 of 28
Shift Briefing Shift Briefing Plant Status Plant Status The plant The plant is is operating operating at at -50%
50% power power during during startup startup following aa refuel refuel outage.
outage.
GP-04 is complete up to step 5.2.22.
Equipment Out of Service No equipment is out of service Plan of the Day Raise power to 60%, perform alternate power verification and prepare to place the second feed pump in service.
Page Page 6of28 6 of 28
Scenario Information Critical Tasks Critical Tasks (bolded/italicized in the required operator action statements)
- HPCI/Feedwater during the ATWS (CS/RHR when LOCA signal Terminate and prevent HPCl/Feedwater received)
- PerForm LEP-02, Alternate Rod Insertion using RMCS.
Perform Page 77 of 28
EVENT 1I EVENT SHIFT TURNOVER, SHIFT TURNOVER, RAISE RAISE REACTOR REACTOR POWER POWER TO TO 60%
60%
The crew crew will complete shift turnover and raise raise reactor reactor power power to to -60%.
60%.
Malfunctions required:
Malfunctions required: None.
None.
Objectives:
SOC - Directs reactor power to be raised using Recirc pump speed control.
SCO -
RO - Performs power increase using recirc flow control.
Success Path:
60% power.
Power is raised to -60%
Simulator Operator Actions:
o E If contacted as the RE for power increase guidance, inform crew to raise power using Reactor Recirc flow.
o If contacted as the RE to monitor power increase, inform crew that you will monitor core performance.
o D When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity Manipulation - Raise power 10% using recirc pump speed controls.
SRO Time Action Notes Directs Power to be raised to -60%60%
power.
RO Time Action Notes Raises power using recirculation flow to 60% power.
-60%
Raise flow on one RR Pump (2%) (-2%)
at a time to stay within mismatch criteria (7.5x1 (7.5x10 066 MIbs Mlbs jet pump flow if << than 58 MIbs 3.5x1 06 MIbs Mlbs or 3.5x10 6 Mlbs if> than 58 MIbs).
Mlbs).
Continues alternating Recirc pump increases until power is 60%.
-60%.
Verifies operation on the Power to Flow map.
BOP BOP Time I Time IAction Action Plant Monitoring Plant Monitoring I Notes Notes Page8of28 Page 8 of 28
EVENT 2 EVENT REACTOR POWER REACTOR POWER LEVEL LEVEL VERIFICATION USING USING ALTERNATE INDICATIONS INDICATIONS Performs OGP-04, Attachment 1, Performs 1, Verification of Reactor Power Level Level Using Using Alternate Indications Indications Malfunctions required: None.
Objectives:
seo Soc - Directs Verification of Reactor Power Level Using Alternate Indications.
RO - Performs Verification of Reactor Power Level Using Alternate Indications lAW OGP-04.
Success Path:
Verification of Reactor Power Level Using Alternate Indications within 5% of Heat Balance.
Simulator Operator Actions:
o El If contacted as the RE to monitor core performance, inform crew that you will monitor core performance on the computer.
o El When directed by the lead examiner, proceed to the next event.
Required Operator Actions Normal Operations - Verification of Reactor Power Level Using Alternate Indications lAW OGP-04, Attachment 1.
SRO Time Action Notes Directs Verification of Reactor Power Level Using Alternate Indications.
RD RO Time I Time I Action Action Plant Monitoring Notes I Notes BOP Time Action Notes Performs GP-04 Attachment 1 1 Obtain valid Heat Balance (Display 820) and record heat balance % %
power in Table 1.
Obtain LPRM % PWR (Display 861)
Filtered LPRM Readings Edit, and record in Table 1.
Goes to step 4 to obtain steam flow
% power.
Page 9of28 9 of 28
(Contd) REACTOR POWER LEVEL VERIFICATION USING ALTERNATE EVENT 2 (Cont'd)
INDICATIONS (Contd)
BOP (Cont'd)
Time Action Notes Perform the following at the prompt on the ERFIS terminal:
Select Screen 6 by typing 6 Select 11 for Normal FW Heater Lineup Record Steam Flow equivalent %
power on Table 11 (from RE program).
Compare the Heat Balance (%) with the other alternate indications (%).
If the heat balance is greater than all alternate indications (conservative as is) OR One or more alternate indications are within 5% of the heat balance (normal acceptance),
Then Power Ascension may continue.
Page 10 10 of 28
EVENT 33 EVENT MAIN STEAM MAIN STEAM LINELINE RAD RAD MONITOR MONITOR FAILURE FAILURE Power to Power to the the Main Main Stack Stack Rad Rad Monitor Monitor will will be be lost.
lost. The The power power results results in Group 66 isolation, in Group isolation, Secondary containment Isolation but SBGT Secondary containment Isolation but SBGT fails fails to to auto auto start.
start. The The crew crew must must manually manually start start SBGT to SBGT to maintain maintain Secondary Secondary Containment Containment integrity.
integrity.
Malfunctions required:
Malfunctions required:
UPS 2A to Sample UPS Sample Detection Detection Skid breaker open.
Skid breaker Objectives:
Objectives:
SCO - Determine SCO - Determine actions actions required required for LCO LCO perper Technical Specifications.
Specifications.
BOP - Respond BOP Respond to a process radiation monitoring downscale/inop annunciator.
Success Path:
Technical Specification /I TRM
- 3.3.6.1 PCIS Instrumentation, determine Function 2c is inoperable, determine actions A and B apply (single channel), then C and F after 11 hour1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />.
- TRM 3.4 Post Accident Monitoring, determine Function 5 is inoperable and condition A applies
- ODCM 7.2 Gaseous Effluent Monitoring, determine function 1 1 is inoperable and notify E&RC.
- 3.6.4.3 3.6.4.3 SBGT, Determine Condition A Al, 1, restore in 7 days Simulator Operator Actions:
LI Insert Trigger 1I at the discretion of the lead evaluator.
D LI Ensure SBGT start when switches are taken to ON.
D LI If asked to investigate, report UPS Panel 2A to the Stack Rad Monitor is tripped.
D LI If contacted as I&C to investigate, acknowledge the request, if asked do not D
recommend transfer to the alternate power supply until the cause of the trip is investigated.
LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Tech Spec Declaration - 3.3.6.1 condition A and B, TRM 3.4 condition A, ODCM 7.2, and 3.6.4.3 condition Al. A 1.
Page Page 11 11 of of 28 28
EVENT 33 (cont'd)
EVENT (contd) MAIN STEAM MAIN STEAM LINE LINE RAD RAD MONITOR MONITOR FAILURE FAILURE SRO SRO Time Action Notes Notes Direct actions Direct actions of of the APPS for the Main Main Stack Rad Stack Rad Monitor Monitor Direct manual start of SBGT.
I/C to investigate loss of UPS 2A.
Direct IIC Refer to Tech Specs.
3.3.6.1, Determine function 2c is inoperable (Condition A and B),
then C and F after 11 hour1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />.
TRM 3.4 Determine function 5 is inoperable (Condition A, 31 days)
ODCM 7.2, Determine function 11 is inoperable and notify E&RC.
3.6.4.3 SBGT, Determine Condition A Al, 1,
restore in 7 days.
RO Time Action Notes Plant Monitoring .
May open the SW-V111 SW-Vl 11 or VI 17 to V117 supply cooling water to the vital header lAW 2APP-UA-05 1-9 1-9 or 2-9.
Page Page 12 12 of of 28 28
(contd)
EVENT 3 (cont'd) MAIN STEAM LINE RAD MONITOR FAILURE BOP Time Action Notes Report loss of Main Stack Rad Monitor.
UA-03 5-4, PROCESS OG VENT PIPE RAD HI-HI 6-3, PROCESS SMPL OG VENT PIPE DNSC/INOP 6-4, PROCESS OG VENT PIPE RAD-HI RAD - HI UA-05 3-5, SBGT SYS B B FAILURE 4-6, SBGT SYS A FAILURE 6-10, RX BLDG ISOLATED Report TS review for the SCO from the Annunciator reviews.
- . 3.6.4.3
- . 3.3.6.1 Table 3.3.6.1-1, Function 2C
- . ODCM 7.3.2 Table 7.3.2-1 1, 7.3.7, and 7.3.13 Function 1,7.3.7,
- . TRM 3.4, Table 3.4.2 Function 5 Determine SBGT Train B B did not auto start and manually start Dispatch AO to investigate UPS 2A condition.
SW-Vill or May open the SW-V111 orVll7 V117 to supply cooling water to the vital header lAW 2APP-UA-05 1-9 or 2-9.
Page 13 of 28
EVENT 4 TBCCW PUMP B TRIP TCC Pump 28 2B will trip and T8CCW TBCCW low header pressure will alarm. The crew will respond per OAOP-17.O and place a T8CCW OAOP-17.0 TBCCW pump in service Malfunctions required:
2B TCC pump Trip of 28 Objectives:
SOC - Direct entry into OAOP-17.0.
SCO OAOP17.O.
RO - Restoration of TCC pressure Success Path:
TBCCW pump started and TCC pressures restored to normal.
2C T8CCW Simulator Operator Actions:
D Insert Trigger 2 at the discretion of the lead evaluator.
Li If contact as the T8 D TB AC, 2B TCC pump is hot to the AO, wait one minute and report that 28 touch and the breaker is tripped.
Li If contacted as Unit One CRS, report Unit One is not using the 2C TCC Pump.
D LI Acknowledge request as I&C to do troubleshooting/repair for the 28 D 2B TCC TOO Pump.
LI D When directed by the lead examiner, proceed to the next event.
Required Operator Actions SRO Time Action Notes OAOP-17.O.
Direct entry into OAOP-17.0.
TOO Pump.
Direct start of a TCC I/O to investigate loss of 28 Direct I/C 2B TCC TOO pump.
RO Notes I Time I Action Time Action Monitoring Plant Monitoring.
I Notes Page 14 of 28
EVENT 44 (Cont'd)
EVENT (Contd) TBCCW PUMPPUMP B B TRIP TRIP BOP BOP Time Action Notes Notes Report loss Report loss of of 2B 2B TCC Pump Pump and and refer refer to APPs.
2APP-UA..03 (2-4) TBCCW PUMP 2APP-UA-03 DISCH HEADER PRESS LOW Enter OAOP-17.0.
OAOP-17.O.
Dispatch AOAC to investigate 2B TCC Pump condition.
May dispatch AO AC to perform prestart checks for 2A or 2C TCC Pump.
Starts a TCC pump. (May start two pumps)
(Depending on the amount of time that no TCC pump is operating, one pump may not immediately restore TCC pressure due to the system loads TCC temperature control valves being wide open.)
If needed, Verify Unit One is not using 2C TCC pump and start pump.
Page Page 15of28 15 of 28
EVENT 5/6 EVENT 516 MTLO CONTROLLER MTLO CONTROLLER FAILURE/TURBINE FAILUREITURBINE VIBRATIONS VIBRATIONS HIGH HIGH Malfunctions Required:
Malfunctions Required:
Main Turbine lube Main lube oil oil cooler cooler controller controller fails closed.
closed. When high high temperature alarm alarm annunciates activate annunciates activate trigger trigger to accelerate accelerate turbine vibrations.
vibrations.
Objectives:
Respond to an abnormal turbine vibration per UA-23 6-1 and UA-23 6-3.
Success Path:
The MTLO controller on XU-2 indicates 100% output (full closed) and turbine lube oil temperature will rise. Dispatch AO AC and I&C to investigate.
Simulator Operator Actions:
oD At the discretion of the lead evaluator, insert Trigger 3 to fail the MTLO controller closed.
o If asked as the TB AO LI AC to investigate, report that the temperature control valve to the MTLO is closed. (There is no bypass valve).
oLI Verify turbine vibrations on 4, 5, and 6 begin to rise after receiving UA-23 1-6.
oLI If asked as I&C to investigate acknowledge the request.
o When directed by the lead examiner, proceed to the next event.
LI Required Operator Actions SRC SRO Time Action Notes Direct actions of APPs.
APP's.
When vibrations rise to above the TSI setpoint, direct manual scram and turbine trip per the vibration APP.
(12 mils on bearings 1-8, 10 mils on bearings 9-10)
(As conservative decision making may insert before setpoint).
RC RO Time Action Notes Plant Monitoring Monitoring.
When directed by the SRC, SRO, insert aa manual scram and trip the main turbine.
Recognize and report an ATWS. A TWS.
Page Page 1616 of of 28 28
EVENT 5/6 EVENT 516 (Cont'd)
(Contd) MTLO MTLO CONTROLLER CONTROLLER FAILURE/TURBINE FAILUREITURBINE VIBRATIONS VIBRATIONS HIGH HIGH BOP BOP Time Time Action Action Notes Notes Recognize and Recognize and report report rising rising lube lube oil oil temperatures.
temperatures.
Dispatch TB AO Dispatch TB AC to to investigate investigate TCV.
TCV.
Perform actions of APPs Perform APPs UA-23 1-6 TURB OR 1-6 OR RFP BRG TEMP RFP BRG HIGH HIGH 6-1 TURBINE VIBRATION HIGH 6-3 TSI HIGH VIBRATION TRIP Monitor turbine bearing temperatures and vibrations (PC display 630).
May place the Main Turbine Lube Oil controller in manual and attempt to operate the valve.
Page Page 1717 of of 28 28
EVENT 7/8718 ATWS ACTIONS Most control rods will fail to insert on the scram. The crew will respond to the A TWS per EOP-ATWS EOP 01-LPC. When SLC initiation is attempted, neither SLC pump will start due to switch failure. The crew will enter LEP-03 and align for alternate boron injection using CRD Malfunctions Required:
Scram discharge volume vents and drain fail closed on the scram.
SLC switch is failed in the off position.
Objectives:
SCO - Direct actions for a reactor scram per EOP-01-RSP.
Direct actions to control reactor power per EOP-01-LPC.
RO/BOP - Perform immediate actions for a reactor scram.
RO/SOP Perform actions for an ATWS ATWS per EOP-01-LPC.
Success Path:
SRVs. Performs actions of LPC, recognizes failure Controls reactor pressure using the SRV's.
of SLC and performs alternate boron injection.
Simulator Operator Actions:
D If crew does not trip the main turbine by the time SLC initiation is directed, initiate D
Trigger 6 to trip the main turbine.
