ML13169A424
| ML13169A424 | |
| Person / Time | |
|---|---|
| Site: | Braidwood  |
| Issue date: | 04/15/2013 |
| From: | Division of Reactor Safety III |
| To: | Exelon Generation Co |
| Zoia, C. | |
| Shared Package | |
| ML11354A330 | List: |
| References | |
| Download: ML13169A424 (159) | |
Text
Simulation Facility Braidwood Scenario No.:
NRC 13-1 Operating Test No.: 2013-1 Examiners:
Applicant:
_____________________ SRO
_____________________ ATC
_____________________ BOP Initial Conditions:
IC-21 Turnover:
Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. Online risk is yellow. Rods are in manual due to rod control summing amplifier malfunction last shift. Following completion of turnover, the crew is to perform 1BwOSR 3.7.4.1, MAIN STEAM SYSTEM ISOLATION 1MS018A/B/C/D VALVE TRAVEL AND INDICATION 18 MONTH SURVEILLANCE (due date in 3 days). The SM directs the SG PORVs to be stroked with the MCB M/A stations and returned to Auto upon completion.
Event No.
Malf. No.
Event Type*
Event Description IMF CV32B TRGSET 1 ZLO1SI01PA(3) = = 1 IMF CV01A (1 0)
IMF RX17 3.5 TRGSET 2 "ZLO1IA066(2)== 0" IMF FW19B (2 0) 3.5 30 1B CV pump auto start failure 1A CV pump trip on SI Rod control summing amp failure FW break when SI actuates 1
TRGSET 3 ZAO1PKMS042A >
0.90 IMF PB2411 (3 0) ON IMF PB2412 (3 0) ON IOR ZLO1MS018B2 (3
- 0) ON IOR ZLO1MS018B1 (3
- 0) ON IOR ZAO1ZIMS010 (3
- 0) 90 N-BOP, US TS-US 1BwOSR 3.7.4.1, 1MS018A/B/C/D Surv. with 1MS018B valve failure.
2 IMF TC14D 0 R-ATC, US
- 4 Governor valve servo failure closed 3
IMF RX06K 0 15 I-BOP, US TS-US 1C SG NR level transmitter 1LT-539 fails low 4
IMF CV10 0 30 I-ATC, US 1CV121 controller failure 5
IMF FW16 1500 30 I-BOP, US 1PT-508 FW Htr Dsch Press fails high 6
IMF TH03B 450 M-ALL 1B SGTR (450 gpm) 7 Preload C-ATC 1A CV pump trips/1B CV pump fails to auto start 8
Preload M-ALL 1B SG feedline break inside containment (3.5 MLBM/hr faulted and ruptured)
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
Braidwood NRC 13-1 Page 2 SCENARIO OVERVIEW Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. Online risk is yellow. Rods are in manual due to rod control summing amplifier malfunction last shift. Following completion of turnover, the crew is to perform 1BwOSR 3.7.4.1, MAIN STEAM SYSTEM ISOLATION 1MS018A/B/C/D VALVE TRAVEL AND INDICATION 18 MONTH SURVEILLANCE (due at end of shift).
After completing shift turnover and relief, the BOP performs 1BwOSR 3.7.4.1. The 1B SG PORV valve will fail the test due to a broken hydraulic line when the valve is stroked open. The Unit Supervisor will enter Tech Spec 3.7.4, Condition A and Tech Spec 3.6.3, Condition C. 1MS019B will remain closed to comply with TS 3.6.3, condition C. 1MS018B will remain unavailable for the remainder of the scenario. The crew should inform the SM following the 1MS018B failure.
After the 1MS018B failure has been addressed, the #4 turbine governor valve servo will fail, causing the
- 4 governor valve to close. Turbine load will lower approximately 30 Mw. The ATC will borate the RCS as necessary and/or move rods in to stabilize RCS temperature.
After the #4 governor valve failure is addressed, 1C SG NR level transmitter 1LT-539 will fail low.
1FW530, Feedwater Regulating Valve, will open fully and 1C SG level will rise. The BOP will take manual control of 1C SG level and stabilize 1C SG level. 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment E, will be implemented. The BOP will restore 1C SG level control to automatic after 1C SG level is restored to normal and an operable 1C SG NR level controlling channel is selected. Technical specifications 3.3.1, conditions A and E and 3.3.2, conditions A and D are applicable.
After the 1LT-539 failure has been addressed, 1CV121 Charging pump flow control valve controller 1FK-121 will fail to 0% demand. The 1CV121 valve will fully close and pressurizer level will drop. The crew will take actions to stabilize the plant by taking manual control of the 1FK-121 controller.
After the 1FK-121 failure has been addressed, feedwater line pressure detector 1PT-508 will fail high over a 30 second period. Both main feedwater pumps speed will lower, reducing feedwater flow and causing all steam generator levels to begin lowering. The crew will take actions to stabilize the plant by taking manual control of the main feedwater pumps. 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment J, will be implemented. 1PT-508 will remain unavailable for the remainder of the scenario.
After the 1PT-508 failure has been addressed, a 450 gpm SGTR initiates on the 1B SG. The crew will determine that the leakage is beyond the capacity of a single charging pump and initiate a reactor trip and safety injection. The hydraulic transient of the reactor trip and safety injection result in a feedline break inside containment on the ruptured SG. The crew will implement 1BwEP-0, REACTOR TRIP OR SAFETY INJECTION. When safety injection is actuated, the 1A CV pump will trip. The 1B CV pump must be manually started to establish high head ECCS flow. After determining 1B SG secondary pressure boundary is not intact the crew will transition to 1BwEP-2, FAULTED STEAM GENERATOR ISOLATION. The crew will complete isolation of 1B SG and transition to 1BwEP-3, STEAM GENERATOR TUBE RUPTURE, based on secondary radiation trends on the 1B SG. In addition, the crew will recognize 1B SG pressure does not drop to zero and lowering pressurizer level/pressure will indicate a SGTR (alternate indications). After determining ruptured SG pressure is less than 320 psig the crew will transition 1BwCA-3.1, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED.
Completion criteria is completion of step 6 of 1BwCA-3.1.
Braidwood NRC 13-1 Page 3 Critical Tasks
- 1. Manually start the 1B CV pump prior to completion step 6 of 1BwEP-0.
(ERG Critical Task number - E-0--I) (K/A number - 013000A4.01 importance - 4.5/4.8)
- 2. Isolate 1B Steam Generator prior to completing step 4 of 1BwEP-2.
(ERG Critical Task number - E-2--A) (K/A number - 000040AA1.10 importance - 4.1/4.1)
Braidwood NRC 13-1 Page 4 SIMULATOR SETUP GUIDE:
Verify/perform TQ-BR-201-0113, BRAIDWOOD TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.
Establish the conditions of IC-21, 100% power, steady state, equilibrium xenon.
Verify VA plenums A & C in service.
Complete items on Simulator Ready for Training Checklist.
Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.
Place simulator in RUN (allow simulator to run during board walk down and turnover).
Place ROD BANK SELECT switch to MAN Run caep NRC 13-1 SETUP from disk and verify the following actuate:
IMF CV32B TRGSET 1 ZLO1SI01PA(3) = = 1 IMF CV01A (1 0)
IMF RX17 3.5 TRGSET 2 "ZLO1IA066(2)== 0 IMF FW19B (2 0) 3.5 30 Verify/Set I Target Curve slopes to +2% of I.
Place Safety System Status Yellow placard on 1PM05J.
Adjust Tave about 1oF above Tref (Set RCS boron to 802.2 ppm).
Provide examinees with turnover sheets and 1BwOS NR-1.
If the crew contacts the SM after the turnover about the slightly high Tave, reply that the SM is in a meeting and that he will review the reactivity plan after the meeting (in about 30 minutes). (This is related to initial conditions for event number 2)
Braidwood NRC 13-1 Page 5 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: 1BwOSR 3.7.4.1 with 1MS018B valve failure (Tech Spec).
Run caep N131 EVENT 1 from disk and verify the following actuate:
- TRGSET 3 ZAO1PKMS042A > 0.90
- IMF PB2411 (3 0) ON
- IMF PB2412 (3 0) ON
- IOR ZLO1MS018B2 (3 0) ON
- IOR ZLO1MS018B1 (3 0) ON
- IOR ZAO1ZIMS010 (3 0) 90 When requested, as Equipment Operator report you are standing by at the 1MS018B/C Valves.
Report the following as an EO when prompted:
AS FOUND position for 1MS019A/B/C/D is OPEN When requested to close 1MS019A/B/C/D insert the following:
IRF MS51 0 for 1MS019A IRF MS52 0 for 1MS019B IRF MS53 0 for 1MS019C IRF MS54 0 for 1MS019D As SM acknowledge the failure of 1MS018B, LCO 3.6.3, condition C and LCO 3.7.4, condition A, and requests for on line risk assessment, maintenance support, and IR initiation.
If asked, as EO, report 1MS018B has a broken hydraulic line and a small puddle of hydraulic fluid is present beneath the valve. The hydraulic pump is running.
As WEC supervisor, acknowledge request for EST for 1MS018B C/S, if EST is requested Event 2: #4 governor valve servo failure.
Insert IMF TC14D 0 Insert IMF PN1970 ON to actuate Tave Control Dev High alarm If dispatched as EO to investigate #4 GV failure, wait 2 minutes and report #4 GV is closed and no visible damage present.
Delete DMF PN1970 after Tave is restored within less than 2oF of Tref.
Acknowledge as Power Team loss of load due to Governor Valve failure.
Acknowledge as chemistry/rad protection requests for RCS samples.
Acknowledge as SM the GV failure and requests for on line risk assessment, maintenance support, and IR initiation. If asked about isolating EH to #4 gov. valve, concur with isolation to prevent further valve movement.
Acknowledge as Power Team load reduction and estimated duration of derate.
Braidwood NRC 13-1 Page 6 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 3: 1C SG NR level transmitter 1LT-539 fails low.
Insert IMF RX06K 0 15 to fail 1LT-539 low over a 15 second period.
To trip the required bistables, participate in brief and perform the following (Sim Drawing RX19):
As extra NSO contact Unit 1 (X-2209).
Insert the following:
MRF RP20 OPEN (open protection cabinet #1 door).
MRF RX063 TEST (C1-753 S/G LEVEL TEST SWITCH 539).
MRF RP20 CLOSE (close protection cabinet #1 door).
Acknowledge as Shift Manager the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.
Acknowledge as Shift Manager reactor overpower condition, on line risk assessment, request for IR, evaluation for reactivity screening, QNE and personnel notifications, and evaluation of return to full power operation.
Event 4: 1FK121 Controller failure IMF CV10 0 120 If dispatched as EO to investigate, wait two minutes and report no visible damage to 1CV121 Valve. Valve appears to be failed closed in auto and responding correctly in manual (if asked for feedback to manual ops).
Acknowledge as Shift Manager the failure, request for maintenance support, and IR request.
Event 5: Feed line pressure detector 1PT-508 fails high.
Insert IMF FW16 1500 30 for 1PT-508 failed high.
If dispatched as EO to investigate 1PT-508, wait two minutes report no visible damage to 1PT-508.
Acknowledge as SM 1PT-508 failure, on line risk assessment, request for maintenance support, and IR requests.
If ramp is suspended, acknowledge as Power Team suspension of ramp.
If asked for direction from SM for ramping unit, direct crew to re-initiate the ramp when actions for 1PT-508 failure are complete.
Braidwood NRC 13-1 Page 7 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 6: 1B SGTR Insert IMF TH03B 450 Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
Event 7: 1A CV pump trips/1B CV pump fails to auto start (preload)
If dispatched as EO to investigate 1A CV pump, report ground overcurrent flag at breaker cubicle.
Event 8: Faulted ruptured 1B SG (preload)
Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
After STA requested, as STA report CSF status.
If asked, TSC will get back to the crew with guidance.
Comments:
Braidwood NRC 13-1 Page 8 Scenario No:
NRC 13-1 Event No.
1 Event
==
Description:==
1BwOSR 3.7.4.1, MAIN STEAM SYSTEM ISOLATION 1MS018A/B/C/D VALVE TRAVEL AND INDICATION 18 MONTH SURVEILLANCE.
Time Position Applicants Actions or Behavior CUE From turnover, perform 1BwOSR 3.7.4.1.
US
- Direct BOP to perform 1BwOSR 3.7.4.1.
- Refer to 1BwOSR 3.7.4.1.
- Initial step 1, initial conditions.
- Contact Equipment Operator at 1MS019B for initial position and to close 1MS019B.
- At 1PM04J, OPEN 1MS018B.
- Respond to alarm Annunciator S/G 1B PORV TROUBLE (1-15-B10).
- Identify/report trouble alarm on 1MS018B.
- Refer to BwAR 1-15-B10.
o Dispatch operator to 1MS018B.
o Place 1MS018B C/S in close to stop hydraulic pump.
o Request Equipment Status Tag for 1MS018B C/S & 1MS019B hand wheel.
US
- Identify entry conditions for TS 3.7.4, condition A.
- Identify entry conditions for TS 3.6.3, condition C.
o Direct operator to keep 1MS019B closed.
o Inform SM of 1MS018B status, TS Status, request IR, On Line Risk Assessment, maintenance support, and clearance order/EST for 1MS019B.
NOTE: After the actions for 1MS018B failure are complete and with lead examiner concurrence, enter next event.
Comments:
Braidwood NRC 13-1 Page 9 Scenario No:
NRC 13-1 Event No.
2 Event
==
Description:==
- 4 governor valve servo failure Time Position Applicants Actions or Behavior CUE
- Annunciator TAVE CONT DEV HIGH (1-14-D1).
- #4 governor valve closed indication at 1PM02J OWS drop 211 or OWS drop 210.
- Generator MW lowering at 1PM01J or OWS drop 210.
- RCS Tave rising at 1PM05J.
CREW
- Refer to BwARs ATC/
- Determine turbine load drop in progress from 1PM01J or OWS drop 210.
- Reference BwARs.
- Dispatch operators to investigate #4 GV.
US
- Notify SM of #4 GV malfunction.
- Direct operators to restore RCS Tave / Delta I.
NOTE: The crew may decide to borate the rods back out based upon Delta I concerns.
ATC o Insert control rods to maintain Tave and Tref approx. equal.
o Initiate RCS boration per BwOP CV-6 or hard card at 1PM05J.
o Determine required boric acid volume.
o Determine desired boric acid flow rate.
o Set 1FK-110 BA Flow Control to desired boration rate.
o Set 1FY-0110 BA Blender Predet Counter to desired volume.
o Place MAKE-UP MODE CONT SWITCH to STOP position.
o Place MODE SELECT SWITCH to BORATE position.
o Place MAKE-UP MODE CONT SWITCH to START.
o Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).
OR o Batch addition of Boric Acid:
o Open 1CV110B.
o Open 1CV110A.
o Start the BA Transfer pump.
o When desired amount of BA has been added, stop the BA Transfer Pump.
o Close 1CV110A.
o Close 1CV110B.
o Turn on PZR backup heaters in accordance with BwOP RY-14, PRESSURIZER BACKUP HEATER OPERATION.
US Contact SM to perform risk assessment, initiate IR, and contact maintenance, OAD,
Comments:
Braidwood NRC 13-1 Page 10 Scenario No:
NRC 13-1 Event No.
2 Event
==
Description:==
- 4 governor valve servo failure Time Position Applicants Actions or Behavior SED to investigate/correct component.
o Check reactor power change < 15% in one hour.
o Contact Power Team and inform Power Team of load reduction and estimated duration of power derate.
o Review Tech Spec 3.4.1 for applicability.
o Review RIL per COLR.
EVALUATOR NOTE: After the actions for the governor valve failure are complete and with lead examiners concurrence, insert the next event.
Comments:
Braidwood NRC 13-1 Page 11 Scenario No:
NRC 13-1 Event No.
3 Event
==
Description:==
1C SG NR level transmitter 1LT-539 fails low Time Position Applicants Actions or Behavior CUE Annunciator 1-15-C9, S/G 1C LEVEL DEVIATION HIGH LOW Annunciator 1-15-C5, S/G 1C LVL LO-2 RX TRIP ALERT SG 1C feed flow and NR level rising.
BOP Determine SG 1C feed flow and/or NR level rising at 1PM04J.
Identify 1LI-539 indicates low SG NR level at 1PM04J.
Reference BwARs 1-15-C5 & 1-15-C9.
CREW Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.
US Notify Shift Manager of SG level channel failure.
Implement 1BwOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment E, NARROW RANGE SG LEVEL CHANNEL FAILURE, and direct operator actions of 1BwOA INST-2 to establish the following conditions:
BOP Stabilize 1C SG level at 1PM04J.
Place 1FK-530, FW Reg Valve 1FW530 controller, in manual.
Lower demand on 1FK-530 sufficiently to lower feedwater flow to restore 1C SG level.