D If requested to perform alternate boron injection using CRD, acknowledge the D
request. (will be performed after RPV injection is re-started)
U Acknowledge request as I&C D l&C to investigate failure of SLC.
U When directed by the lead examiner, proceed to the next event.
D Required Operator Actions SRO Time Action Notes Enter RSP and transition to LPC.
Direct mode switch to shutdown when steam flow << 3 Mlbs/hr.
Direct ARI initiation.
Direct Recirc Pump speeds reduced to 10%.
Direct Recirc Pumps Tripped.
Page 18 of 28
718 EVENT 7/8 ATWS ACTIONS SRO Continued Time Action Notes Direct SLC initiation.
Direct LEP-03, Alternate boron injection.
Direct ADS inhibited.
Direct RWCU isolation.
Direct LEP-02, Alternate Rod Insertion.
BOP Time Action Notes Places ADS in inhibit.
Isolates RWCU.
Closes RWCU Outboard Isol Valve G31 -F004.
G31-F004.
RO Time Action Notes Place mode switch to shutdown when 3x10 6 Ib/hr.
steam flow << 3x10 6 lb/hr.
Initiates ARI.
Places Recirc Pump speeds reduced to 10%.
Trips Recirc Pumps.
Initiates SLC.
Recognizes failure of SLC and reports to SCO.
Page 19 19 of 28
EVENT 7/8 EVENT 718 ATWS ACTIONS RO (cont'd)
(contd)
Time Action Notes Notes Performs LEP-03, Alternate Boron Injection.
Injection.
AO to perform LEP-03, Direct AD Section 1, Alternate Boron Injection using CRD.
Performs LEP-02, Alternate Rod Insertion. (RMCS Section)
Insert IRMs.
When < < range 3 on IRMs insert SRMs.
Start both CRD pumps.
Place CRD Flow Controller to Manual.
Throttle open flow controller to establish establish? ~ 260 drive water psid.
Bypass RWM.
Selects control rods and drives in using Emerg rod in notch override.
Performs alternate rod insertion per LEP-LEP 02 Section 3.
Request jumpers for LEP-02 Section 3.
Page 20 of 28
EVENT 8/9 EVENT 819 ATWS ACTIONS ATWS ACTIONS - CONTINUED
- CONTINUED The crew The crew will will terminate terminate and and prevent prevent injection, injection, re-injection re-injection will will start when level start when level isis at at 90 90 inches inches due due to table to table 33 conditions conditions not not met.
met. IfIf RFPs REPs are are tripped tripped they they will will be be unavailable unavailable for for level level control control as as the the Recirc Valves Recirc Valves willwill fail fail in in the closed position the closed position not not allowing allowing the the RFPs RFPs to to be be restarted.
restarted. HPCIHPCI will will be be available for available for level level control.
control.
Objectives:
Objectives:
SCO - Direct Direct actions to lower reactor reactor vessel vessel level level when the conditions of Table 3 are not met per per EQP-01 -LPC.
RO/BOP - Control reactor level during an ATWS per EOP-01 LPC.
Success Path:
Success Continues actions in the LPC LPC procedure, procedure, terminate and prevent prevent injection, drive rods using using RMCS.
Simulator Operator Actions:
D If requested to defeat Group II LL3, wait 2 minutes, initiate Trigger 8 and inform the SCO that the jumpers are installed.
D If requested to install LEP-02, Section 3 jumpers, wait until level has been terminated and prevented or 5 minutes whichever is longer, insert Trigger 7 and inform the SCO that the jumpers are installed.
D If requested as I&C D l&C to investigate the failure of the scram discharge volume vents and drains, acknowledge the request.
D If requested to open the MVD-5005, wait 5 minutes, initiate Trigger 9 and inform the control room that the valve is open.
D If requested to defeat Drywell Cooler LOCA Lockout, wait three minutes, initiate D
Trigger 10 and inform the SCO that the jumpers are installed.
D When injection to the RPV has been re-established and if requested to line up boron to the CRD system initiate Trigger 11.
Li When directed by the lead examiner, proceed to the next event.
D Page Page 2121 of28 of 28
EVENT 8/9 EVENT 8/9 CONTINUED ATWS ACTIONS - CONTINUED Required Operator Operator Actions SRO Time Action Notes Direct Group 10 Direct 10 switches toto override override reset.
Direct terminate and prevent HPCI/Feedwater (CSIRHR HPCIIFeedwater (CS/RHR when LOCA signal received).
When level reaches +90 inches, evaluate Table 3:
- . If not met, establishes a level band of LL4 to +90 inches.
Directs Drywell cooling restored per SEP-SEP 10.
Evaluate TAF and LL4 indicated levels using Caution 11 graphs.
Direct injection established to maintain RPV level LL4 to 90 inches (should try to keep level above the LL3 setpoint, most likely will establish a level band of 60-90 inches)
Page 22 of 28
EVENT 8/9 EVENT 819 ATWS ACTIONS - CONTINUED ATWS ACTIONS - CONTINUED RO RO Time Time Action Action Notes Notes Continues to Continues to select control rods select control and drive rods and drive in using in Emerg rod using Emerg in notch rod in notch override.
override.
Monitor APRMs Monitor APRMs for downscale.
downscale.
Performs LEP-02 Performs LEP-02 Section Section 33 after jumpers are installed.
Inhibit ARI Inhibit Places ARllnitiation ARI Initiation Switch to INOP Places ARI Reset Switch to RESET and maintains for 5 seconds.
Verifies red TRIP light above ARI Initiation is OFF Reset RPS when scram jumpers installed.
Ensures Dish Vol Vent & Drain Test switch is in Isolate.
Confirms Disch Vol Vent Valves V139 and CV-FO1O CV-F010 are closed Confirms Disch Vol Drain valves V140 and CV-F011 CV-FO1 I are closed.
Resets RPS.
Place Disch Vol Vent & Drain Test switch to Normal Recognize/report failure of scram discharge discharge volume vents and and drains.
drains.
Page Page 23 23 of of 28 28
8/9 EVENT 819 ATWS ACTIONS - CONTINUED BOP Time Action Notes Notes Places Group 10 10 switches to override I/
reset Terminate and prevent injection to RPV.
HPCI - Places HPCI Aux Oil Pump to Pull to Lock.
FW- Can be performed a couple of FW -
ways.
- 2. Adjust discharge pressure of pump down to below RPV pressure to prevent injection.
Ensures MSTR RFPT SPIRX SP/RX L VL CTL in manual and LVL SULCV closed.
ECCS - Turns OFF low pressure ECCS pumps if they start.
May place Feedwater in service for level control when directed by the SCO.
Raise RFP discharge pressure above RPV pressure Open SULCV to obtain desired level Page 24 of 28
819 EVENT 8/9 ATWS ACTIONS - CONTINUED
- BOP Continued Time Action Notes Notes HPCI in service for level May place HPCI ATVVS control during A TWS when directed by the SCO.
Place HPCI in manual (M) and adjust output demand to approximately 40% using the manual lever.
Adjust HPCI setpoint to approximately 1000 GPM.
Start auxiliary oil pump.
When HPCI turbine speed stops increasing, then raise HPCI pump flow to approximately 1000 GPM using the manual lever on HPCI.
Ensure E41-F012 is closed when flow has increased above 800 GPM.
Transfer HPCI from Manual (M) TO Auto (A).
Adjust HPCI setpoint to maintain desired reactor water level Page 25 of 28
EVENT 10 EVENT 10 RODS IN ALL RODS IN When level level has has been been lowered lowered and and level level band band has has been been established, established, the the scram scram discharge discharge volume and drains vents and drains will be be repaired.
repaired. Control Control rods rods can can then be be inserted inserted by by manual manual scram.
scram. When all all control rods control rods are are inserted inserted and and level level is is being being maintained maintained 170 170 to 200 200 inches inches the scenario may may be be terminated Malfunctions Required:
Success Path:
When actions are taken to control reactor water level during the A ATWS TWS after terminating and preventing, the SDV vents and drains will be repaired and rods can be inserted.
When all rods are inserted and level is being controlled 170 - 200 inches the scenario may be terminated.
Simulator Operator Actions:
o When directed by the lead evaluator, delete the following commands:
oD Malfunction - RD036F,
- RDO36F, Scram Disc Vol Drn Fails Closed oD Malfunction - RP010F, RPO1OF, ATWS 3 (Make sure RPS is reset before deleting)
SOC that a loose wire was found on the SDV vent and drain logic and Inform the SCO have been fixed.
oD If contacted as the RB AO AC to secure Alternate Boron Injection delete remote S L_IALEPO3.
SL_IALEP03.
oEl When directed by the lead examiner, proceed to the next event.
Required Operator Actions SRO Time Action Notes Exit LPC and enter RVCP when all rods are in.
Direct securing Alternate Boron Injection.
Direct level restored to 170 170 - 200 inches after rods are all in.
Page Page 26 26 of of 28 28
EVENT 10 ALL RODS IN RO Time Action Notes Continues to drive rods using RMCS Confirms Disch Vol. Vent & Drains are open when reported fixed.
Inserts a scram after discharge volume has drained for -22 minutes.
Reports all rods in.
Directs AC AO to secure Alternate Boron Injection.
BOP Time Action Notes Maintains reactor pressure as determined by the SCO.
5CC.
Maintains level as directed by the SCO.
Restores level to 170 - 200 inches after all rod inserted.
Increases RCIC controller to 500 gpm.
Increases HPCI controller to raise reactor water level.
Raises feedwater flow to raise RFP5 were not reactor water level, if RFPs tripped.
Page 27 of 28
Simulator Operator Activities:
WHEN directed by the lead examiner, place the simulator in FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER Page 28 of 28
ATTACHMENT 11 Page 1 1 of 3 Verification of Reactor Power Level Using Alternate Indications Unit 2 Unit_2_ Date: Today NOTE: This attachment is used to validate the heat balance at approximately 10%
power increments.
OPT-Ol .8D, Core Thermal Power
- 1. OBTAIN valid Heat Balance (Display 820 or OPT-01.8D, Calculation) AND RECORD heat balance % % power in Table 1.
TABLE 1 1 TIME APPROX. STEAM LPRM HEAT APRM GAFs INITIALS RX FLOW % POWER BALANCE ::::; 1.00 POWER % POWER % POWER TURBINE N/A ON LINE N/A N/A N/A N/A N/A 2hrsago 2 hrs ago 30% 29.2 29.9 30.1 RO RO 1 hr ago 1 40% 38.6 39.6 39.9 RO RO l5minago 15 min ago 50% 48.9 49.8 50.1 RO RO 60%
70%
80%
90%
100%
Definitions for Table 1:
HEAT BALANCE % % POWER - A calculation of core thermal power obtained by solving an energy balance on the reactor vessel. Valid heat balance calculations may be obtained from Display 820 edits or manually by performing OPT-01.8D.OPT-Ol .8D.
Caution must be taken to ensure that any failed sensors have valid substituted values.
LPRM % % POWER - An alternate indication of reactor power calculated only on the process computer which is obtained by averaging calibrated LPRM readings.
STEAM FLOW % POWER - An alternate indication of reactor power obtained by correlating the total steam flow to a valid heat balance. Total steam flow can be obtained from Process Computer Point B041, ERFIS Points C32FA014, C32FA015, C32FA016, C32FA017, or RTGB indications C32-R603A, B, C, Don D on P603.
OGP-04 IOGP-04 Rev. 89 34 Page 31 of 341
ATTACHMENT 11 Page 2 of Page of 33 Verification of Reactor Reactor Power Power Level Level Using Using Alternate Indications Indications NOTE: The steam flow-power correlation is not accurate with the Turbine on-line and reduced feedwater heating in effect. STEAM FLOW % POWER should be marked N/A unless data exists from the Reactor Engineer using an approved calculation.
- 3. PERFORM the following to obtain the Total Steam Flow (Mlb/hr):
Steam Line (A) (B) (C) (D)
(ERFIS) C32FA014 C32FA015 C32FA016 C32FA017 (P603) C32-R603A C32-R603B C32-R603C C32-R603D Total Steam Flow == (A) +
+ (B) +
+ (C) +
+ (D) =
= _ _ _ __
OR USE Computer Point B041
- 4. PERFORM the following to log on at the ERFIS terminal:
- a. TYPE: ECOI B SET HOST EC01 B (EC02B)
(ECO2B)
OR SET HOST ECO1A EC01A (ECO2A)
(EC02A)
- b. TYPE: GEPACUSER, at USERNAME prompt
- c. TYPE: GEPAC, at PASSWORD prompt OGP-04 IOGP-04 Rev. 89 Page Page 32 of of 34 341
ATTACHMENT 1I Page3of3 Page 3 of 3 Verification of Reactor Power Level Using Alternate Indications NOTE: Typing MAN runs an interactive program called MAN_ALTDSP that performs alternate power calculations based upon user supplied plant inputs.
Remember to enter decimal points for all values. Use the equivalent %
power output from this program for the comparison in the next step.
NOTE: Typing NE runs an automatic program called NE_MAIN that reads ERFIS computer points and automatically calculates the alternate power correlations for display. There are 7 screens in the program. The user can A to advance from one screen to the next or the user can enter the type "A" number of the screen (1-7) he wishes to display next. The Alternate Power Display is Screen 6. The user can enter "H"H for on-line HELP. The user must E to EXIT the program.
enter "E"
- d. TYPE: MAN (for manual input)
- e. TYPE: NE (for automatic input) and select Screen 6 (type: 6).
- 5. RECORD STEAM FLOW equivalent % power on Table 1 I of this attachment using the values obtained from MAN or NE programs.
- 6. COMPARE the Heat Balance (%) (%) with the other alternate indications (%).
- 7. IF the heat balance is greater than all alternate indications (conservative as is) OR one or more alternate indications are within +/-+/- 5% of the heat balance (normal acceptance), THEN Power Ascension may continue.
- 8. IF power ascension is NOT permitted, THEN CONTACT Reactor Engineering to account for the differences in agreement.
- 9. REPEAT the above steps at 10% increments until the reactor is at 100% 100% power.
OGP-04 IOGP-04 Rev. 89 Page 33 of 34 341
PROGRESS ENERGY PROGRESS ENERGY CAROLINAS CAROLINAS BRUNSWICK TRAINING BRUNSWICK TRAINING SECTION SECTION SIMULATOR SCENARIO SIMULATOR SCENARIO 2010-1 NRC EXAM SCENARIO #4
Appendix D Scenario Outline Form ES-D-1 Form Facility: BRUNSWICK Facility: BRUNSWICK Scenario No.:
Scenario No.: 2010-1 #4 Op-Test No.:
Op-Test No.: DRAFT DRAFT Examiners:
Examiners: Operators:
Operators: (SRO)
(SRO)
(RO)
(BOP)
Initial Conditions: Unit Two (2) is operating at 6% power. Reactor startup is in progress per GP-03.
GP-10 sequence A2X is complete up to Step 166.
Turnover: Continue with GP-03 actions to raise reactor power to 10% in preparation for placing the Mode switch to RUN.
Event Maif. No.
Malf. Event Event Description No. Type*
Type*
11 NIO18F NI018F 1-RO I-RO IRM C fails upscale (TS) l-SRO I-SRO 2 N/A N-BOP Shift SPEs N-SRO 3 N/A R-RO Raise reactor power by pulling control rods R-SRO 4 RDO12M, 26-23 RD012M,26-23 C-RO Stuck control rod C-SRO 5
5 Q2BXPUAD HCU 30-07 Accumulator low pressure (TS) 6 MSOO5F MS005F M-ALL MSV closure Inadvertent MSIV 7
7 ESOO4F ES004F C-RO SRV F F failing open C-SRO 88 CAO2OF CA020F M-ALL Tailpipe rupture (LOCA) 9 K1227A 1-BOP I-BOP RHR A Spray logic failure l-SRO I-SRO 10 10 RH_ZVRH28BM C-BOP E11-F028B failure C-SRO 11 11 Drywell & Suppression Pool Spray and Reactor water level being maintained.
- (N)ormal
- (N)ormal, (R)eactivity, (l)nstrument, (I)nstrument, (C)omponent, (M)ajor
SCENARIO DESCRIPTION SCENARIO DESCRIPTION Unit Two (2)
Unit (2) is is operating at 6% power.
power. Reactor Reactor startup isis in in progress progress per per GP-03.
GP-03.
GP-10 sequence A2X is GP-10 is complete up up to step 166.
166.
Event 11 Event crew will continue raising The crew raising power power by by pulling pulling control control rods rods in in preparation preparation for placing the Mode Mode switch to RUN. Rods pulls will commence at Step 166 166 (10-(10-23 @ @ 12) of the A2X sequence. While withdrawing control rod 10-23 from position 12, IRM C will fail upscale causing a rod block and half scram. SRO will address IRM A and C inoperability lAW TS 3.3.1.1. Once addressed, l&C will report IRM A is ready to be returned to service following proper I&C channel check. The crew will take the actions of the APP and bypass IRM C and reset the half scram.
Event 2 Maintenance will contact the control room and request SPEs be swapped due to low oil level. Shift SPE lAW 20P-26.1, Section 8.
Event 3 Following SPE shift, control rods will continue to be withdrawn raising power.
Event 4 When control rod 26-23 is selected for withdrawal, it will be stuck at position
- 12. AOP-02 may be entered and 20P-07, 2OP-07, Section 8.2 actions are required to withdraw a difficult intermediate control rod.
Event 5 When control rod 26-23 is fully withdrawn, HCU 30-07 accumulator light and annunciator will alarm. AO will be dispatched to investigate and determine accumulator alarm is due to low pressure and requires charging. TS 3.1.5 evaluation will be required.
Event 6 HCU 30-07 accumulator is repressurized and TS addressed a spurious Group 1 1 isolation (MSIV closure) causes reactor pressure and power rise.
Manual SRV opening or Scram may be performed. HPCI and/or RCIC may be manually started to control RPV water level due to loss of RFPTs. RFPT5.
Event 7 2 minutes following MSIV closure, SRV F will fail open requiring entry into OAOP-30.0 to attempt to close.
Event 88 With SRV FF failed open, PCCP will be entered and as reactor pressure falls below 700 psig, the tail pipe will rupture causing direct pressurization of the Suppression Pool air space (loss of PSP).
Event 99 When containment spray is attempted with RHR Loop A, the Spray logic will fail to actuate, making sprays unavailable. Emergency depressurization will be required due to pressure suppression pressure limit. Logic will be available following ED.
Event 10 10 When containment spray is attempted with the B B RHR Loop, the El E 11-F028B 1 -F028B will trip on thermal overload. RHR Loop BB will be the only loop available to provide DW Spray lAW SEP-02. Emergency depressurization will be required duedue to pressure suppression suppression pressure limit. Valve will be available following ED.
Event 11 11 Once the reactor is is depressurized with DWDW & Sprays in service and RPV
& SP Sprays being maintained in the normal band, the scenario may be water level being terminated.
terminated.
OBJECTIVES OBJECTIVES SRO SRO
- 1. 3442318402,
- 1. 344231 B402, Direct Direct Actions For For Safety/Relief Safety/Relief Valve Failures Failures Per Per AOP-30.0 AOP-30.O 344243B402, Direct
- 2. 3442438402, Direct Shift Shift Response Response To High High Suppression Suppression Pool Pool Temperature Per Per AOP-14.O AOP-14.0
- 3. 3442178502,
- 3. 344217B502, Direct Direct Actions To Control Control RPV RPV Level Level Per EOP-01-RVCP EOP-O1-RVCP 344218B502, Direct Actions To Control Reactor Pressure Per EOP-01-RVCP
- 4. 34421S8502, EOP-O1-RVCP 344220B502, Direct Actions To Emergency Depressurize The RPV Per EOP 5. 3442208502, EOP-O1-RVCP 3442 14B502, Direct Actions To Control Primary Containment Pressure Per EOP 6. 3442148502, PCCP 344215B502, Direct Actions To Control Primary Containment Temperature Per
- 7. 3442158502, EOP-02-PCCP S. 344216B502, Direct Actions To Control Suppression Pool Temperature Per EOP-
- 1. 2006038501, 223601B401, Respond to High Suppression Pool Temperature per AOP-14.0
- 3. 23900S8401, AOP-30.O 200049B501, Spray The Drywell Per EOP-01-SEP-02
- 4. 2000498501, EOP-O1-SEP-02 200062B501, Spray The Suppression Pool Per EOP-01-SEP-03
- 6. 2050148101, REFERENCES A. OP-07 B. OP-OS
- 8. OP-08 C. OP-26.1 D. GP-03 E. GP-1O GP-10 F. AOP-02.O AOP-02.0 G. AOP-30.O AOP-30.0 H. AOP-39 I. OI5O 01-50 J. EOP-O1-RSP EOP-01-RSP K. EOP-O1-RVCP EOP-01-RVCP L. EOP-02-PCCP M. EOP-LEP-O1 EOP-LEP-01 N. EOP-O1-SEP-02 EOP-01-SEP-02
- 0. EOP-O1-SEP-03 O. EOP-01-SEP-03 P. EOP-O1-SEP-09 EOP-01-SEP-09 Q. Conduct Of Operations Manual R. Technical Specifications S. Plant Emergency Procedures T. Annunciator Panel Procedures
SIMULATOR SETUP SIMULATOR Initial Conditions Initial Conditions IC-6 IC-6 RxPwr Rx Pwr 6%
6%
Event Triggers Event Trigger Description 0 Normal Ops (Shift SPEs)
SPE5) 11 (IRM C Fails Upscale)
Auto Initiated (lRM 2 Auto Initiated (Control Rod 26-23 Stuck) 3 Manually Initiated (HCU 30-07 Low Pressure) 4 Manually Initiated (MSIV closure) 5 Auto Initiated (SRV F Fail Open) 6 Auto Initiated (SRV F Tailpipe ruture) 7 Auto Initiated (RHR Loop A Spray Logic Failure) 8 Auto Initiated (E11-F028B (El l-F028B Overload)
Event Trigger Trigger Description Number I
1 I 1 NIO18F NI018F Withdraw override SRM C failure (K2324JGD) 2 SPE shift 33 Raise reactor power by pulling control rods 4 RDOI2M RD012M Control Rod 26-23 stuck at position 12 "12" 22 K2324JVD EMERG IN deletes RDOI2M RD012M 26-23 55 33 Q2BXPUAD HCU 30-07 low pressure 6 55 MSOO5F MS005F Inadvertent MSIV closure 77 6 ESOO4F ES004F SRV FF fails open 88 77 CAO2OF CA020F SRVFtaiI SRV F tail pipe rupture 99 K1227A A RHR Containment Spray Logic failure 10 10 88 Q17I7RGN Q1717RGN Ell-F028B E11-F028B Overload 11 11 Delete K1227A 11 11 Delete El l-F028B Overload E11-F028B 11 11 Pull SRV FF Backpanel fuses
Malfunctions Summary Malfunctions MaIf ID MalflD Mult Mult Description Description Current Current Target Target Rmptime Rmptime Actime Actime Dactime Dactime Trig Trig ID 10 Value Value Value Value NIO18F NI018F IRM C IRM C FAILURE FAILURE FALSE FALSE TRUE TRUE 40 sec 40 sec 11 RDOI2M RD012M 30-07 STUCK 30-07 STUCK CONTROL CONTROL ROD ROD TRUE TRUE TRUE TRUE MSOO5F MS005F MSIV closure MSIV closure FALSE FALSE TRUE 5 ES004F ES004F ADS VALVE fail open FALSE FALSE TRUE 66 CA020F CA020F SRV FF tail pipe SRV pipe rupture rupture FALSE FALSE TRUE 77 Remotes Summary Remf 10 Remf ID Mult Description Description Current Target Rmptime Actime Trig ID 10 Value Value K2324JGD OVERRIDE 1 Q2BXPUAD 30-07 ACCUM-ROD DISPLAY OFF ON 3 K2324JVD EMER IN 2 G1HZ1G1H REACTOR PRESSURE < 700 psig 7 Q13O3LGH Q1303LGH SCRAM PUSH BUTTON mm 2 min 6 SIMULATOR SETUP Override Summary ID Tag 10 Description Position/ Actual Override Rmptime Actime Dactime Trig Target Value Value K1227A CONTSPRAYVLVCONT CONT SPRAY VLV CO NT NORM ON ON K1227A CONTSPRAYVLVCONT CONT SPRAY VLV CO NT MANUAL OFF OFF K1227A CONTSPRAYVLVCONT CONT SPRAY VLV CONT RESET OFF OFF Q1717LGN Q1717LGN TORUS ISOL E11-F0028B GREEN ON/OFF ON ON 99 Q1717RRN TORUS ISOL E11-F0028B RED ON/OFF ON/OFF OFF ON 99 Q15O8RRJ Q1508RRJ SRVVLVB21-FO13FRED SRVVLV B21-F013F RED ON/OFF ON/OFF OFF OFF 11 11 Q15O8LGJ Q1508LGJ SRVVLVB21-FO13FGREEN SRV VLV B21-F013F GREEN ON/OFF ON/OFF ON OFF 11 11 Annunciator Summary Window Description Description Tagname Override Type Oval Oval AVaI AVa I Actime Dactime Trig Trig 6-1 6-1 CRD CRD ACCUM ACCUM LO LO PRESS/HI PRESS/HI LEVEL LEVEL ZA761 ZA761 ON/OFF ON/OFF ON ON OFF OFF 33 5-8 5-8 RHR RHR BB VALVES VALVES OVERLOAD OVERLOAD ZA358 ZA358 ON/OFF ON/OFF ON ON OFF OFF 99 2-2 2-2 AUTO AUTO DEPRESS DEPRESS CONTROL CONTROL PWR PWR ZA322 ZA322 ON/OFF ON/OFF ON ON OFF OFF 11 11 FAILUE FAILUE I
Special Instructions Exam In Progress"
- 1. Ensure "Exam Progress Stop Signs posted at all simulator entrances.
2 Advance all chart recorders to indicate steady state conditions.
- 2. conditions
- 3. Place all SPDS displays to the Critical Plant Variable display (#100).
- 4. Ensure appropriate keys have blanks in switches.
- 7. Ensure reference materials are in appropriate location.
- 8. Verify all log books have blank sheets only.
lC-6 and place in run.
- 9. Reset to IC-6
@ 12)
- 10. Insert control rods to get back to Step 166 (10-23 @
- 11. Bypass IRM A and place off normal tag.
12.Verify
- 12. Verify SPE A is in service
- 13. Ensure GP-10 is completed up to Step 166 of A2X sequence.
- 14. Ensure OGP-03 is completed up to Step 5.1.5.
- 15. Ensure Reactor pressure is 925 psig and #1 BPV open at least 20%.
- 16. Transfer RFP & Master level controllers to Auto and fully open SULCV in Manual.
- 17. Verify APRM GAFs are ~1.00.
<1.00.
- 18. Load scenario file, 2010 Scenario 4.scn, if required.
- 19. Provide turnover sheet along with IRM A Troubleshooting Form (Attachment 5).
BRIEFING SHIFT BRIEFING Plant Status Plant Status Unit startup is Unit is in in progress progress per per GP-03 GP-03 following a refueling refueling outage.
Reactor power Reactor power is is approximately 5%. Control Control rod rod withdraw is is in in progress per Step 5.1.5 of GP-03.
Reactor pressure is 925 psig with one bypass valve open to approx. 20%.
GP-10, sequence A2X, is being used and is complete up to Step 166.
Equipment Out of Service IRM A was declared inoperable early last shift due to spiking and is bypassed.
I&C Troubleshooting has determined that the instrument loop is functioning satisfactorily and that the spiking was due to welding near the pre-amp at that time.
Stable operation has been observed for the last 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />. The Ops Center SRO is evaluating IRM Operability.
Plan of the Day Continue with GP-03 actions to raise reactor power to 10% in preparation for placing the Mode switch to RUN.
Continuous control rod withdrawal is allowed per RE recommendation.
SCENARIO TRAINING SCENARIO TRAINING INFORMATION INFORMATION Instructor Notes Instructor Notes
- 1. This guide
- 1. This guide is is designed designed to meet the to meet the requirements requirements of of an an examination examination scenario scenario for for Initial License Initial License asas outlined outlined in NUREG-1021, in NUREG-1 Revision 9, 021, Revision ES-301 and 9, ES-301 and Appendix Appendix D. D.