Operate 1FK-530 in manual to stabilize 1C SG level in the normal operating band.
Select operable 1C SG NR level channel.
Place 1C SG water level channel select C/S to L-558.
Establish automatic level control by placing 1FK-530 in auto.
RO Perform the following:
Monitor reactor power at 1PM05J.
Assist US by making notifications.
Refer to BwARs.
US o Perform pre-job brief per HU-AA-1211 for bistable tripping.
o Complete 1BwOL 3.3.1, Attachment A, INSTRUMENT CONDITION TRACKING LOG.
Extra NSO/
BOP o Locally trip bistables for 1C steam generator level by placing in TEST/ BOP verifies correct bistable operation:
o P-14/Lo-2 Rx Trip/AF Pump Start C1-753 US Determine AMS channel NOT affected.
Comments:
Braidwood NRC 13-1 Page 12 Scenario No:
NRC 13-1 Event No.
3 Event
==
Description:==
1C SG NR level transmitter 1LT-539 fails low Time Position Applicants Actions or Behavior Determine TS 3.3.1 conditions A and E are applicable.
Determine TS 3.3.2 conditions A and D are applicable.
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure, and make other notifications.
The next event is to be inserted following the above actions by the US and Lead Examiner concurrence.
Comments:
Braidwood NRC 13-1 Page 13 Scenario No:
NRC 13-1 Event No.
4 Event
==
Description:==
1CV121 controller fails low in auto Time Position Applicants Actions or Behavior CUE Annunciator 1-9-D3, CHG LINE FLOW HIGH LOW.
Annunciator 1-9-A1, REGEN HX LTDWN TEMP HIGH.
Annunciator 1-7-B2 RCP SEAL WTR INJ FLOW LOW.
1FK-121 controller output failed low.
1FI-121A Charging Flow Indication dropping.
Pzr level indicators 1LI459A/460A/461 indicate lowering level.
ATC/
BOP Perform the following at 1PM05J:
- Determine loss of charging flow.
- Identify 1FK-121 is failing low.
- Report failure to US.
CREW o Reference BwARs o Isolate Letdown per BwAR direction. (the crew may elect to do this) o Close 1CV8105 or 1CV8106 (if crew isolates letdown, crew may do this to limit thermal shock to charging nozzle per precaution D.6 in 1BwGP 100-3)
Recognize 1FK-121 output failed low.
o Dispatch operator to investigate cause of failure.
NOTE: THE CREW MAY ELECT TO ENTER 1BwOA PRI-15, LOSS OF NORMAL CHARGING. SEE SEPARATE BLOCK ON NEXT PAGE FOR EXPECTED ACTIONS FOR THAT PROCEDURE.
US o Direct actions of 1BwOA PRI-15 (see note above)
Direct/Ensure ATC takes manual control of 1FK-121 and returns charging flow to normal.
o Inform SM of FK-121 failure.
ATC Perform the following at 1PM05J:
Place 1FK-121, 1CV121 Controller, in manual.
Raise demand on 1FK-121.
Monitor charging flow and pressurizer level and return level to normal.
Maintain charging flow by operating 1FK-121 in manual.
US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
Comments:
Braidwood NRC 13-1 Page 14 Scenario No:
NRC 13-1 Event No.
4 Event
==
Description:==
1CV121 controller fails low in auto Time Position Applicants Actions or Behavior US o IF PZR pressure drops below 2209 psig, enter Tech Spec 3.4.1 condition A.
o If 1CV-121 fully closes such that there is 0 gpm charging flow, LCO 3.5.5 Condition A applies.
ATC/
BOP 1BwOA PRI-15 ACTIONS (APPLICABLE IF CREW ENTERS THE PROCEDURE):
o Status of Cent Chg Pumps (one running) o Check Cent Chg pump parameters (none fluctuating) o If 1PI-120A greater than RCS pressure:
o Place 1CV121 in manual (at this point, the ATC is likely to determine the controller was failed in automatic) o Place affected Cent Chg pump in Pull Out o Start the standby Cent Chg pump o Place 1CV121 in auto if desired (crew should keep the controller in manual) o Check CV System Alignment o Either 1CV8146 or 1CV8147 Open (one open) o 1CV8324A or 1CV8324B Open (one open) o BOTH 1CV8105 and 1CV8106 Open (if previously closed one, crew re-opens) o Check charging flow established (established) o Check normal letdown isolated (if previously isolated, crew implements 1BwOAS ESP-2 to re-establish normal letdown) o Notify SM to perform risk evaluation, initiate IR and make external notifications o Evaluate Tech Specs/TRM (none applicable) o Return to procedure and step in effect BOP 1BwOA ESP-2 ACTIONS (APPLICABLE IF CREW ISOLATED LETDOWN) o Restore normal letdown using 1BwOA ESP-2, REESTABLISHING LETDOWN DURING ABNORMAL CONDITIONS as directed by performing the following at 1PM05J:
o Close letdown orifice isolation valves (1CV8149A-C) o Close letdown isolation valves (1CV459 and 1CV460) o Verify either 1CV8401A or B open o Open 1CV8324B and 1CV8389B o Confirm Letdown CNMT isolation valves 1CV8152 and 1CV8160 open o Place 1CV131 controller in manual at 40% demand o Place 1CC130 controller in manual at 60% demand o Adjust 1CV121 and 1CV182 to attain at least 100 gpm charging with seal injection 8-13 gpm per RCP o Open 1CV459 and 1CV460 o Re-establish 120 gpm letdown flow by opening appropriate orifice isolation valves (1CV8149A and either 1CV8149B or C) o Adjust 1CV131 and 1CC130 to restore letdown to 360 psig and 90-115oF
Comments:
Braidwood NRC 13-1 Page 15 Scenario No:
NRC 13-1 Event No.
4 Event
==
Description:==
1CV121 controller fails low in auto Time Position Applicants Actions or Behavior o Place controllers in auto when desired (1CV131 and 1CC130) o Verify 1PR06J restored The next event is to be inserted following the above actions by the US and Lead Examiner concurrence.
Comments:
Braidwood NRC 13-1 Page 16 Scenario No:
NRC 13-1 Event No.
5 Event
==
Description:==
FW Hdr Dsch Press 1PT-508 fails high.
Time Position Applicants Actions or Behavior CUE o Annunciators (1-15-A9 thru D9) "S/G 1_ LEVEL DEVIATION HIGH LOW" o Annunciators (1-15-A4 thru B4) S/G 1_ FLOW MISMATCH FW FLOW LOW o Annunciator (1-17-E2) HTR DRN PUMP GLAND WTR PRESS HI/LOW o Steam flow / FW flow mismatch on all SGs o 1B MFP speed lowering o 1C MFP speed lowering o Master, 1B and 1C MFP speed controllers demand lowering o 1PI-508 meter indication rising.
o 1PI-509 meter indication rising.
CREW Refer to BwARs Determine 1PT-508 failing high at 1PM04J.
Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.
o Dispatch operators to investigate 1PT-508 failure.
US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Implement 1BwOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment J "FW PUMP SPEED CONTROL MALFUNCTION" and direct operator actions of 1BwOA INST -2 to establish the following conditions.
BOP Perform the following at 1PM04J:
Place 1SK-509A, Master FW pump speed controller in manual.
Raise demand on 1SK-509A.
Raise FW pump speed sufficiently to restore SG levels and FW header DP to normal per 1BwGP 100-3A9.
Maintain SG levels by operating 1SK-509A in manual.
o Align steam dumps (go to step 6) o Crew may intermittently place each FRV in manual (then return to auto) to clear integral signal.
ATC Perform the following:
Monitor reactor power response to SG under and overfeeding transient.
Comments:
Braidwood NRC 13-1 Page 17 Scenario No:
NRC 13-1 Event No.
5 Event
==
Description:==
FW Hdr Dsch Press 1PT-508 fails high.
Time Position Applicants Actions or Behavior US Contact SM to perform risk assessment, initiate IR, evaluate reactivity screening, overpower assessment, QNE notification, duty personnel (WW Manager, Station Duty Manager, SDO, NDO) and evaluate for restoration to full power (as stated in step 6 of 1BwOA INST-2, Attachment J).
o IF PZR pressure drops below 2209 psig, enter Tech Spec 3.4.1 condition A.
Comments:
Braidwood NRC 13-1 Page 18 Scenario No:
NRC 13-1 Event No.