- 2. During
- 2. During the execution of the execution of this this scenario, scenario, thethe students students should should be be rated rated on on the the performance of performance of the the objectives, objectives, compliance compliance with with general general simulator simulator performance performance standards, and standards, and for overall overall team skills skills in accordance with TAP-409 in accordance TAP-409 and and NUREG-NUREG 1021, ES-303.
1021, ES-303.
B.Common Student Student Problems/Errors None None C.Simulator Deficiencies There are no known simulator deficiencies applicable to this scenario.
D.CREW CRITICAL TASKS (Critical Tasks are identified to ensure scenario validity and do not constitute pass/fail pass/fall criteria for Initial License.)
- 2. Maintain RPV level above LL4
EVENT 1I SHIFT EVENT SHIFT TURNOVER, TURNOVER, RAISE RAISE REACTOR REACTOR POWER,POWER, IRM IRM CC FAILURE FAILURE The crew The crew will will continue raising power continue raising power by by pulling pulling control control rods rods in in preparation preparation for for placing placing the Mode the Mode switch switch to RUN.
to RU Rods pulls N. Rods pulls will will commence commence at at Step Step 166 (10-23 @
166 (10-23 @ 12)
- 12) of of the the A2X sequence.
A2X sequence. While While withdrawing withdrawing control control rod rod 10-23 10-23 from from position position 12, 12, IRM IRM C C will will fail fail upscale causing upscale causing aa rodrod block block and and half half scram.
scram. Unit Unit SRO SRO will will address address IRM IRM AA and and CC inoperability lAW inoperability lAW TS 3.3.1.1.
3.3.1.1. Once Once addressed, Ops Ops Center Center SRO SRO will report report IRM IRM A A is is ready to be ready be returned returned to service service following proper proper channel check. The crew crew will take the actions of the APP and bypass bypass IRM IRM C and reset reset the half half scram.
Objectives:
Objectives:
SRO SRO Directs and monitor reactor power ascension with control rods Direct actions for IRMIRM C failure.
Address IRMIRM C TS 3.3.1.1 RO Withdraw control rods to raise reactor power Monitor plant parameters during power ascension Perform actions for IRM C failure Success Path:
Technical Specification /I TRM
- 3.3.1.1 Reactor Protection System (RPS) Instrumentation Determines with IRMs A & C inoperable, Condition A. One or more required channels inoperable for Function 1 laa (IRM Neutron Flux-High.
FluxHigh.
Required Action A.1 (Place channel in trip) OR A.2 (Place associated trip system in trip) within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
Declare IRM A operable by channel check and bypass IRM C with tracking LCO for IRM C.
Simulator Operator Actions:
0o While continuously withdrawing control rods, verify Trigger #1 initiates to fail IRM C C upscale.
o0 If contacted as the RE for IRM CC inoperability, acknowledge request.
o0 When IRM CC inoperability has been addressed and by lead examiners direction, contact the control room as Ops Center SRO and report IRM A can be declared Operable following aa satisfactory channel check.
0o When directed by the lead examiner, proceed to the next event.
Required Operator Actions Instrument Failure -IRM IRM CC upscale rod block block and and half half scram.
Technical Specification Specification -IRM IRM CC inoperability and restore IRM A operability.
SRO Time Time Action Action Notes Notes Ensures Ensures no no other other distracting distracting evolutions evolutions are are in in progress progress while while reactivity controls controls are being manipulated.
are being manipUlated.
EVENT 1I SHIFT TURNOVER, RAISE EVENT RAISE REACTOR REACTOR POWER, POWER, IRM IRM C C FAILURE FAILURE SRO SRO Time Action Notes Notes Directs RO Directs RO to raise raise reactor reactor power power by by withdrawing control rods lAW GP-10.
GP-1O.
(Continuous withdrawal allowed).
Directs BOP to continue monitoring plant.
Directs APP reference.
Contacts I&C l&C for IRM C failure.
May contact Shift Manager also.
References TS 3.3.1.1 and determines with IRMs A & C inoperable:
Condition A is applicable for Function 11 a A. I OR A.2 is required Required Action A.1 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
TRM 3.3 (Control Rod Block Instrumentation) Function 3 Condition A, Required Action A.1 Restore channel to OPERABLE status within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Evaluates IRM A operability following check satisfactory channel check.
2OP-09, 20P-09, Attachment 4, 2.3.4 (Operability Guidance) - Channel Checks are a sufficient WO PMT for SRMs and IRMs at power unless a component failure is suspected in which case an IN curve and TDR trace is desirable.
Directs IRM A channel check be performed.
Determines IRM A is operable Directs removing IRM A from Bypass Directs bypassing bypassing IRM IRM C C Directs Directs resetting half half scram
I SHIFT TURNOVER, RAISE REACTOR POWER, IRM C FAILURE EVENT 1 RO Time Action Notes Commence rod withdrawal at step 166 of GP-10 per guidance of 01-01.02 20P-07 Continuous Rod Withdraw
- 1. ENSURE ROD SELECT POWER control switch is in ON.
- 2. SELECT desired control rod by depressing its CONTROL ROD SELECT push button.
- 3. ENSURE the backlighted CONTROL ROD SELECT push button is brightly illuminated AND the white indicating light on the full core display is also illuminated.
- 4. ENSURE ROD WITHDRAWAL PERMISSIVE indication has illuminated.
- 5. CONTINUOUSLY WITHDRAW control rod to position designated on GP pull sheets by holding EMERGENCY ROD IN NOTCH OVERRIDE switch to OVERRIDE, while simultaneously holding ROD MOVEMENT switch to NOTCH OUT.
- 6. MONITOR control rod position AND nuclear instrumentation while withdrawing the control rod.
- 7. PERFORM the following for control rods to be fully withdrawn:
- a. WHEN control rod reaches position 48, THEN PERFORM either of the following:
- MAINTAIN the continuous withdraw signal for the desired time
- APPLY a separate notch withdraw signal.
- b. ENSURE control rod does NOT retract beyond position 48. (ref. SR 3.1.3.4)
- c. RELEASE ROD MOVEMENT and EMERGENCY ROD IN NOTCH OVERRIDE switches, if used.
- d. ENSURE control rod settles at position 48 AND rod settle light extinguishes.
- e. ENSURE control rod reed switch position indicators agree with FULL OUT indication on full core display.
Stops withdrawing control rods when IRM C fails upscale. ROD OUT BLOCK Determines IRM C failed upscale.
I SHIFT TURNOVER, RAISE REACTOR POWER, IRM C FAILURE EVENT 1 RO Time Action Notes Responds and reports applicable alarms for IRM C failing upscale. A-5 1-7 REACTOR AUTO SCRAM SYS A 4-7 NEUT MON SYS TRIP 2-4 IRM UPSCALE 2-2 ROD OUT BLOCK 3-4 IRM A UPSCALE//NOP UPSCALE/INOP A-5 IRM A UPSCALE//NOP UPSCALE/INOP actions:
May Reposition range switch for IRM C to bring indicated power to between 15 and 50 on the 0-125 scale.
May verify IIRM RM C Drawer Selector switch (Control Panel H12-P606) is in OPERATE.
May notify SRO of Tech Spec applicability May inform SRO IRM C cannot be bypassed and half scram cannot be reset due to IRM A being bypassed.
Performs channel check of IIRM RM A for operability. RO DSR Item # 9 9 (IRM channel check) 201-03.2, Definition 5.1.
Removes IRM A from Bypass Bypasses IRM C per APP guidance.
Resets half scram per APP guidance.
BOP Time Action Notes Monitors reactor plant parameters during evolution.
EVENT EVENT 2 2 SHIFT SHIFT STEAM STEAM PACKING PACKING EXHAUSTERS EXHAUSTERS Maintenance will contact the control room and request SPEs be swapped due to low oil level in SPE A. Shift SPE lAW 20P-26.1, Section 8.
Objectives:
BOP 20-26.1, Section 8 Shift SPEs lAW 20P-26.1, Success Path:
SPE BB placed in service and SPE A shutdown lAW 20P-26.1, 2OP26. 1, Section 8.
Simulator Operator Actions:
D Following half scram reset and by direction of the Lead examiner, Contact the control room as Maintenance and request SPE A be shutdown due to low oil level to prevent equipment failure.
AC, when requested, report MVD-V52 is open, El As AO, D
o As AO, D AC, when requested, report MVD-V51 is closed.
0 When directed by the lead examiner, proceed to the next event.
D Required Operator Actions 20-26.1.
Normal Operation - Shift SPEs lAW 20P-26.1.
SRO Time Action Notes Direct RO to stop power maneuver and monitor plant while shifting SPEs.
Directs BOP to shift SPEs to remove A from service.
May direct continuing control rod withdrawal following SPE shift.
RO Time Action Notes Monitors plant while shifting SPEs.
BOP Time Action Notes Communicates maintenance request for shutting down SPE A to SRO.
Identifies 20P-26.1, Section 8.1 (Shifting Steam Packing Exhausters) is required.
EVENT 2 SHIFT STEAM PACKING EXHAUSTERS BOP Time Action Notes Notes Shifts SPEs Directs AO to OPEN FLOA FLOAT T TRAP MVD.-V52.
OUTLET VALVE, MVD-V52.
Makes plant PA announcement and Starts SPE B Ensures STEAM SEAL SPE 28 2B MO INLET VL VLV, V, OG-MOV-E2, is open.
Throttles closed STEAM SEAL SPE 2A MO DISCH VLV, OG-MOV-D1, AND Throttles open STEAM SEAL SPE 28 2B MO DISCH VLV, OG-MOV-D2, while maintaining GLAND EXHAUST HEADER, OG-PI-EPT-9, located on Panel XU-2, between 10 and 20 inches water vacuum.
May get annunciator UA-02 4-5 GLAND SEAL VACUUM LOSS OG-Pl-EPT9-SPE If Gland seal vacuum on OG-PI-EPT9-SPE drops below 55 inches of water.
Ensures STEAM SEAL SPE 2A MO DISCH VLV, OG-MOV-D1, is closed.
Makes plant PA announcement and Stops SPE A AO to close FLOAT TRAP Directs AC OUTLET VAL VALVE, VE, MVD-V51 Ensures STEAM SEAL SPE 2A MO IN LET VALVE, OG-MOV-E1, is closed.
INLET Informs SRO SPE shift is complete.
Notifies maintenance SPE A is shutdown.
EVENT 3/4 EVENT 314 RAISE REACTOR RAISE REACTOR POWER POWER ISTUCK ISTUCK CONTROL CONTROL RODROD Following SPE Following SPE shift, control rods shift, control rods will continue continue to to be be withdrawn until until control control rod rod 26-23 26-23 which is which is stuck stuck at position 12, at position 12, requires requires OP-O?
OP-07 actions actions toto move.
move.
Objectives:
Objectives:
SRO SRO Directs and Directs and monitor monitor reactor reactor power power ascension ascension with control control rods rods Direct actions actions for aa stuck stuck control control rod.
rod.
RO RO Withdraw control rods to raise reactor power power Perform 20P-07 actions for stuck control rod Perform Monitor plant Monitor plant parameters during power ascension BOP Monitor plant parameters during power ascension Success Path:
Control rod 26-23 withdrawn to position 48 by use of increase drive water DP and double clutch.
Simulator Operator Actions:
o If contacted as the RE for Control Rod 26-23 stuck, concur with 20P-07 guidance and double clutch withdrawal if requested.
oLi When drive water DP has been raised to 300 psid and RE concurrence, ensure Trigger #2 deletes RD012M when EMERGENCY ROD IN NOTCH OVERRIDE is placed in the EMERGENCY ROD IN position.
o Li When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity Manipulation - Raise reactor power by control rod withdrawal.
Component Failure - Control Rod 26-23 stuck at position 12.
SRO Time Action Notes Directs RO to continueto continue to raise reactor power by withdrawing control rods.
(Continuous withdrawal allowed).
20P-07.
May direct AOP-02 (Control Rod May malfunction) malfunction) -
Provides notifying RE and Using Using 20P-07 20P-07 to to move move rod.
EVENT 3/4 EVENT 3/4 RAISE REACTOR RAISE REACTOR POWER POWER ISTUCK
!STUCK CONTROL CONTROL ROD ROD SRO SRO Time Time Action Notes Notes May evaluate May evaluate Tech Tech Spec Spec 3.1.3 3.1.3 Control Control Rod Operability Rod Operability Condition A. One withdrawn control rod stuck Required Action A.1 Verify stuck control rod separation criteria are met (Immediately)
AND Required Action A.2 Disarm the associated control rod drive (CRD). (2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />)
AND Required Action A.4 Perform SR 3.1.1.1(72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />) 3.1.1.1.(72 May evaluate TS 3.1.3, Control Rod Operability, AND 3.3.2.1, Control Rod Block Instrumentation before performing procedure.
Should not declare control rod stuck until actions of 20P-07 have been attempted.
Separation criteria is met (no identified slow rods)
Obtains RE concurrence for double clutching control rod with elevated drive water DP.
RD RO Time Action Notes Continues rod withdrawal per GP-10 lAW guidance of 01-01.02 and 20P-07.
Report A-6 2-7 APRM DOWNSCALE Reporf annunciator clears.
Recognizes control rod 26-23 is stuck.
Notifies SRO control rod 26-23 is stuck.
Identifies Identifies 2OP-07, 20P-07, Reactor Manual Manual Control System System Operating Procedure, Procedure, Section 8.2 8.2 (Control Rod Difficult to Withdraw, Control Control Rod NOT NOT at Position 00)
- 00) is is required.
314 EVENT 3/4 RAISE REACTOR POWER ISTUCK CONTROL ROD RO Time Action Notes Notes Notifies SRO to consult TS 3.1.3 &
3.3.2.1.
Verifies no Rod Blocks.
Raises drive water DP to 300 psid.
May use 20P-08, Section 8.29 (Adjusting CRDHS Parameters)
Maintains CRD flow rate 30 to 60 gpm
- . May raise CRD flow and/or throttle closed DRIVE PRESSURE VLV, Cl 2-PCV-F003 C12-PCV-F003 Attempts to withdraw control rod 26-23 Normal withdraw attempts may be repeated at elevated drive water DP.
Notifies SRO double clutching is required.
Verifies RE concurrence.
Momentarily places EMERGENCY Deletes malfunction Trigger #2 ROD IN NOTCH OVERRIDE in EMERGENCY ROD IN.
Simultaneously places EMERGENCY ROD IN NOTCH OVERRIDE in OVERRIDE AND ROD MOVEMENT in NOTCH OUT.
Recognizes control rod withdraw and stops to return drive water DP back to normal (260 - 275 psid)
Once fully withdrawn, control rod is inserted to 46 and withdrawn to 48 under normal drive water DP.
Performs coupling check following fully withdrawing control rod to position 48.
BOP Time Action Notes Monitors plant while control rods are being withdrawn.
EVENT 5 HCU 30-07 ACCUMULATOR LOW PRESSURE When directed by Lead examiner, HCU 30-07 accumulator light and annunciator will alarm. AO AC will be dispatched to investigate and determine accumulator alarm is due to low pressure and requires charging. TS 3.1.5 evaluation will be required.
Objectives:
SRO Direct actions for inoperable CRD accumulator.
Address TS 3.1.5 RO/BOP ROIBOP Perform actions for HCU accumulator alarm Success Path:
Technical Specification /I TRM
- 3.1.5 Control Rod Scram Accumulators Determines Condition C. One or more control rod scram accumulators inoperable with reactor steam dome pressure < 950 psig.
Required Action C.1 Verify all control rods associated with inoperable accumulators are fully inserted Immediately.
AND C.2 Declare the associated control rod inoperable within 1 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
Simulator Operator Actions:
LI When directed by the Lead examiner, activate Trigger #3 to cause accumulator D
alarm and annunciator for HCU 30-07.
LI If contacted as AO D AD to investigate, acknowledge request, wait 2 minutes and report the red indication light is ON for the affected HCU 30-07 at the local panel.
LI When directed by to depress the red light, report light stays lit and accumulator D
pressure is at 930 psig.
LI D After Tech Spec declaration is made, delete CRD ACCUM LO PRESS/HI LEVEL (ZA761) and ACCUM-ROD DISPLAY (Q2BXPUAD (Q2BXPUAD)) and report HCU 30-07 has been re-charged with final accumulator pressure equal to 1140 psig.
LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Component Failure - HCU accumulator low pressure Technical Specification - 3.1.5 SRO Time Action Notes Directs APP actions Direct contingency plans to monitor the other accumulator alarms due to masking.
Directs charging the accumulator per 20P-08.
20P-OB.
EVENT 5 HCU 30-07 ACCUMULATOR LOW PRESSURE SRO Time Action Notes Determines TS 3.1.5 applicability Determines Condition C. One or more control rod scram accumulators inoperable with reactor steam dome pressure << 950 psig.
Required Action C.1 Verify all control rods associated with inoperable accumulators are fully inserted Immediately.
AND C.2 Declare the associated control rod inoierable within 11 hour1.273148e-4 days <br />0.00306 hours <br />1.818783e-5 weeks <br />4.1855e-6 months <br />.
inoperable RO Time Action Notes Acknowledges and reports to SRO annunciator A-7 6-1 CRD ACCUM LO PRESS/HI LEVEL Directs AO to investigate.
Directs AO to determine if alarm is due to low pressure or high water level in the HCU by depressing the lighted indication on the local HCU panel and observing the status of the light (light out indicates water).
Directs charging the accumulator per 20P-08 Reports to SRO annunciator A-7 6-1 CRD ACCUM LO PRESS/HI LEVEL is clear.
BOP Time I Time IAction Action Monitors plant Notes I Notes
EVENT 6/7 617 MSIV CLOSURE, REACTOR SCRAM, SRV F FAILS OPEN MSIV When HCU 30-07 accumulator is re-pressurized and TS addressed, a spurious Group 11 isolation (MSIV closure) causes reactor pressure and power rise. Manual Manual SRV opening or Scram may be performed. HPCI and/or RCIC may be manually started to control RPV water level due to loss of RFPTs.
Objectives:
SRO Direct manual scram and pressure control Directs entry to AOP-14 Enters RSP, RVCP, PCCP RO/BOP ROIBOP Diagnose loss of pressure control Diagnose SRV F failing open Perform SCRAM actions Control reactor parameters post SCRAM Success Path:
Manual reactor scram inserted with pressure being controlled Simulator Operator Actions:
o When HCU 30-07 accumulator is re-pressurized and TS addressed and by direction of the Lead examiner, activate Trigger 5.
o L If contacted as I&C to investigate MSIV closure, Acknowledge request.
o Ensure Trigger 6 automatically actuates 2 minutes after MSIV closure.
o D If contacted as Ops Center SRO to pull fuses for SRV F, acknowledge request and activate Trigger 11 one minute later and report fuses pulled.
o D If contacted as I&C to investigate SRV F opening, Acknowledge request.
Required Operator Actions Major - Reactor scram Component Failure - SRV F fails open SRO Time Action Notes Direct manual scram insertion.
Direct manual pressure control.
Enters and directs EOP-01-RSP Determines entry into EOP-01-RVCP is req ui red required Directs AOP-30 entry Directs LEP-02 to reset scram.
EVENT 6/7 617 MSIV CLOSURE, REACTOR SCRAM, SRV F FAILS OPEN SRO Time Action Notes verification Directs verification:
- . Group Isolations Isolations
- . ECCS Initiations
- . Diesel Generator Auto Starts Directs restoring and maintaining reactor water level between +170 and +200 inches with one or more of the systems listed in Table 11
- . CRD (SEP-09)
Direct RHR be placed in suppression pool cooling Directs starting RCIC to maintain level May direct starting HPCI to maintain level May direct utilizing SLC aligned to Demin (LEP-Ol).
Water (LEP-01).
RD RO Time Action Notes Inserts a manual scram as directed by SRO Performs scram immediate actions:
1.
- 1. Unit 2 Only: After steam flow is less than 33 x 106 106 lb/hr, Ib/hr, PLACE the reactor mode switch to SHUTDOWN.
- 2. IF reactor power is below 2% (APRM downscale trip), THEN TRIP the main turbine.
ENSURE the master reactor level controller
- 3. ENSURE setpoint is +170.
+ 170".
IF two reactor feed pumps are running, and
- 4. IF is above +160 reactor vessel level is +160" and rising, then trip one.
Reports Scram immediate actions complete All rods in, Mode Switch in shutdown
EVENT 617 EVENT 6/7 MSIV CLOSURE, MSIV CLOSURE, REACTOR REACTOR SCRAM,SCRAM, SRV FF FAILS FAILS OPEN OPEN RO RO Time Action Notes Notes Maintains RPV Maintains RPV level level 170-200" 1 70-200 Reports when Reports when out out of of band band and and actions actions to to address address recovery.
recovery.
Diagnoses loss of Feedwater flow to RPV Recognize SRV F failed opened.
Enter and announce AOP-30.0 Performs AOP-30 immediate actions:
- 1. Cycles the control switch of the affected safety/relief valve to OPEN and CLOSE OR OPEN and AUTO several times.
- 2. Ensures the affected safety/relief valve control switch is left in CLOSE OR AUTO.
- 3. Contacts Ops Center SRO to pull fuses for SRV FlAWF lAW OAOP-30, Attachment 11 Recognizes SRV control power fuses pulled (no position indication and AUTO DEPRESS CONTROL PWR FAILURE)
Manually starts RCIC to maintain RPV level May perform SEP-09, CRD Flow Maximization with procedure or Hardcard.
May start HPCI to maintain level or pressure.
BOP Time Action Notes Diagnoses Diagnoses lossloss of Feedwater flow to RPV Announces Unit Unit Two reactor scram
EVENT 6/7 617 MSIV CLOSURE, REACTOR SCRAM, SRV F FAILS OPEN BOP Time Action Notes May perform SCRAM Hardcard actions.
- 1. Ensure
- 2. Control Reactor Pressure Between 800 and 1000 psig
- 3. Control Reactor Water Level Between +170 and +200 Inches
- 4. Place SULCV in Service
- 5. Insert Nuclear Instrumentation
- 6. Ensure Turbine Oil System Operating Enter and announce AOP-14.0 AOP-14.O Place RHR in suppression pool cooling
EVENT 8/9/10 SRV TAIL PIPE RUPTURE, SPRAY FAILURES With SRV F F failed open and reactor pressure approaching 700psig, the tail pipe will rupture causing direct pressurization of the Suppression Pool air space (loss of PSP).
Suppression chamber and drywell pressure rapidly rise. Suppression chamber pressure leads drywell pressure and torus-drywell vacuum breakers lifting indicate broken SRV tailpipe When containment spray is attempted with the A RHR Loop, the Spray logic will fail to actuate, making sprays unavailable. Emergency depressurization will be required due to pressure suppression pressure limit. Logic will be available following ED.
When containment spray is attempted with the B El l-F028B will trip on B RHR Loop, the E11-F028B thermal overload. RHR Loop B B will be the only loop available to provide DW OW Spray lAW SEP-02. Emergency depressurization will be required due to pressure suppression pressure limit. Valve will be available following ED.
Objectives:
SRO Direct entry into PCCP Direct Emergency Depressurization when loss of PSP is recognized.
RO/BOP ROIBOP Diagnose and report rapidly rising containment pressures Determine leak is in suppression chamber based on higher suppression chamber pressure Attempt to initiate spray per SEP-02 and/or SEP-03 Diagnose and report failure of Loop BB spray logic Success Path:
Emergency depressurize the RPV and restore RPV water level followed by aligning RHR for SP Spray.
Simulator Operator Actions:
o LI Monitor RPV pressure and ensure Trigger 7 activates when RPV pressure drops below 700 psig.
o l&C for RHR A Spray logic failure, acknowledge request.
Li If contacted as I&C o Ell-F028B overload, acknowledge request.
l&C for RHR B E11-F028B Li If contacted as I&C o
Li If contacted as AO for RHR B Ell-F028B E11-F028B overload, acknowledge and request breaker location MCC (2XB-2)
Required Operator Actions Component Failure - SRV F tailpipe failure Major - Emergency Depressurize the RPV SRO Time Action Notes Enters and Directs PCCP Directs SP Spray lAW SEP-03 before Suppression Chamber pressure reaches 11.5 psig
EVENT 8/9/10 EVENT 8/9/10 SRV TAIL PIPE SRV PIPE RUPTURE, RUPTURE, SPRAYSPRAY FAILURES FAILURES SRO SRO Time Time Action Notes Notes Directs OW Directs DW Spray Spray lAW lAW SEP-02 SEP-02 when Suppression Chamber Suppression Chamber exceeds exceeds 11.5 1 1.5 psig psig Determine leak is in suppression chamber based on higher suppression chamber pressure Directs I&C for RHR A Spray logic failure.
El 1-F028B failure Directs I&C for RHR E11-F028B When PSPL exceeded, determine emergency depressurization is required Directs Emergency Depressurization RO/BOP Time Action Notes Diagnose and report rising containment pressures.
Diagnose SRV F tailpipe rupture
- SP to OWDW vacuum breakers open
- . SP pressure> DW pressure OW Place RHR Loop A into suppression pool RHR Loop A remains available for SPC only cooling, cooling. a LOCA signal is recieved.
until a
- SW-Viol Open SW-V101
.* Close SW-V143
.* If LOCA signal is present place RHR SW Booster Pumps A & &CC LOCA override switch to manual override
.
- StartRHRSWPump Start RHRSW Pump
.* Adjust El1-PDV-F068A E11-POV-F06SA (1 pump 2000 - 4000 gpm)
(2 pumps 5000 - 8000
- SOOO gpm)
.* Supply Cig Clg Wtr to Vital Hdr
.
- Verify spray logic logic is made made up up I
.
- Start Loop Loop A RHR Pmp
.* Open Ell-F028A E 11-F028A
.* Throttle El1-F024A E 11-F024A (1 pump pump 6000-6000 - 10000 10000 gpm) gpm)
(2 (2 pumps 6000-6000 - 11500 11500 gpm) gpm)
. Throttle E11-F048A E 11-F048A
819110 EVENT 8/9/10 SRV TAIL PIPE RUPTURE, SPRAY FAILURES RO/BOP Time Action Notes Diagnose and report RHR Loop A Spray Logicfailure Logic failure Initiate suppression chamber spray per SEP-03.
- If necessary, then place Loop B 2/3 CORE HEIGHT LPCI INITIATION OVERRIDE SWITCH, E11-CS-S18B, in Manual Overrd.
- If the CTMT SPR OVRD light for the Loop B CONTAINMENT SPRAY VALVE CONTROL SWITCH, E11-CS-S17B is not on, then momentarily place Loop B CONTAINMENT SPRAY VALVE CONTROL SWITCH, E11-CS-Eli-CS S17B, to Manual
- Ensure at least one RHR Loop B B Pump is operating
- Ensure TORUS DISCHARGE ISOLVLV, ISOL Ell-F028B, is open VLV, E11-F028B,
- Open TORUS SPRAY ISOL VLV, El l-F027B.
E11-F027B.
Diagnose and report RHR Loop B B E11-Eli F028B overload.
Dispatch AO to RB MCC 2XB-2 to attempt thermal reset for E11-F028B Eli-F028B overload.
Report RHR Loop B is only available for DW Spray operation.
819110 EVENT 8/9/10 SRV TAIL PIPE RUPTURE, SPRAY FAILURES RO/BOP RO/BOP Initiate Drywell Initiate Drywell Spray per per SEP-02
- Ensure both reactor recirculation pumps are tripped
- Place all drywell cooler control (LIO) switches to OFF (LlO)
- Request Drywell Cooler override switches to STOP.
- Confirms the following:
- Drywell pressure and drywell SAFE temperature are in the "SAFE" region of the DSIL graph.
- Suppression pool water level is below +21 inches.
- Throttle open Loop B DRYWELL SPRAY OTBD ISOL ISOLVLV, Eli VLV, E11-FO16B, F016B, to obtain between 8,000-10,000 gpm flow
EVENT 11 EMERGENCY DEPRESSURIZATION, CONTAINMENT SPRAY Once the reactor is depressurized and DW OW & & SP Sprays are in service, with RPV water level being maintained in the normal band, the scenario may be terminated.
Objectives:
sco seo Directs actions Emergency Depressurization and restoration of reactor water level.
Direct drywell and torus spray per SEP-02 and SEP-03 following level restoration.
ROIBOP RO/BOP Performs actions for emergency Depressurization and restoration of reactor water level.