6, 7 & 8 Event
==
Description:==
1B SGTR, 1A CV pump trips/1B CV pump fails to auto start, 1B SG faulted/ruptured Time Position Applicants Actions or Behavior CUE o RM-11 Grid 1 SJAE /Gland Steam Exhaust radiation in ALERT o RM-11 Grid 1 1B MSIV room MS line radiation in ALARM/trending up o PZR pressure lowering o PZR level dropping CREW Recognize indications of Ruptured SG Decide to manually initiate reactor trip and safety injection ATC Initiate a manual reactor trip and transition to 1BwEP-0 Initiate a manual SI US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BwEP-0 and direct operator actions of 1BwEP-0 ATC Perform immediate operator actions of 1BwEP-0:
Verify reactor trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux - DROPPING BOP Perform immediate operator actions of 1BwEP-0:
Verify Turbine Trip All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED BOP Perform immediate operator actions of 1BwEP-0:
Verify power to 4KV busses ESF Buses - BOTH ENERGIZED (141 & 142)
CREW Recognize and respond to conditions requiring a Safety Injection in accordance with 1BwEP-0 REACTOR TRIP OR SAFETY INJECTION, Step 4:
Check SI Status o SI First OUT annunciator - LIT o SI ACTUATED Permissive Light - LIT o SI Equipment - AUTOMATICALLY ACTUATED o
Either SI pumps - RUNNING
Comments:
Braidwood NRC 13-1 Page 19 Scenario No:
NRC 13-1 Event No.
6, 7 & 8 Event
==
Description:==
1B SGTR, 1A CV pump trips/1B CV pump fails to auto start, 1B SG faulted/ruptured Time Position Applicants Actions or Behavior o
Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B PZR pressure cannot be maintained > 1829 psig Manually actuate SI from 1PM05J and 1PM06J US Direct BOP to perform Attachment B of 1BwEP-0 EVALUATOR NOTE: US and ATC will continue in 1BwEP-0 while BOP is performing Attachment B:
Verify FW isolated at 1PM04J:
FW pumps - TRIPPED.
Isolation monitor lights - LIT.
FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.
Verify DGs running at 1PM01J:
DGs - BOTH RUNNING.
1SX169A/B OPEN.
Dispatch operator locally to check operation.
Verify Generator Trip at 1PM01J:
OCB 1-8 and 7-8 open.
PMG output breaker open.
Verify Control Room ventilation aligned for emergency operations at 0PM02J:
VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.
Operating VC train equipment - RUNNING.
0B Supply fan 0B Return fan 0B M/U fan 0B Chilled water pump 0B Chiller Operating VC train dampers - ALIGNED.
M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.
0B VC train M/U filter light - LIT.
0VC09Y - OPEN.
0VC313Y - CLOSED.
Operating VC train Charcoal Absorber aligned for train B.
0VC44Y - CLOSED.
0VC05Y - OPEN.
0VC06Y - OPEN.
Control Room pressure greater than +0.125 inches water on 0PDI-VC038.
Verify Auxiliary Building ventilation aligned at 0PM02J:
Comments:
Braidwood NRC 13-1 Page 20 Scenario No:
NRC 13-1 Event No.
6, 7 & 8 Event
==
Description:==
1B SGTR, 1A CV pump trips/1B CV pump fails to auto start, 1B SG faulted/ruptured Time Position Applicants Actions or Behavior Two inaccessible filter plenums aligned.
Plenum A:
- 0VA03CB - RUNNING
- 0VA023Y - OPEN
- 0VA436Y - CLOSED Plenum C:
- 0VA03CF RUNNING
- 0VA072Y - OPEN
- 0VA438Y - CLOSED Verify FHB ventilation aligned at 0PM02J:
- 0VA04CB - RUNNING
- 0VA055Y - OPEN
- 0VA062Y - OPEN
- 0VA435Y - CLOSED
- Shutdown Unnecessary Plant Equipment
- Secure all running HD pumps
- Initiate Periodic Checking of Spent Fuel Cooling
- Notify US Attachment B complete ATC/
[CT]
E-0--I Verify ECCS pumps running CV pumps - NONE RUNNING Manually start the 1B CV pump prior to completion step 6 of 1BwEP-0.
Both RH pumps - RUNNING Both SI pumps - RUNNING ATC/
BOP Verify RCFCs running in Accident Mode Group 2 RCFC Accident Mode lights - LIT Verify Phase A isolation Group 3 Cnmt Isol monitor lights - LIT Verify Cnmt Vent isolation Group 6 Cnmt Vent Isol monitor lights - LIT Verify AF system:
AF pumps - BOTH RUNNING AF isolation valves - OPEN 1AF13A-H AF flow control valves - THROTTLED 1AF005A-H Verify CC pumps - BOTH RUNNING.
Comments:
Braidwood NRC 13-1 Page 21 Scenario No:
NRC 13-1 Event No.
6, 7 & 8 Event
==
Description:==
1B SGTR, 1A CV pump trips/1B CV pump fails to auto start, 1B SG faulted/ruptured Time Position Applicants Actions or Behavior Verify SX pumps - BOTH RUNNING.
ATC/
BOP Check Main Steamline Isolation not required.
Check pressures:
o SG pressures > 640 psig - continue on in 1BwEP-0.
o SG pressures < 640 psig - verify MSIVs and MSIV bypass valves closed.
CNMT pressure > 8.2 psig.
ATC/
CNMT pressure remained < 20 psig.
ATC/
AF flow > 500 gpm S/G level not rising in an uncontrolled manner o
Close 1AF013B & F ATC/
BOP Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights required for injection - LIT Verify ECCS flow High Head SI flow >100 gpm (1FI-917) o RCS pressure < 1700 psig o SI pump discharge flow > 200 gpm o RCS pressure > 325 psig ATC Check PZR PORVs and SPRAYs:
PORV isolation valves - ENERGIZED PORV relief paths - PORVs in AUTO, PORV isolation valves OPEN Normal PZR Spray valves - CLOSED ATC Maintain RCS temperature control Check RCPs - RUNNING Verify RCS average temperature stable at or trending to 557oF o Throttle AF flow o Isolate AF flow to 1B SG ATC Check status of RCPs
- All RCPs - RUNNING
- Check RCP trip criteria o
RCS pressure > 1425 psig - continue on in 1BwEP-0
Comments:
Braidwood NRC 13-1 Page 22 Scenario No:
NRC 13-1 Event No.
6, 7 & 8 Event
==
Description:==
1B SGTR, 1A CV pump trips/1B CV pump fails to auto start, 1B SG faulted/ruptured Time Position Applicants Actions or Behavior o
RCS pressure < 1425 psig
- Verify high head injection flow (1FI-917) > 100 gpm
- Trip all RCPs BOP/
ATC Check if SG secondary pressure boundaries are intact:
- Check pressure in all SGs:
- 1B SG pressure dropping in an uncontrolled manner CREW Transition to 1BwEP-2, FAULTED STEAM GENERATOR ISOLATION
Comments:
Braidwood NRC 13-1 Page 23 Scenario No:
NRC 13-1 Event No.
7 & 9 Event
==
Description:==
1B SGTR (450 gpm), Faulted 1B SG Time Position Applicants Actions or Behavior US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Request STA evaluation of status trees Enter/Implement 1BwEP-2 and direct operator actions of 1BwEP-2 to establish the following conditions BOP Check MS isolation
- 1B SG pressure dropping in an uncontrolled manner
[CT]
E-2--A Isolate 1B Steam Generator prior to completing step 4 of 1BwEP-2.
Verify/Close 1AF013B & F - may have already been closed at step 15 of 1BwEP-0 1B row of FW isolation monitor lights - lit 1MS018B open, 1MS019B closed (previously).
1SD002E & F closed 1SD005C closed BOP Check Annunciator AF PUMP SX SUCTION VLVS ARMED (1-3-E7) - NOT LIT CREW Check Secondary Radiation Depress Phase A Reset Pushbuttons at 1PM06J OPEN 1SD005A-D at 1PM11J Request Chemistry sample SG for activity (US)
Check 1AR22/23B 1B Main Steam Line on PPC or RM-11 o Discuss 1PR27J o Check 1C MS Line radiation CREW Transition to 1BwEP-3, STEAM GENERATOR TUBE RUPTURE US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions
Comments:
Braidwood NRC 13-1 Page 24 Scenario No:
NRC 13-1 Event No.
7 & 9 Event
==
Description:==
1B SGTR (450 gpm), Faulted 1B SG Time Position Applicants Actions or Behavior o Request STA evaluation of status trees Enter/Implement 1BwEP-3 and direct operator actions of 1BwEP-3 to establish the following conditions:
- Check Status of RCPs:
RCPs - may have been tripped earlier when RCP trip criteria met BOP Identify ruptured SG 1B 1B Main steam line rad monitor ABNORMAL for plant conditions Isolate ruptured SG 1MS018B inoperable due to hydraulic leak (1MS019B closed) o Confer with SM about continuing procedure with 1MS018B NOT in auto Verify 1SD002E & F CLOSED Verify MSIVs and MSIV bypass valves for 1B SG CLOSED Check PORVs on intact (1A, 1C, & 1D) SGs available for RCS cool down Check ruptured SG level - Narrow Range < 31%
Do not feed 1B SG per caution prior to step o Verify/close 1AF013B & F - should have already been closed in 1BwEP-0 OR 1BwEP-2 CREW Determine ruptured SG pressure < 320 psig Transition to 1BwCA-3.1, SGTR WITH LOSS OF REACTOR COOLANT - SUBCOOLED RECOVERY DESIRED US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions o Request STA evaluation of status trees Enter/Implement 1BwCA-3.1 and direct operator actions of 1BwCA-3.1 ATC/BO P
Reset SI Depress both SI reset pushbuttons Verify SI actuated permissive light - NOT LIT Verify auto SI blocked permissive light - LIT Reset CNMT isolation Reset phase A isolation Check SAC - one running Open 1IA065 and 1IA066
Comments:
Braidwood NRC 13-1 Page 25 Scenario No:
NRC 13-1 Event No.
7 & 9 Event
==
Description:==
1B SGTR (450 gpm), Faulted 1B SG Time Position Applicants Actions or Behavior Verify all AC buses energized by offsite power All 4 KV ESF buses energized All 4KV non-ESF buses energized All 6.9 KV buses energized De-energize PZR Heaters Place all B/U heaters contactors to OFF Place variable heaters in NAT o
Consult with SM (TSC) for recommended minimum Prz level.
Check if CS should be stopped CS pumps - NONE running Check ruptured SG level 1B SG NR level < 31% - do not feed 1B SG per caution prior to step Check if RH pumps should be stopped
- 1SI8812A & B open (aligned to RWST)
- RCS pressure > 325 psig and stable/rising
- Stop both RH pumps and place in standby Note: At this point the scenario may be terminated at examiner discretion.
Final
WC-AA-111 Revision 4 Page 25 of 61 ATTACHMENT 10 SURVEILLANCE WO DISPOSITION SHEET (APPLICABLE TO MID-WEST SITES ONLY)
Page 1 of 1 Unit: _1__
Procedure:
PMID/RQ: ______
1BwOSR 3.7.4.1_
123456____ Work Order #: __ N/A PMID/RQ
Title:
PMID/RQ Due Date: ___
MAIN STEAM SYSTEM ISOLATION 1MS018A/B/C/D VALVE TRAVEL AND INDICATION 18 MONTH SURVEILLANCE N/A________ PMID/RQ Late Date: N/A Signature/Authorization Approval Review: Name Date Shift Authorization to Start Work:
Time
_Joe Supervisor ______ Today Work Started 1 HR ago Work Stopped:
Supv Review of Work Completion:
ANI Review of work package:
Surveillance Found Within Acceptance Criteria YES NO Surveillance Left Within Acceptance Criteria YES NO (Work Started date (above shall be Complete one of the following:
the credit date unless otherwise explained)
Verify Credit Surveillance Credit Date per another WO# ______________
Below:
If crediting per another WO, verify credit date is Work Started date of referenced WO.
Complete Sat - Credit Surveillance Complete w/ Portions Unsat - Credit Surveillance No Work Performed - Credit Surveillance Failed - Do Not Credit (Surv Due/Late Dates will NOT advance)
No Work Performed - Do Not Credit (Surv Due/Late Dates will NOT advance)
Comments _____________________________________________
ADDITIONAL REVIEW OF RESULTS (IF REQUIRED)
_IST Coordinator Title Signature Date
WC-AA-111 Revision 4 Page 25 of 61
1BwOSR 3.7.4.1 Revision 2 Continuous Use 1
MAIN STEAM SYSTEM ISOLATION 1MS018A/B/C/D VALVE TRAVEL AND INDICATION 18 MONTH SURVEILLANCE A.
STATEMENT OF APPLICABILITY This procedure outlines the steps necessary to verify that the Steam Generator Power Operated Relief Valves (PORV) cycle through the full range of travel with correct position indication when tested pursuant to Tech Spec SR 3.7.4.1 and 5.5.8. This procedure also satisfies Tech Spec SR 3.7.4.2 for the Steam Generator PORV block valves. Testing will be performed at least once per 18 months and is applicable in Modes 1, 2, 3 and 4.
B.
REFERENCES 1.
Tech Spec LCO: 3.7.4 2.
Tech Spec Surveillance Requirements:
a.
SR 3.7.4.1 b.
5.5.8 c.
SR 3.7.4.2 3.
Station Procedures:
a.
BwVP 200-4, ISI Refueling Outage Requirements for Class 1, 2, and 3 valves b.
1BwOSR 3.6.3.5.MS-1, Main Steam System Containment Isolation Valve Stroke Quarterly Surveillance c.
1BwOL 3.7.4, LCOAR - Steam Generator (SG) Power Operated Relief Valves (PORVs).
4.
Station Drawing: M-35-2 5.
Inservice Testing Program Plan for Valves (IST Program).
6.
UFSAR Sections:
a.
10.3 b.
15.6.3
1BwOSR 3.7.4.1 Revision 2 Continuous Use 2
C.
PREREQUISITES 1.
Receive permission to perform the surveillance from the Shift Manager or designee prior to performance by having the Data Package Cover Sheet signed and dated.
2.
The UNIT may be in MODE 1, 2, 3, 4, 5, 6 or DEFUELED with no cooldown using steam dumps in progress. A partial surveillance may be performed in any MODE per the discretion of the Shift Manager or designee.
3.
VERIFY adequate communication is established between the Control Room and field personnel.
D.
PRECAUTIONS None.
E.
LIMITATIONS AND ACTIONS 1.
In the event the Acceptance Criteria is not met during the performance of this surveillance, IMMEDIATELY notify the Shift Manager or designee to declare the valve inoperable and implement 1BwOL 3.7.4 as required.
2.
For any valve declared inoperable, demonstrate acceptable operation after required corrective action has been taken, but before returning the valve to service.
3.
If possible, PERFORM 1BwOSR 3.6.3.5.MS-1 (when required) concurrently with this procedure to obtain both valve stroke timing data and indication check documentation.
1BwOSR 3.7.4.1 Revision 2 Continuous Use 3
F.
MAIN BODY 0.0 SURVEILLANCE OVERVIEW 0.1 Parallel strings of Subsections are independent of one another so that they may be performed in any order or individually if performance of a partial surveillance is required.
0.2 The Subsections are normally performed sequentially.
0.3 The Subsections of this surveillance perform the following:
F.1.0 Establishes initial conditions.
F.2.0 Stroke and Indication Test of 1MS018A, S/G 1A PORV and stroke of 1MS019A S/G 1A Atmospheric Relief Isol.
F.3.0 Stroke and Indication Test of 1MS018B, S/G 1B PORV and stroke of 1MS019B S/G 1B Atmospheric Relief Isol.
F.4.0 Stroke and Indication Test of 1MS018C, S/G 1C PORV and stroke of 1MS019C S/G 1C Atmospheric Relief Isol.
F.5.0 Stroke and Indication Test of 1MS018D, S/G 1D PORV and stroke of 1MS019D S/G 1D Atmospheric Relief Isol.
1.0 3.0 4.0 5.0 2.0 END START
1BwOSR 3.7.4.1 Revision 2 Continuous Use 4
F.
1.0 INITIAL CONDITIONS NOTE Initial each step in the space provided adjacent to the procedure step number AFTER that step has been SUCCESSFULLY completed. Person(s) performing VERIFICATIONS SHALL initial in the space provided following the step.
NOTE Each subsections that performs a valve indication test contains two substeps for performing open and closed tests. Either of these two substeps may be completed first when performing the subsection.
_____1.1 VERIFY all applicable PREREQUISITES, PRECAUTIONS, and LIMITATIONS AND ACTIONS satisfactorily addressed.
_____1.2 VERIFY the IST COORDINATOR is listed in the Work Description Section of the Data Package Cover Sheet to review the results.
1BwOSR 3.7.4.1 Revision 2 Continuous Use 5
F.