Places RHR Loop A in Suppression Chamber and DW OW spray Success Path:
Restore reactor water level to 170-200 inches.
RHR Loop has been placed in SP & & OW DW Sprays Simulator Operator Actions:
Instructor Activities Li Following emergency depressurization actions and by direction of the Lead D
K1227A examiner, DELETE K1227 l&C to report A overrides and contact the control room as I&C RHR A Spray logic has been repaired.
LI Following emergency depressurization actions and by direction of the Lead D
examiner, DELETE Q1717LGN, RRN,& ZA358 overrides and report as AO the thermal overload has been reset for the E11-F028B.
abovel70 with DW & SP spray in service, the Li When RPV level is being controlled above170" D
scenario may be terminated LI When directed by the lead evaluator, place the simulator in FREEZE.
D Required Operator Actions Emergency Depressurize the RPV Restore and maintain RPV level above LL4 SRO Time Action Notes Determine Emergency Depressurization is required.
Direct placing 7 ADS valve switches to open.
Direct RPV level be restored and maintained +170-200 inches Evaluate level instruments lAW Caution 1.
EVENT EVENT 1111 EMERGENCY EMERGENCY DEPRESSURIZATION, DEPRESSURIZATION, CONTAINMENT CONTAINMENT SPRAY SPRAY SRO Time Action Notes Directs controlling condensate injection when RPV pressure is less than 440 psig.
Directs controlling Low Pressure ECCS injection when RPV pressure is less than 400 psig Directs DW and SP spray when level is being controlled.
ROIBOP RO/BOP Time Action Notes Places 77 ADS valve control switches Operates LP ECCS to restore and maintain RPV level 170-200 inches.
/eve/170-200 LPCI injection.
Re-align RHR for LPGI Ensures Drywell Sprays / SP Sprays /
Cooling removed from service Torus Gooling Low Pressure EGGS ECCS systems may be overridden to prevent uncontrolled injection.
Termination Cue When RPV water level is being maintained above 170 inches with a Loop of RHR spraying the DW and Suppression Pool, by direction of the Lead examiner, the scenario may be terminated.
Simulator Operator Activities:
WHEN directed by the lead examiner, place the simulator in FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER
ATTACHMENT 5 R R
Refere nec Reference Page 1 1 of 11 Use Neutron Monitoring Spiking Troubleshooting Form
- 1. Initiatol~S name Unit Two SRO Initiators SRQ
- 2. Check all instruments that are spiking and the associated Unit:
oJ Unit 1 I o SRM A SRMA IRM A IllIRM D Li IRME IRM E III JUnit2 Unit2 D DSRMSSRMB o DIRMBIRMB D LI IRMF IRM F oLISRMC SRMC oLIIRMC IRMC oLI IRMG o SRMD DSRMD D IRMD DIRMD D LI IRM H IRMH
- 3. Time and date of event Today Previous Shift Today*
- 4. \Nhat What is the duration of the spiking (duration ofof individual spike)? Add additional information below to characterize spiking event.
o Seconds III Minutes D Hours
- 5. Ensure all required observations to support operability are appropriately documented.
- 6. Has a INOWO or AR been initiated?
If yes, list number(s): 00345765 00346765 ~Yes Yes fl No DNo
- 7. Has a log entry been made? ~Yes Yes U No nNo
- 8. Is there any welding occurring in the plant? elYesYes DNo No 9.
9, Are there any personnel under-vessel? fl Yes nYes !;ZI No
- 10. At-c Are there any plant evolutions in progress? ~Yes Yes DNo No
- 11. Is there any electrical switching occurring? [lYes nYes 171 No
- 12. Are any control rods being moved or selected? Yes h7!Yes DNo No
- 13. Has there been a recent change in the mode switch? nYes Yes bl! No
- 14. Is there any major equipment being started? !;Zj Yes fl No DNo
- 15. Has there been any observed relay chatter? DYes Yes ~No No
- 16. Is there any refuel bridge movement? p Yes nYes III No
- 17. Are the rod interlocks being affected? ~Yes j Yes DNo No
- 18. Completed copy of this attachment sent to engineer Yes VlYes nNo No PLease note below any additional Please addItional information that may aid troubleshooting (such as 2 instruments spiking but not in the same manner):
Multiple upscale and downscale alarms during startup over a 15 minute period. All other IRMs responded normally.
20P-09 120P-09 Rev. 28 Page 38 of 39139
PROGRESS ENERGY PROGRESS ENERGY CAROLINAS CAROLINAS BRUNSWICK TRAINING SECTION BRUNSWICK SIMULATOR EXAM SCENARIO 2010-1 NRC Exam Scenario #5
}
Appendix D Scenario Outline Form ES-D-1 Facility: Brunswick Scenario No.: 2010-1 #5 Op-Test No.: Draft Examiners: Operators:
Initial Conditions: The unit is operating at approximately 92%, end of cycle. Coast-down is in progress. FFTR has not been implemented. RCC Pump 2B is under clearance. APRM 2 is failed low and bypassed.
Turnover: Maintain maximum power for current plant conditions.
Event MaIf.
Malf. Event.
Event, Event No. No. Type*
Type* Description 11 1 1 C-BOP NSW pump trip w/failure of standby (AOP)(TS)
C-SRO 2 2 C-RO SLC Continuity Failure (TS)
C-SRO 3 NA N-BOP Oil leak develops on RFP A. Oil tank low level alarms.
N-SRO RFP A removed from service.
3 NA R-RO Power reduction to shutdown RFP.
(Cont)
(Con't) R-SRO 4 3 C-RO Recirc MG Set cooling loss. Fails to trip on high oil temp C-SRO requiring manual trip. Operation in SAR requires exit (AOP)(TS) 5 4 C-BOP Sub E7 trips on fault resulting in total loss of RCC. Actions C-SRO for total RCC loss including manual scram. (AOP) 5 5 N/A Several control rods fail to fully insert on the scram and must (Cont)
(Con't) be manually inserted 6 NA M-All M-AII Small steam leak in the drywell, rising drywell temp & press (already_elevated_due_to_loss_of_RCC)
(already elevated due to loss of RCC) 77 6 C-RO Drywell spray on RHR Loop B B fails to function (Loop A spray C-SRO not available due to E7 loss). Drywell temp exceeds 300°F
- (N)ormal, (R)eactivity, (R)eactlVlty, (l)nstrument, (I)nstrument, (C)omponent, (M)ajor (M)aJor NRC NRC #5 Page 22 of of 31 Rev.OO
SCENARIO DESCRIPTION SCENARIO DESCRIPTION The plant The plant is is operating operating atat 92%
bypassed. NSW NSW Pump Pump 2B 2B shaft shaft will seize will seize and 2A NSW NSW pump will fail to auto start.
After the pumps have have been shifted, the continuity light bulb bulb will blow on the A squib Valve. With the monitoring system system is system inoperative the system is inoperative, so so declaration of TS 3.1.7 would be declared. The light bulb is replaced and the TS can be exited.
After the SLC failure, an oil leak will develop on REP RFP 2A oil system. A low level alarm will be received. The crew should reduce power and shutdown RFP 2A. The pump will
- 20 minutes if still running.
trip in 20 After RFP 2A has been shutdown, the temperature controller for Recirc MG Set 2A will fail closed. Oil temperature will rise causing an alarm, then a trip condition. The Recirc MG Set will fail to auto trip and must be manually tripped. The flow reduction will place the plant in the Scram Avoidance Region of the Power/Flow Power/Elow map, requiring immediate exit by control rod insertion or raising flow (not to exceed SLO limits).
Substation E7 trips on fault resulting in loss of all associated loads. RCC Pumps 2A and 2C are lost resulting in complete loss of RBCCW and drywell cooling. This condition requires a manual reactor scram and securing RCC system loads (RWCU, Recirc Pumps, CRD Pumps).
Several control rods fail to insert fully on the scram and must be inserted per LEP-02.
CRD Pumps should be left running until rods are inserted. 120 VAC power panel 2AB must be transferred to alternate E8 power for rod insertion.
The loss of drywell cooling will result in rising drywell temperature and pressure.
Drywell pressure will exceed 1.7 psig requiring entry into PCCP and RVCP (or LPC until rods are inserted).
A small steam leak will develop in the drywell. Drywell temperature and pressure rises at a faster rate requiring initiation of drywell sprays. RHR Loop 2A is unavailable for spray due to loss of E7 E7 (valve (valve power).
power). When RHR RHR 2B isis placed placed in drywell spray, the outboard spray valve (F016B) (FO16B) will fail. With no no spray available, drywell temperature will exceed 300°F 300°E (cannot be restored restored and maintained below) requiring emergency depressu rization.
depressurization.
During During the depressurization, depressurization, low low pressure pressure injection injection systems Core Spray (RHR, Core systems (RHR, and Spray and Condensate)
Condensate) must must be be operated operated to to prevent prevent uncontrolled uncontrolled injection.
injection.
When When emergency emergency depressurization depressurization actions have been actions have the scenario performed, the been performed, may be scenario may be terminated.
terminated.
NRC NRC #5 #5 Page Page 33 of of 31 31 Rev. 00 Rev.OO
OBJECTIVES SRO 341219B102, Direct Actions To Lower Reactor Power From Rated to 55% Including Removal Of One Feed Pump From Service Per GP-05 & & GP-12 344209B402, Direct Shift Response To Recirculation Pump Trip Per AOP-04.0 344219B402, Direct Shift Response To RBCCW Failure Per AOP-16.0 344237B402, Direct Actions For A Loss of Any 4KV Buses or 480V E Buses Per AOP-36. 1 AOP-36.1 3442 14B502, Direct Actions To Control Primary Containment Pressure Per EOP 344214B502, PCCP 344215B502, Direct Actions To Control Primary Containment Temperature Per EOP-EOP 02-PCCP 344220B502, Direct Actions To Emergency Depressurize The RPV Per EOP RVCP RO 202202B101, 202202B1 01, Decrease Reactor Recirculation Pump Speed/Reactor Power Using The Manual Control Station Per OP-02 259204B1 01, Secure The First Reactor Feed Pump Per OP-32 202017B401, Respond To Recirc Pump Trip(s) Per AOP-04.0 208011 B401, Respond To A RBCCW System Failure Per AOP-1AOP-16 6 262005B401, 262005B40 1, Respond To A Loss Of 4160 VAC or 480 VAC Emergency Bus( Bus(es) es) Per AOP-36.1 201 041 B501, Insert Control Rods With Reactor Manual Control System Per EOP 201041 LEP-02 200049B501, Spray The Drywell Per EOP-01-SEP-02 EOP-01 -SEP-02 NRC #5 Page 44 of 31 Rev.OO Rev.00
SIMULATOR SETUP Initial Conditions Initial IC-25 E ven t T*
Event Triggers riggers Event Trigger Description 11 Manually Initiated (NSW Pump Trip) 2 Manually Initiated (SLC Continuity Alarm) 3 Manually Initiated (RFP Manually (REP A Oil Leak) 4 Manually Initiated (Recirc MG Set Loss Cooling) 5 Manually Initiated (Sub E7 Trips) 6 Auto Initiated (ZA624 =
TRUE, Fluid Drive A Scoop Tube Lock alarm) 7 Manually initiated (Steam Leak in Drywell) 8 Auto Initiated (K1J36EEN[OPEN]
= TRUE, E11-F016B E11-FOI6B Control Switch Open)
Malfunctions Event System Tag Title Value Activate Deactivate (Ramp) Time Time A RC RCO28F RC028F Recirc A Auto Trip Fail NA o0 SEC NA A NI N1032F NI032F APRM 2 Fails Low NA OSEC 0 SEC NA 1I CW CWO23F CW023F NSW Pmp Shaft Seizure (B) NA o0 Sec NA 8 CF CFD27F CF027F REP 2A Lube Oil Leak RFP NA 30 MIN NA 4 RC RCOI7F RC017F Recirc MG A Cool Wtr Loss NA OSEC 0 SEC NA 5
5 DG DGOI5E DG015F LossOfSubE7 Loss Of Sub E7 NA oOSECSEC NA 6 NB NBOO6F NB006F MSL Break 2% OSEC 0 SEC NA 10 MIN A RP RPOO8F RP008F ATWS ATWS#1 #1 NA 0OSECSEC NA Switches Event Panel Tag Title Value Activate Deactivate (Ramp) Time Time A XU-2 K4520A NSW Pump A Man o0 SEC NA A XU-2 RCCPumpB RCC Pump B Off OSEC OSEC_- NA NRC #5 Page5of3l Page 5 of 31 Rev.OO
LLamps amps Event Event Panel Panel Tag Title Value Activate Deactivate Deactivate (Ramp)
(Ramp) Time Time A P601 Q1J36LGN E11-FOl6BGreen E11-F016B Green ON oOSEC SEC NA 2 P603 Q2201 LOA Q2201LOA A Squib Valve Ready Off 0 SEC OSEC NA A XU-2 Q4521 RR4 Q4521RR4 2B RCC Pump Green Off 0 SEC OSEC NA Alarms Event Panel Tag Title Value Activate Deactivate (Ramp) Time Time 3 XU-2 ZUA442 REP A Oil Level Hi/Low RFP ON 0 SEC OSEC NA 7 P603 ZA623 Recirc MG A Drive Trip ON 0 SEC OSEC NA 9 P601 ZA358 VIv Mtr Overload RHR B Vlv ON 0 SEC OSEC NA 2 P603 ZA445 Squib Valve Cont Loss Remote Functions Event System Tag Title Status Activate A RH ZVRHI6BT ZVRH16BT Ell-FO16B E11-F016B OFF o0 SEC 11 ED ZEIDHO8, ZEIDH08, Transfers AB Panels to Alternate Alt Hil HXO, H11 (2AB-RX, 2AB, 32AB) o0 Sec ec 12 RP IBZNORM RPS to Alternate Alt o0 Sec IAEPAALT EPA Breakers Set Set 10 Sec NRC #5 Page 66 of 31 Rev.DD Rev.OO
Special Instructions Ensure Exam In Progress Stop Signs posted at all simulator entrances.
Advance all chart recorders to indicate steady state conditions.
Place all SPDS displays to the Critical Plant Variable display (#100).
Ensure appropriate keys have blanks in switches.
Exit shutdown screen on RWM and place the RWM key in the key locker.