2.0 STROKE AND INDICATION TEST OF 1HOV-MS018A, S/G 1A PORV 2.1 RECORD the "AS FOUND" position of the following:
1MS018A, S/G 1A PORV CLOSED/PERCENT OPEN: __________
1MS019A, S/G 1A Atmospheric Relief Isol CLOSED/OPEN
_____2.2 VERIFY/CLOSE 1MS019A.
2.3 PERFORM an OPEN indication test of 1MS018A, S/G 1A PORV, as follows:
¢ ____
a.
VERIFY/OPEN 1MS018A, at 1PM04J (verify open light indication).
¢ ____
b.
VERIFY 1MS018A is open by field observation. (401')
2.4 PERFORM a close indication test of 1MS018A, S/G 1A PORV, as follows:
¢ ____
a.
VERIFY/CLOSE 1MS018A at 1PM04J (verify CLOSED light indication).
¢ ____
b.
VERIFY 1MS018A is closed by field observation. (401')
¢ ____2.5 VERIFY 1MS018A was stroked through one complete cycle.
NOTE The following step may be marked N/A if the SG PORV is being stroked for a partial surveillance after maintenance affecting valve operability and credit is NOT being taken for the IST surveillance requirements for 1MS019A.
¢ ____2.6 VERIFY/STROKE 1MS019A through one complete cycle.
2.7 RESTORE the following equipment to the "AS FOUND" POSITION or as directed by the Shift Manager or designee (RECORD the POSITION).
1MS018A, S/G 1A PORV CLOSED/PERCENT OPEN: __________
VERIFICATION _____
1MS019A, S/G 1A Atmospheric Relief Isol CLOSED/OPEN VERIFICATION _____
1BwOSR 3.7.4.1 Revision 2 Continuous Use 6
F.
3.0 STROKE AND INDICATION TEST OF 1HOV-MS018B, S/G 1B PORV 3.1 RECORD the "AS FOUND" position of the following:
1MS018B, S/G 1B PORV CLOSED/PERCENT OPEN: __________
1MS019B, S/G 1B Atmospheric Relief Isol CLOSED/OPEN
_____3.2 VERIFY/CLOSE 1MS019B.
3.3 PERFORM an OPEN indication test of 1MS018B, S/G 1B PORV, as follows:
¢ ____
a.
VERIFY/OPEN 1MS018B, at 1PM04J (verify open light indication).
¢ ____
b.
VERIFY 1MS018B is open by field observation. (401')
3.4 PERFORM a CLOSE indication test of 1MS018B, S/G 1B PORV, as follows:
¢ ____
a.
VERIFY 1MS018B indicates CLOSED at 1PM04J.
¢ ____
b.
VERIFY 1MS018B is closed by field observation. (401')
¢ ____3.5 VERIFY 1MS018B was stroked through one complete cycle.
NOTE The following step may be marked N/A if the SG PORV is being stroked for a partial surveillance after maintenance affecting valve operability and credit is NOT being taken for the IST surveillance requirements for 1MS019B.
¢ ____3.6 VERIFY/STROKE 1MS019B through one complete cycle.
3.7 RESTORE the following equipment to the "AS FOUND" position or as directed by the Shift Manager or designee (RECORD the POSITION).
1MS018B, S/G 1B PORV CLOSED/PERCENT OPEN: __________
VERIFICATION _____
1MS019B, S/G 1B Atmospheric Relief Isol CLOSED/OPEN VERIFICATION _____
1BwOSR 3.7.4.1 Revision 2 Continuous Use 7
F.
4.0 STROKE AND INDICATION TEST OF 1HOV-MS018C, S/G 1C PORV 4.1 RECORD the "AS FOUND" position of the following:
1MS018C, S/G 1C PORV CLOSED/PERCENT OPEN: __________
1MS019C, S/G 1C Atmospheric Relief Isol CLOSED/OPEN
_____4.2 VERIFY/CLOSE 1MS019C.
4.3 PERFORM an OPEN indication test of 1MS018C, S/G 1C PORV, as follows:
¢ ____
a.
VERIFY/OPEN 1MS018C, at 1PM04J (verify open light indication).
¢ ____
b.
VERIFY 1MS018C is open by field observation. (401')
4.4 PERFORM a CLOSE indication test of 1MS018C, S/G 1C PORV, as follows:
¢ ____
a.
VERIFY 1MS018C indicates CLOSED at 1PM04J.
¢ ____
b.
VERIFY 1MS018C is closed by field observation. (401')
¢ ____4.5 VERIFY 1MS018C was stroked through one complete cycle.
NOTE The following step may be marked N/A if the SG PORV is being stroked for a partial surveillance after maintenance affecting valve operability and credit is NOT being taken for the IST surveillance requirements for 1MS019C.
¢ ____4.6 VERIFY/STROKE 1MS019C through one complete cycle.
4.7 RESTORE the following equipment to the "AS FOUND" position or as directed by the Shift Manager or designee (RECORD the POSITION).
1MS018C, S/G 1C PORV CLOSED/PERCENT OPEN: __________
VERIFICATION _____
1MS019C, S/G 1C Atmospheric Relief Isol CLOSED/OPEN VERIFICATION _____
1BwOSR 3.7.4.1 Revision 2 Continuous Use 8
F.
5.0 STROKE AND INDICATION TEST OF 1HOV-MS018D, S/G 1D PORV 5.1 RECORD the "AS FOUND" position of the following:
1MS018D, S/G 1D PORV CLOSED/PERCENT OPEN: __________
1MS019D, S/G 1D Atmospheric Relief Isol CLOSED/OPEN
_____5.2 VERIFY/CLOSE 1MS019D.
5.3 PERFORM an OPEN indication test of 1MS018D, S/G 1D PORV, as follows:
¢ ____
a.
VERIFY/OPEN 1MS018D, at 1PM04J (verify open light indication).
¢ ____
b.
VERIFY 1MS018D is open by field observation. (401')
5.4 PERFORM a CLOSE indication test of 1MS018D, S/G 1D PORV, as follows:
¢ ____
a.
VERIFY 1MS018D indicates CLOSED at 1PM04J.
¢ ____
b.
VERIFY 1MS018D is closed by field observation. (401')
¢ ____5.5 VERIFY 1MS018D was stroked through one complete cycle.
NOTE The following step may be marked N/A if the SG PORV is being stroked for a partial surveillance after maintenance affecting valve operability and credit is NOT being taken for the IST surveillance requirements for 1MS019D.
¢ ____5.6 VERIFY/STROKE 1MS019D through one complete cycle.
5.7 RESTORE the following equipment to the "AS FOUND" position or as directed by the Shift Manager or designee (RECORD the POSITION).
1MS018D, S/G 1D PORV CLOSED/PERCENT OPEN: __________
VERIFICATION _____
1MS019D, S/G 1D Atmospheric Relief Isol CLOSED/OPEN VERIFICATION _____
1BwOSR 3.7.4.1 Revision 2 Continuous Use 9
G.
ACCEPTANCE CRITERIA 1.
Proper limit switch setting has been verified by simultaneous verification of the valve position with both local and remote indication for each following valve:
a.
1MS018A, S/G 1A PORV b.
1MS018B, S/G 1B PORV c.
1MS018C, S/G 1C PORV d.
1MS018D, S/G 1D PORV 2.
The Steam Generator Power Operated Relief Valves (PORV) were verified to stroke through one complete cycle.
3.
The Steam Generator Power Operated Relief Block Valves were verified to stroke through one complete cycle.
(Final)
Simulation Facility Braidwood Scenario No.:
NRC 13-2 Operating Test No.: 2013-1 Examiners:
Applicant:
_____________________ SRO
_____________________ RO
_____________________ BOP Initial Conditions:
IC-31 Turnover:
Unit 1 is at 90% power, steady state, equilibrium xenon, BOL. Online risk is green. 1B Heater Drain Pump is OOS for motor replacement for the past 3 days. Expected back in service in 7 days. 1CV8149C was returned to service last shift following maintenance to replace its fuse block. Following completion of turnover, the shift manager requests the BOP swap 75 gpm letdown orifices from 1CV8149B to 1CV8149C per BwOP CV-9 for an upcoming clearance order on 1CV8149B to replace its fuse block while the RO monitors reactor power.
Event No.
Malf. No.
Event Type*
Event Description IOR ZDI1HD01PB PTL IMF MS01A 100 IMF MS01B 100 IMF MS01C 100 IMF MS01D 100 IMF CS01B MRF RP37 OUT TRGSET 1 YP:MFW35A==1 TRG 1 IMF TH11A (0
- 90) 5 TRGSET 2 ZLO 1RY8000A(2)==0 MRF ED058C (2 10)
OPEN 1B HD pump OOS MSIV fail to close MSIV fail to close MSIV fail to close MSIV fail to close 1B CS pp failure K643 CS Trn A actuation relay failure PZR PORV 455A failure 1RY8000A block valve breaker trips 1
None N-BOP, US Swap 75 gpm Letdown orifices 2
IMF RX18H 650 IMF RX18L 650 I-ATC, US TS, US Loop 4 Thot RTD fails high 3
IMF RX03C 4.8 I-BOP, US 1FT-522 fails high (Stm Flow) 4 IMF FW35A C-BOP, US R-RO, US 1A Heater Drain Pump trip requiring turbine runback 5
Preload C-ATC, TS-US 1RY455A partially opens 1RY8000A block valve breaker trips 6
MS07C 4 0 M-ALL Uncontrolled depressurization of all SGs 7
Preload C-BOP, US Failure of both trains of CS to automatically actuate 8
DMF MS01D C-ALL 1A &1D MSIVs close
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
Braidwood NRC 13-2 Page 2 SCENARIO OVERVIEW Unit 1 is at 90% power, steady state, equilibrium xenon, BOL. Online risk is green. 1B Heater Drain Pump is OOS for motor replacement for the past 3 days. Expected back in service in 7 days. 1CV8149C was returned to service last shift following maintenance to replace its fuse block. Following completion of turnover, the shift manager requests the BOP swap 75 gpm letdown orifices from 1CV8149B to 1CV8149C per BwOP CV-9 for an upcoming clearance order on 1CV8149B to replace its fuse block while the RO monitors reactor power.
After completing shift turnover and relief, the crew will swap 75 gpm letdown orifices. The BOP will manually lower letdown pressure, remove 1CV8149B from operation and place 1CV8149C on-line. The BOP will then restore letdown line pressure and restore letdown to automatic operation After completing the letdown orifice swap, Loop 4 Thot fails high, resulting in demanded rod inward motion. The crew should take actions to stabilize the plant per 1BwOA INST-2 attachment A. Technical Specifications 3.3.1 applies.
After the RTD failure has been addressed, a failure of 1FT-522 steam flow channel will occur. The crew will enter 1BwOA INST-2 and perform appropriate actions. The crew should swap to an operable steam flow channel. No Technical Specification applies.
After completion of 1BwOA INST-2 actions, 1A Heater Drain Pump will trip. 1BwOA SEC-1, SECONDARY PUMP TRIP-Attachment C will be entered. The BOP will initiate a turbine load reduction to 780 MW at 20 MW/minute. The RO will borate the RCS as necessary to stabilize RCS temperature.
As the crew is reducing load to address the 1A HD pump, PZR PORV 1RY455A will open to the intermediate position, resulting in a slow RCS pressure drop. The ATC will isolate the PZR PORV by closing 1RY8000A, PORV block valve. Once 1RY8000A is closed, its breaker will trip open 10 seconds later, removing power from 1RY8000A. 1RY455A will remain unavailable for the remainder of the scenario.
Tech Spec 3.4.11, conditions B and C apply. If pressure drops below 2209 psig, Tech Spec 3.4.1 will apply.
After the plant is stabilized and failure of 1RY455A addressed, a large fault will occur on the 1C MS line. When containment pressure reaches 20 psig, Phase B actuates but the CS pumps do not start. The crew should manually realign train A CS valves which will start the 1A CS pump. Operators should transition to 1BwEP-2 and recognize that the MSIVs have failed to close and that an uncontrolled depressurization of all SGs is in progress. The crew should transition to 1BwCA-2.1 where they will throttle AF flow to the SGs. Entry into 1BwFR-H.1 will be required when the crew throttles AF flow to 45 gpm per SG, however, a note in 1BwFR-H.1 directs the procedure not to be performed. The crew will continue in 1BwCA-2.1 until SI termination when the 1A & 1D MSIVs will close and the crew will transition to 1BwEP-2.
The crew will then isolate AF to the 1B & 1C SGs. Entry into 1BwFR-P.1 may be required as directed by the status trees.
Completion criteria is completion of 1BwEP-2.
Critical Tasks
- 1. Manually actuate one train of containment spray prior to transition out of 1BwEP-0.
(ERG Critical Task number - E-0--E) (K/A number - 013000A4.01 importance - 4.5/4.8)
(ERG Critical Task number - ECA-2.1--A) (K/A number - 0WE12EA1.3 importance - 3.4/3.9)
Braidwood NRC 13-2 Page 3 SIMULATOR SETUP GUIDE:
Verify/perform TQ-BR-201-0113, BRAIDWOOD TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.
Establish the conditions of IC-31, 90% power, steady state, equilibrium xenon.
Verify OA & OC VA plenums in service.
Complete items on Simulator Ready for Training Checklist.
Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.
Place simulator in RUN (allow simulator to run during board walk down and turnover).
Place 1B HD pump in PTL.
Run caep NRC 13-2 SETUP from disk and verify the following actuate:
IOR ZDI1HD01PB PTL IMF MS01A 100 IMF MS01B 100 IMF MS01C 100 IMF MS01D 100 IMF CS01B MRF RP37 OUT TRGSET 1 YP:MFW35A==1 TRG 1 IMF TH11A (0 90) 5 TRGSET 2 ZLO1RY8000A(2)==0 MRF ED058C (2 10) OPEN Place info tag on 1B HD pump and INFO tag on 1HD075B.
Verify/Set I Target Curve slopes to +2% of I.
Provide examinees with turnover sheets and 1BwOS NR-1.
Braidwood NRC 13-2 Page 4 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Swap Letdown orifices As SM, acknowledge the completion of letdown orifice swap.
Event 2: Loop 4 Thot RTD fails high Run caep NRC 13-2 EVENT 2 from disk and verify the following actuate:
IMF RX18H 650 IMF RX18L 650 Acknowledge as SM entry into TS 3.3.1, conditions A and E entry, request for NSOs, on line risk assessment, request for maintenance support, and IR requests.
As SM, if requested support for tripping bistables, report that bistables are not to be tripped until work analyst
/NSO support can be obtained (i.e. not at this time) and that the abnormal operating procedure should be continued. Bistable tripping will be conducted later.
Event 3: Steam Flow detector 1FT-522 failure Insert IMF RX03C 4.8 As SM, acknowledge failure of 1FT-522, and requests for on line risk assessment, maintenance support, and IR initiation and evaluation for full power restoration.
As SM, acknowledge request for personnel notifications.
Event 4: 1A Heater Drain Pump trip Insert IMF FW35A As SM, acknowledge the failure, 1BwOA SEC-1 entry, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation.
If dispatched as EO, report 1A Heater Drain pump is seized and report ground overcurrent flag at breaker cubicle.
Note: Verify that Event 5 initiates 90 seconds after initiating Event 4.
Braidwood NRC 13-2 Page 5 Event 5: 1RY455A partially opens/1RY8000A block valve breaker trips.
Verify the preload actuates: (malfunction TH11A will open to a value of 5% 90 seconds after malfunction FW35A initiates; followed by remote function RF ED058C to OPEN to de-energize 1RY8000A 10 seconds after it fully closes).
If dispatched as Equipment Operator, report 1RY8000A breaker (131X2B A5 front and rear) is tripped. If breaker reclosure is requested, the breaker will not close.
Acknowledge as Shift Manager the failure(s), LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.
If ramp is suspended, acknowledge as Power Team suspension of ramp.
If asked for direction from SM for ramping unit, direct crew to re-initiate the ramp when actions for 1PT-508 failure are complete.
Event 6/7: Uncontrolled depressurization of all SGs/Auto SI, and CS failures Insert IMF MS07C 4 0 Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
After STA requested, as STA report CSF status: Red on heat sink when AF throttled to 45 gpm per SG, orange on integrity if RCS temperature < 240°F.
If dispatched as EO to investigate 1B CS pump, report ground overcurrent flag at breaker cubicle.
Event 8: After the crew enters 1BwCA-2.1, PERFORM THE FOLLOWING IMMEDIATELY AFTER AF IS THROTTLED TO 45 GPM PER SG 1A & 1D MSIVs close DMF MS01A DMF MS01D Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
Comments:
Braidwood NRC 13-2 Page 6 Scenario No:
NRC 13-2 Event No.
1 Event
==
Description:==
Swap 75 gpm Letdown orifices Time Position Applicants Actions or Behavior CUE
- Shift manager requests swapping 75 gpm letdown orifices from 1B to 1C (from turnover).