Reset alarms on SJAE, MSL, and RWM NUMACs.
Ensure reference material is in appropriate location.
Verify any log books have blank sheets only and procedures are not marked.
Bypass APRM 2 and place EC tag on bypass switch.
Place a red cap on 2B RCC pump.
Load malfunctions/overrides or scenario file if available.
Ensure ENP-24 for IC-25 @@ P603.
NRC #5 Page 77 of 31 Rev.00 Rev.OO
SHIFT BRIEFING Plant Status 92% power. End of cycle coast-down is in progress. Final The plant is operating at :::::92%
Feedwater temperature reduction per GP-13 has not been implemented.
Equipment Out Of Service APRM Channel 2 is failed downscale and bypassed. I&C is investigating the cause of the failure.
2B RCC Pump is under clearance due to high vibrations. Return to service expected 28 in 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />.
No other equipment is out of service.
Plan of the Day Maintain maximum achievable power.
No other activities are scheduled for this shift.
NRC #5 Page 88 of 31 Rev.OO
SCENARIO TRAINING SCENARIO TRAINING INFORMATION INFORMATION Instructor Notes Instructor Notes This guide This guide isis designed designed to to meet meet the requirements of the requirements of an an examination examination scenario scenario for for Initial Initial License License as outlined in as outlined NUREG-1021 (Draft in NUREG-1021 (Draft Rev Rev 9), ES-301 and 9), ES-301 and Appendix Appendix D.D.
During the During the execution execution of of this this scenario, scenario, the the students students should should be be rated rated on on the the performance of performance of the the objectives, objectives, compliance compliance with with general general simulator simulator performance performance standards, and standards, and for overall team for overall skills in team skills accordance with in accordance with TAP-409 TAP-409 and and NUREG-1021, NUREG-1021, ES-303.
Common Student Common Student Problems/Errors Problems/Errors None noted to date.
None Simulator Deficiencies There are no known simulator deficiencies applicable to this scenario.
Critical Tasks Insert control rods per LEP-02.
Depressurize the reactor when drywell average air temperature cannot be restored and maintained below 300°F by performing or anticipating emergency depressurizat depressurization.ion.
Reason For Revision New scenario.
NRC#5 NRC #5 Page9of3l Page 9 of 31 Rev.OO Rev.00
EVENT 1 I SHIFT TURNOVER, NSW PUMP TRIP The crew will complete shift turnover and a NSW pump will trip and the standby will fail to start. The standby can be manually started.
Malfunctions required: Shaft Seizure for B NSW pump and auto start failure of A NSW pump.
Objectives:
SCO - Directs standby NSW pump to be started.
Success Path:
Standby NSW Pump is started and pressure is returned to normal.
Simulator Operator Actions:
oL When directed by the lead examiner, initiate Trigger 1, I, to fail B NSW pump.
ou If contacted as AO to perform pre-start checks for the A NSW Pump, report pre-start checks are completed.
o If contacted as Unit One, report one of the NSW pumps are inoperable.
o Acknowledge the request for IC to investigate the trip of B NSW Pump.
oLI When directed by the lead examiner, proceed to the next event.
Required Operator Actions Component - Start standby NSW pump.
TS 3.7.2 - Condition B, With One required NSW pump inoperable for reasons other than Condition A, Restore required NSW pump to OPERABLE status in 7 days.
SRO Time Action Notes Direct entry into OAOP-18.0, NSW System Failures.
Direct start of standby NSW Pump Makes TS determination. From the Bases:
The SW System is considered operable when TS 3.7.2 - Condition B, With One it has two operable CSW pumps (specifically required NSW pump the CSW 2A and CSW 2C pumps), three site NSW pumps (any combination of Unit 11 and inoperable for reasons other Unit 2 2 NSW pumps), and an operable flow than Condition A, Restore path capable of taking suction from the intake required NSW pump to structure and transferring the water to the OPERABLE status in 7 days ECCS equipment and the DGs.
NRC#5 NRC #5 Page 10 of 31 Rev.OO Rev.00
EVENT 1I (Cont'd)
EVENT (Contd) SHIFT TURNOVER, NSW NSW PUMP PUMP TRIP RD RO ITime Time Action I Action Plant Monitoring Notes I Notes BOP Time Action Notes Announce and enter OAOP-18.0 Announce UA-01 annunciators, 1-10, NUCLEAR HDR SERV WTR PRESS-LOW PRESS-LOW.
4-10, NUCLEAR HDR SW PUMP B TRIP Announce UA-18 annunciator 6-1, BUS E4 4KV MOTOR OVLD Start Standby NSW Pump as directed by either the APP or the AOP when system pressure is <40#.
NRC#5 NRC #5 Pagellof3l Page 11 of 31 Rev.DD Rev.00
EVENT 2 EVENT SLC SQUIB VALVE LIGHT LIGHT BULB BULB FAILURE FAILURE crew will respond The crew respond to the lossloss of the 2B SLC SLC pump pump and makemake the TS declaration.
Malfunctions required: 2A SLC Squib Valve Continuity Light to off and Annunciator A-04 4-5, SQUIB VALVEVALVE CONTINUITY LOSS.
Objectives:
SCO - Determines applicable TS.
Success Path:
TS 3.1.7 determination.
Simulator Operator Actions:
oLI When directed by the lead examiner, initiate Trigger 2, to extinguish the A Squib Valve Continuity light and activate Annunciator A-04 4-5.
oLI If contacted as AO AC to check the SLC Circuit Supply Breaker, Circuit 12 on Emergency 120V 1 20V AC Distribution Panel 2AB, report that it looks normal.
oLI If asked for indications on the back panels report that on P624 SLC Explosive Squib Valve Continuity Meter, C41-M600A, is reading 0 milliamps and SLC C41-FOO4A continuity light is off.
Explosive Squib Valve C41-F004A oLI If requested for IC to investigate circuit, wait until TS call has been made then C41-FOO4A continuity light bulb on the report SLC Explosive Squib Valve C41-F004A P624 panel is burnt out.
o LI When requested to replace the SLC Explosive Squib Valve C41-F004A C41-FOO4A continuity light bulb on the P624 panel then delete override for the light LCA) and the Annunciator (ZA445).
(Q2201 LOA) o LI When directed by the lead examiner, proceed to the next event.
Required Operator Actions TS determination - 3.1.7, Condition A, Restore SLC to operable status in 77 days.
SRO Time Action Notes Determines TS declaration for the time that the light bulb is blown:
TS 3.1.7 Condition A Restore SLC to operable status in 77 days NRC NRC #5
- 5 Page Page 12 12 of of 31 31 Rev.OO Rev.00
(contd) SLC SQUIB VALVE LIGHT BULB FAILURE EVENT 2 (cont'd)
RO Time Action Notes Respond to Annunciator A-04 4-5, SQUIB VALVE CONTINUITY LOSS May dispatch AO to investigate SLC Circuit Supply Breaker, Circuit 12 on I 20V AC Distribution Panel Emergency 120V 2AB.
Request that the light bulb for A Squib Valve Continuity Light is changed.
BOP I Time Time I Action Action Plant Monitor I Notes Notes NRC NRC #5 Page 13 13 of 31 Rev.OO Rev.OO
EVENT 3 REACTOR FEED PUMP OIL LEAK An oil leak will develop on RFP 2A oil system. A low level alarm will be received. The crew should reduce power and shutdown RFP 2A. The pump will trip in ==20 20 minutes if still running.
Malfunctions required: RFP RFPA HI/LOWAnnunciator A OIL LEVEL HI/LOW Annunciator and RFP 2A Lube Oil Leak Objectives:
SCO - Determines that 2A RFP REP needs to be shutdown and directs power to support REP.
securing 2A RFP.
RO - Lower power to be able to remove 2A RFP.
- REP.
- REP from Service Success Path:
REP removed from service.
2A RFP Simulator Operator Actions:
oLi When directed by the lead examiner, initiate Trigger 3, to activate RFP A OIL H//LOWAnnunciator.
LEVEL HI/LOW Annunciator.
oLi After power has been reduced and level has been raised to 190 inches, REP oil leak.
initiate Trigger 8 to activate the RFP oLi If contacted as AC AO report oil tank level is low. Report an oil leak on RFP REP A.
Report the leak appears to be unisolable.
oLi When contacted as maintenance, report that the RFP REP must be shutdown in an expeditiously (per the procedure) and due to the leak location the AC oil pumps must be shutdown. The DC pump only can be operated.
oLi If contacted as the Load Dispatcher acknowledge the power reduction.
oLi If contacted as the NE recommend to lower power per OENP-24.5 and thermal limits will be monitored via the computer.
oLi If requested to de-energize seal water solenoids for RFPREP 2A, report circuits (2C-TBI, circuits 8 &
are off (2C-TB1, & 24).
oLi If asked and the DC oil pump is the only running pump (AC Pumps are shutdown), report as AC AO the oil leak has stopped oLi When directed by the lead examiner, proceed to the next event.
Required Operator Actions Reactivity Manipulation - to 60-65% power Normal Operation - Shutdown 2A RFP.
NRC#5 NRC #5 Page 14l4of of 31 Rev.00 Rev.OO
SRO Time Action Notes Direct power reduction per OENP-24.5 and GP-12 to shutdown RFP REP A (60-65%).
REP A to be removed from service Direct RFP 20P-32.
per 2QP-32.
May direct RFP secured.
RO RD Time Action Notes Reduce power per OENP-24.5 as directed SCO.
by the SCQ.
Lower flow on one RR Pump (-2%) (2%) at a time to stay within mismatch criteria 6
(7 .5x1 06 Mlbs (7.5x1 Mibs jet pump flow if << than 6
MIbs or 3.5x1 58 Mlbs 6 3.5x10 MIbs if> than 58 0 Mlbs MIbs).
Mlbs).
Continues alternating Recirc pump decreases until core flow is -43 43 Mlbs.
MIbs.
Inserts control rods using ENP-24.5 to get to 60-65% power.
Turns control rod power on.
Selects control rods in the sequence prescribed on the OENP-24.5 sheets.
14-27, 38-27, 26-39, 26-15, and 14-27,38-27,26-39,26-15, maybe 26-27.
Continuously drives selected rod in using RMCS.
NRC #5 Page 15 15 of 31 Rev.00 Rev.DD
(Contd) REACTOR FEED PUMP OIL LEAK EVENT 3 (Cont'd)
BOP Time Action Notes REP A per 20P-32. (the RFP Shutdown RFP REP may trip during the execution of this procedure)
Adjust level setpoint on MSTR RFPT SP/RX LLVL SPIRX VL CTL, C32-SIC-R600, to 190 inches.
Notify Radwaste Operator to monitor CDD flows and place demineralizers COD in service as necessary.
Ensure SJAE Condensate CO-F V-49, is Recirculation Valve, CO-FV-49, closed.
RFPA Place RFP A Recirc Vlv, FW-FV-V46, in OPEN RFPTA Ensure RFPT Ct C32-SIC-A Sp CtI, R6OIA, R601 A, is selected to BIAS and Adjust, using raise and lower push buttons, until BIAS setting is o.
0.
RFPTB Ensure RFPT Ct C32-SIC-B Sp CtI, C32-S1C-R6QIB, R601 B, is selected to BIAS AND Adjust, using raise and lower push buttons, until BIAS setting is O.
0.
Depress SEL pushbutton on both RFPTA RFPT A and B SP CtI, C32-SIC-R6OIA R601 DEM is A and B, until PMP OEM displayed on each Depress AIM pushbutton on C32-SIC-R6OIA R601A Slowly Lower RFPT A speed, using C32-SIC-R6OIA, lower pushbutton on C32-SIC-R601A, And Observe RFPT B increases speed to maintain reactor level between 182 and 192 inches.
NRC #5 Page 16 of 31 Rev.00 Rev.DD
EVENT 33 (Cont'd)
EVENT (Contd) REACTOR REACTOR FEED FEED PUMP PUMP OIL OIL LEAK LEAK BOP cont'd BOP contd Time Action Notes Notes Slowly Lower RFPT A speed using lower pushbutton on C32-SIC-R601A, C32-SIC-R6OIA, REP discharge pressure is until RFP slightly less than reactor pressure.
De-energize seal water solenoid valves.
Close RFP RFPA A Disch Vlv, Wv, FW-FW-V3.
V3.
Return level setpoint on MSTR RFPT SP/RX L LVL VL CTL, C32-SIC-R600, to 187 inches Slowly Reduce RFPT A speed, using RFPTA RFPT ASPSP CTL, C32-SIC-R601A, C32-SIC-R6OIA, REPT speed is -2550 rpm until RFPT REPT A(B)
Place RFPT A(8) MAN/DFCS control switch to MAN Slowly Reduce RFPT A speed to
-1000 rpm by placing RFPT RFPTA A LOWER/RAISE speed control switch in LOWER.
Trip RFPT A(B) 1000 rpm A(8) at -1000 Place RFP A TURNING GEAR MTR mode selector switch in NORM Place RFP A Recirc Wv, Vlv, FW-FV-V46, in AUTO.
IF RFPT does NOT automatically engage, engage, Then Depress turning gear engage engage pushbutton pushbutton when turbine speed reaches zero Ensure EMERG OIL PUMP starts NRC NRC #5
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EVENT 33 (Cont'd)
EVENT (Contd) REACTOR REACTOR FEED PUMP OIL FEED PUMP OIL LEAK LEAK BOP cont'd BOP contd Time Time Action Action Notes Notes OPEN the following drain valves OPEN
. Vlv &
Stop Vlv Drain,
& Ln Drain, MS-V41 and MS-V42 MS-V41 MS-V42 RFP A HP
- 5 Page 18 Page 18 of 31 of 31 Rev.DD Rev.OO
EVENT 44 EVENT RECIRC MG RECIRC MG SET SET A A COOLING COOLING LOSS LOSS The temperature The temperature controller controller for for Recirc Recirc MG MG Set Set 2A 2A will will fail fail closed.
closed. Oil Oil temperature temperature willwill rise causing rise causing an an alarm, alarm, then then aa trip trip condition.
condition. The The Recirc Recirc MG MG Set Set will fail fail to to auto trip trip and must be manually tripped. The flow reduction must reduction will place the plant plant in in the Scram Avoidance Region Avoidance Region of the Power/Flow Power/Flow map, requiring immediate immediate exit by by control rod insertion or raising flow (not to exceed SLO limits).
insertion Malfunctions required: Recirc MG A Cool Wtr Loss Objectives:
SCO - Directs securing 2A recirc Pump and raising RR flow or inserting control rods to exit the Scram Avoidance Region.
RO - Trips A Recirc pump. Raises RR flow or insert rods to exit Scram Avoidance Region.
Success Path:
2A Recirc Pump removed from service and Scram Avoidance Region exited.
Simulator Operator Actions:
oD When directed by the lead examiner, initiate Trigger 4, to activate Recirc MG A cooling loss.
oEl If asked as TBAO to investigate, wait until crew has determined if the problem is with Recirc Pump A or B and report that the cooling water temperature control valve for MG Set A is closed (TV-60?).
(TV-607).
oEl If asked as I&C to investigate, acknowledge the request.
oLI If contacted as NE, report you will monitor thermal limits. If requested, recommend control rod insertion per OENP-24.5 to exit scram avoidance region.
oLI If contacted as chemistry for samples, acknowledge request.
Lio If contacted as NIT, acknowledge the request to backup OPRM data.
IIo When directed by the lead examiner, proceed to the next event.
Required Operator Actions NRC NRC #5 #5 Page Page 1919 of of 31 31 Rev.OO Rev.OO
EVENT 4 (Cont'd)
(Contd) RECIRC MG SET A COOLING LOSS SRO Time Action Notes Direct 2A Recirc Pump to be secured.
OAOP-4.O Direct entry into OAOP-4.0 Direct Scram Avoidance Region to be exited by raising core flow or by control rod insertion using OENP-24.5.
Evaluate TS 3.4.1 Condition A applies, implement modified APLHGR Limit and APRM setpoints within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
Contact I&C to investigate/repair temperature control on Recirc MG A.
BOP Time I Time I Action Action Plant Monitor I Notes Notes NRC NRC #5 Page 20 of 31 Rev.00 Rev.OO
(Contd) RECIRC MG SET A COOLING LOSS EVENT 4 (Cont'd)
RO Time Action Notes Dispatch TBAO to investigate.
Check temperature recorder R625 for rising temperatures.
Determine rising temperatures on MG Set A.
Determine Recirc MG Set A has failed to trip and manually trip after receiving A-06 2-4, FLUID DRIVE A SCOOP TUBE LOCK.
0AOP-04.0.
Enter and announce OAOP-04.0.
Determine region of operation on power/flow map (computer display 806 may be used)
May raise core flow or insert control rods 0ENP-to exit scram avoidance region per OENP-24.5 predetermined rod sequence.
Limitations on the Recirc Pump flow:
< 50% power MIbs
< 45 Mlbs
> 30.8 Mlbs Reduce CRD flow to 30 gpm.
lb/hr to Maintain core flow >30.8 E6 Ib/hr prevent excessive cool down of idle loop.
Monitor for THI.
Notify chemistry for sampling requirements.
NRC #5 Page 21 of 31 +/-H Rev.00 Rev.OO
EVENT55 EVENT LOSS OF E7 Substation E7 trips on fault resulting in loss of all associated loads. A half scram will occur due to the loss of RPS A. RCC Pumps 2A and 2C are lost resulting in complete loss of RBCCW and drywell cooling. This condition requires a manual reactor scram and securing RCC system loads (RWCU, Recirc Pumps, CRD Pumps). The loss of drywell cooling will result in rising drywell temperature and pressure. Drywell pressure will exceed 1.7 psig requiring entry into PCCP and RVCP (or LPC until rods are inserted). HPCI auto initiates and injects (if not tripped on high level).
Malfunctions required: Trip of substation E7 Objectives:
SCO - Directs insertion of control rods using LEP-02.
RO - - Insertion of control rods using LEP-02 BOP - Recognize failure of RBCCW.
Success Path:
Perform actions of AOP-16.0 and AOP-36.1 to scram the reactor.
Simulator Operator Actions:
D When directed by the lead examiner, initiate Trigger 5, to activate trip substation E7.
D If asked to investigate, report E7 480 Main Breaker (AZ1) @ @ E7 is tripped on overcurrent (white overcurrent trip indicator protruding).
D If requested to transfer 2AB, 32AB and 2AB-RX to alternate, initiate Trigger 11.
LI If requested to transfer RPS alternate to alternate supply, initiate Trigger 12.
D LI When directed by the lead examiner, proceed to the next event.
D Required Operator Actions Critical Task - Insert control Rods per LEP-02.
NRC #5 Page 22 of 31 Rev.00 Rev.OO
EVENT 5 (Cont'd)
(Contd) LOSS OF E7 SRO Time Action Notes Direct entry into AOP-36.1 OAOP-16.O Direct entry into OAOP-16.0 Direct actions for a complete loss of RBCCW.
Direct insertion of a manual scram.
EOP-O1-RSP actions.
Enter and direct EOP-01-RSP Direct control rod insertion per LEP-02.
Direct the continued operation of the CRD Pump until rods are inserted.
Enter and direct EOP-01-RVCP EOP-O1-RVCP actions (when control rods inserted). (May transition to LPC if DW pressure reaches 1 .7# and rods are not inserted) 1.7#
Enter and direct EOP-02-PCCP actions.
Direct RPV level be maintained 170-200 inches.
NRC #5 Page 23 of 31 Page23of3l Rev.DD Rev.00
EVENT 55 (Cont'd)
EVENT (Contd) LOSS LOSS OF OF E7 E7 RO RO Time Time Action Action Notes Notes Insert aa manual Insert manual scram scram Perform immediate Perform immediate actions actions forfor Reactor Reactor scram scram 66 After steam After steam flow flow is is less less than than 33 xx 10 1
lb/hr, place Ib/hr, place the reactor reactor mode mode switch switch to to shutdown shutdown When APRM downscale trip, then Trip the main Trip main turbine turbine Ensure the master reactor level controller setpoint is +170 inches Performs LEP-02, Alternate Rod Insertion. (RMCS Section)
Insert IRMs.
When < <range range 3 on IRMs insert SRMs.
Start both CRD pumps.
Place CRD Flow Controller to Manual.
Throttle open flow controller to establish ~ > 260 drive water psid.
Bypass RWM.
Selects control control rods and and drives in using using Emerg rod in notch notch override.
override.
Shutdown Shutdown CRD CRD Pumps Pumps when when all all rods rods in in (AOP-1 (AOP-16). 6).
NRC NRC #5
- 5 Page 24 Page 24 of of 31 31 Rev.DD Rev.00
(Contd) LOSS OF E7 EVENT 5 (Cont'd)
BOP Time Action Notes Diagnose loss of E7 and loss all RBCCW Pumps.
OAOP-36. 1.
Enter and announce OAOP-36.1.
Ensure one of the C8 CB EMERG RECIRC 2A(B)-ERF-CB, is operating.
FANS, 2A(8)-ERF-C8, Direct AO AC to transfer 2AB, 32AB, and 2AB-RX panels to their alternate power supply.
Enter and announce OAOP-16.0.
Perform actions for a total loss of RBCCW (leave CRD running).
Place all RBCCW Pump Switches to Off.
Close the following valves:
RBCCWTODWISOL R8CCW TO OW ISOL VLVS, RCC-V28 RBCCWTODWISOL R8CCW TO OW ISOL VLVS, RCC-V52 (These have no power)
Trip RWCU pumps and isolate the system (Pumps already tripped and isolated)
Trip both reactor recirculation pumps.
Shutdown CRD Pumps when all rods are inserted.
Recognize and report high drywell pressure.
May attempt to control HPCI to prevent high level trip (It will trip on high reactor water level).
Control RPV level as directed by SCO.
(1 70-200 inches)
(170-200 NRC #5 Page 25 25 of 31 Rev.DD Rev.00
EVENT 66 EVENT STEAM LEAK STEAM LEAK IN IN DRYWELL DRYWELL A small steam A small steam leak leak will will develop develop in in the drywell. Drywell the drywell. Drywell temperature temperature andand pressure pressure rises rises at faster rate at aa faster rate requiring requiring initiation initiation of drywell sprays.
of drywell sprays. RHR RHR Loop Loop 2A 2A is is unavailable unavailable for for spray due to loss loss of E7 (valve power).
E7 (valve power). When RHR RHR 2B isis placed placed in in drywell spray, the outboard spray valve (F016B)(FO16B) will fail. With no spray spray available, drywell temperature will exceed 300°F exceed 300°F (cannot (cannot be restored restored and maintained maintained below) requiring emergency emergency depressurization. During depressurization. During the depressurization, depressurization, low pressure injection low pressure injection systems (RHR, (RHR, Core Spray and Condensate) must be operated to prevent uncontrolled injection.
depressurization actions have been performed, the scenario may be When emergency depressurization terminated.
Malfunctions required: Small steam line break in the DW.
Objectives:
Depressurization actions when exceeding 300°F in the DW.
SCO - Directs Emergency Depressurization Depressurization actions when instructed by the SCO.
BOP - Perform Emergency Depressurization Success Path:
Depressurization of the reactor due to 300°F Perform Emergency Depressurization 300° F in the DW.
Simulator Operator Actions:
oEl When drywell pressure exceeds 1.7 psig (A-05 5-6 annunciator) verify activation of Trigger 6, steam leak.
oEl If asked to check breaker for E11-F016B Ell-FO16B (MCC 2XB) report thermal overload tripped, if directed to reset thermal overload, report it trips again, if directed to manually open E11-F016B, El l-FO16B, report valve is bound.
oEl Monitor drywell average temperature on ERFIS, if required to achieve 300 degrees DW temp, modify steam leak severity.
Elo When directed by the lead examiner, proceed to the next event.
Required Operator Actions Critical Task - Depressurize the reactor when drywell
- drywel/ average air temperature cannot be restored and maintained below 300°F by performing or anticipating emergency depressurizat depressurization.
ion.
NRC #5 NRC #5 Page Page 26 26 of of 31 31 Rev.OO Rev. 00
EVENT 66 (Cont'd)
EVENT (Contd) STEAM STEAM LEAK LEAK ININ DRYWELL DRYWELL SRO SRO Time Time Action Action Notes Notes Recognize drywell Recognize drywell temperature tern perature and and pressure rising at faster rate pressure rising at faster rate and and diagnose as diagnose line break.
as line break.
Direct suppression chamber spray per Direct SEP-03.
Direct drywell spray per Direct per SEP-02.
SEP-02.
Direct maintenance to investigate E11- Eli FO16B.
F016B.
Before drywell temperature reaches 300°F, may direct anticipating emergency depressurization if MSIVs are open.
If drywell temperature exceeds 300°F, determines it cannot be restored below 300°F (unless actions in progress for anticipating emergency depressurization) and directs emergency depressurization.
Direct low pressure ECCS be operated to prevent uncontrolled injection.
Direct condensate be operated to prevent uncontrolled injection.
NRC NRC #5
- 5 Page27of3l Page 27 of 31 Rev.OO Rev.00
- EVENT 66 (Cont'd)
EVENT (Contd) STEAM STEAM LEAK LEAK IN DRYWELL IN DRYWELL RO RO Time Time Action Action Notes Notes May recognize May recognize drywell drywell temperature andand pressure pressure rising at faster rate and rate and diagnose as line line break.
break.
Initiate suppression chamber spray per SEP-03.
IfIf necessary, necessary, then place place Loop Loop BB 2/3 CORE HEIGHT LPCI INITIATION OVERRIDE SWITCH, E11-CS-S18B, in Manual Overrd.
If the CTMT SPR OVRD light for the Loop B CONTAINMENT SPRAY VALVE CONTROL SWITCH, Ell-CS-S17B is not on, then E11-CS-S17B momentarily place Loop B CONTAINMENT SPRAY VALVE CONTROL SWITCH, E11-CS-S17B,Ell-CS-S17B, to Manual Ensure at least one RHR Loop B B Pump is operating Ensure TORUS DISCHARGE ISOL VLV, E11-F028B, El l-F028B, is open Open TORUS SPRAY ISOL VLV, El l-F027B.
E11-F027B.
NRC NRC #5
- 5 Page 28 of Page 28 31 of 31 Rev.DD Rev.00
EVENT 66 (Cont'd)
EVENT (Contd) STEAM STEAM LEAKLEAK IN DRYWELL IN DRYWELL RO (Cont'd)
RO (Contd)
Time Time Action Action Notes Notes Initiate drywell Initiate drywell spray per per SEP-02 SEP-02 Ensure WELL WATER Ensure WATER TO VITAL HEADER VLV, HEADER SW-V141, is VLV, SW-V141, is closed closed Ensure both reactor recirculation pumps are tripped Place all drywell cooler control switches to OFF (LlO)
(LIO)
Confirm the following:
- . Drywell pressure and drywell SAFE temperature are in the "SAFE" region of the DSIL graph.
- . Suppression pool water level is below +21 inches.
Open Loop B DRYWELL SPRAY ISOLVLV, INBD ISOL E11-FO21B VLV, E11-F021B Recognize and report failure of E11-Eli FO16B to open as thermal overload.
F016B May dispatch AC AO to check breaker and attempt to reset thermal overload per the APP.
NRC #5 NRC #5 Page Page 29 of 31 29 of 31 Rev.DD Rev.00
EVENT 66 (Cont'd)
EVENT (Contd) STEAM STEAM LEAK LEAK IN IN DRYWELL DRYWELL BOP BOP Time Time Action Action Notes Notes May recognize drywell May recognize drywell temperature temperature and and pressure rising at pressure rising at faster faster rate rate and and diagnose as diagnose as line line break.
break.
Performs actions to rapidly depressurize the RPV to the main condenser as directed by the SCO Opens seven ADS valves Opens valves when when directed by the seo.SCO.
Verifies low pressure ECCS actuations at 410#.
Overrides ECCS off to prevent uncontrolled injection.
Operate Condensate as necessary to prevent uncontrolled injection.
NRC NRC #5
- 5 Page3Oof3l Page 30 of 31 Rev.OO Rev.OO
Simulator Operator Activities:
WHEN directed by the lead examiner, place the simulator in FREEZE.
CAUTION DO NOT RESET THE SIMULATOR PRIOR TO RECEIPT OF CONCURRENCE TO DO SO FROM THE LEAD EXAMINER NRC #5 Page 31 of 31 Rev.OO