US
- Refers to BwOP CV-9
- Determine BwOP CV-9, step F.3 to be performed
- Lower letdown pressure Place 1PK-131, LTDWN Line Press Cont Vlv 1CV131, to MANUAL Raise demand on 1PK-131, LTDWN Line Press Cont Vlv 1CV131, to lower letdown pressure to ~ 180 psig (1PI-131)
- Remove 1B letdown orifice from operation Close 1CV8149B
- Align 1C letdown orifice (simultaneous operation)
Open 1CV8149C
- Restore automatic letdown pressure control Verify letdown pressure stable at ~370 psig (1PI-131)
Place 1PK-131, LTDWN Line Press Cont Vlv 1CV131, to AUTO
- Verify letdown temperature 90°F - 115°F (1TI-130)
- Verify PZR level is being maintained at the program value
- Inform US letdown orifices swapped US
- Acknowledge report o Notify SM 75 gpm letdown orifices swapped from 1B to 1C NOTE: After the actions for swapping letdown orifices are complete and with lead examiner concurrence, enter next event
Comments:
Braidwood NRC 13-2 Page 7 Scenario No:
NRC 13-2 Event No.
2 Event
==
Description:==
Loop D Thot RTD fails high.
Time Position Applicants Actions or Behavior CUE Loop D Tave rises Loop D T rises Control rod inward motion Annunciator CHG LINE FLOW HIGH LOW (1-9-D3)
Annunciator OPDT HIGH ROD STOP C-4 (1-10-A5)
Annunciator OTDT HIGH ROD STOP C-3 (1-10-C5)
ATC Determines rod motion due to instrument failure Place rod bank select switch in MANUAL ATC Identify/report failed Tave & T Determine RTD failed on Loop D Maintain Rod Bank Select switch in MANUAL US Implement 1BwOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment A "RCS NARROW RANGE RTD CHANNEL FAILURE" and direct operator actions.
ATC Manually defeat failed RTD channel Select 1D position on Tave DEFEAT switch Select 1D position on T DEFEAT switch Check Reactor Power < 100%
Select operable channel for T recorder Check if rod control can be placed in auto C5 - NOT LIT Check Tave-Tref stable and within 1°F o Restore to within 1°F Place rod control in AUTO Check PZR level normal & stable o Manually restore PZR level to program level - throttle 1CV121 to restore level ATC Check P12 interlock LO-2 TAVE STM DUMP INTLK P12 (1-BP-4.5) not lit BOP Place Computer point T0462A in TEST Place Computer point T0460 in DELETE FROM SCAN
Comments:
Braidwood NRC 13-2 Page 8 Scenario No:
NRC 13-2 Event No.
2 Event
==
Description:==
Loop D Thot RTD fails high.
Time Position Applicants Actions or Behavior US Check Technical Specifications:
Determines TS 3.3.1 conditions A and E are applicable.
US Inform SM/Maint of Loop 1D Thot RTD failure Inform SM of unit status/potential EP event and TS 3.3.1 cond A and E entry.
o Enter dequip for P-12 Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure The next event is to be inserted following the above actions by the US and Lead Examiner concurrence.
Comments:
Braidwood NRC 13-2 Page 9 Scenario No:
NRC 13-2 Event No.
3 Event
==
Description:==
Steam Flow detector 1FT-522 failure Time Position Applicants Actions or Behavior CUE Annunciator SG 1B FLOW MISMATCH FW FLOW LOW (1-15-B4) 1FI522A flow indicator fails high.
1B SG level indicators 1LI527/528/529/557 indicate rising level o
Annunciator SG 1B LEVEL DEVIATION HIGH LOW (1-15-B9)
ATC/
BOP Determine 1FT-522 failed High.
Reference BwARs CREW Identify entry conditions for 1BwOA INST-2, OPERATION WITH FAILED INSTRUMENT CHANNEL US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BwOA INST-2, OPERATION WITH FAILED INSTRUMENT CHANNEL, Attachment H, STEAM FLOW CHANNEL FAILURE and direct operator actions of 1BwOA INST-2 to establish the following conditions:
BOP Stabilize 1B SG level (actions to stabilize may be performed per BwAR or 1BwOA INST-2) o If SG level abnormal o Control 1B FRV (1FW520) in manual o Place master feed pump speed control in manual o Verify adequate feedwater DP o Restore SG level(s)
Select operable steam flow channel (may be done per BwAR actions)
Establish/verify automatic SG level control Verify steam pressure channels normal CREW Check Rx Power <100%
10 min. calorimetric NIs US Contact SM/maintenance to investigate/correct the failed steam flow channel Determines TS is NOT applicable.
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
Contact SM or make appropriate personnel notifications.
Comments:
Braidwood NRC 13-2 Page 10 Scenario No:
NRC 13-2 Event No.
3 Event
==
Description:==
Steam Flow detector 1FT-522 failure Time Position Applicants Actions or Behavior EVALUATOR NOTE: After the actions for the instrument failure are complete and with lead examiners concurrence, insert the next event.
Comments:
Braidwood NRC 13-2 Page 11 Scenario No:
NRC 13-2 Event No.
4 Event
==
Description:==
1A Heater Drain Pump Trip Time Position Applicants Actions or Behavior CUE Annunciator HD PUMP TRIP (1-17-D2)
HD Tank level rising HD Pump discharge valves opening BOP
- Recognizes 1A HD pump tripped o Refer to BwAR 1-17-D2 as time permits
- Reports failure to US
- Recognizes one Heater Drain Pump running CREW
- Identify entry conditions for 1BwOA SEC-1, SECONDARY PUMP TRIP US
- Acknowledge 1A HD pump trip
- Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure
- Implement 1BwOA SEC-1, SECONDARY PUMP TRIP Attachment C "HD PUMP TRIP" and direct operator actions of 1BwOA SEC-1 to establish the following conditions.
BOP Recognizes standby HD pump NOT AVAILABLE Check HD pump status ONLY 1C HD pump running Initiate turbine load reduction to 780 MW at 20 MW/min Initiate HD runback on OWS graphic 5512 Verify turbine load lowering BOP Check HD Tank level Level > 72% and rising Maintain HD tank level o Verify 1HD046A &B in AUTO o Open 1CB113A-D o Manually open 1HD117, HD tank overflow valve o Lower turbine load as necessary to maintain HD tank level <72%
Check 1HD117, HD tank overflow valve in auto and closed o
Lower turbine load as necessary to close 1HD117 Check 1C HD pump parameters 1C HD pump amps < 168 amps 1C HD pump flow < 2950 KLB/HR
Comments:
Braidwood NRC 13-2 Page 12 Scenario No:
NRC 13-2 Event No.
4 Event
==
Description:==
1A Heater Drain Pump Trip Time Position Applicants Actions or Behavior o
Lower turbine load as necessary to restore 1C HD pump parameters Deactivate turbine runback.
US/RO Check PDMS operable Annunciator PDMS INOPERABLE not lit (1-10-E8) 1BwOS PDMS-1A not implemented Annunciator PDMS LIMIT EXCEEDED not lit (1-10-D7)
RO Control I near target Operate control rods in manual to restore I near target Monitor RCS parameters o
If RCS pressure lowers < 2209 psig, notify US to enter TS 3.4.1, RCS DNB Limits o
If control rods < LO - 2 rod insertion limit, notify US to enter TS 3.1.6, Control Bank Insertion Limits RO Initiate RCS boration Determine required boric acid volume (approximate band: 250 gal - 400 gal) o Determine from Op Aid (ramp starts from 90%)
Per BwOP CV-6 or Hard Card:
Determine desired boric acid flow rate Set 1FK-110 BA Flow Control to desired boration rate Set 1FY-0110 BA Blender Predet Counter to desired volume.
Place MAKE-UP MODE CONT SWITCH to STOP position Place MODE SELECT SWITCH to BORATE position Place MAKE-UP MODE CONT SWITCH to START Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).
o Turn on PZR backup heaters in accordance with BwOP RY-14, PRESSURIZER BACKUP HEATER OPERATION.
OR Batch addition of Boric Acid:
Open 1CV110B Open 1CV110A Start the BA Transfer pump When desired amount of BA has been added, stop the BA Transfer Pump Close 1CV110A Close 1CV110B
Comments:
Braidwood NRC 13-2 Page 13 Scenario No:
NRC 13-2 Event No.
4 Event
==
Description:==
1A Heater Drain Pump Trip Time Position Applicants Actions or Behavior o May flush boric acid lines per BwOP CV-6 step. F.5.
BOP Verify running CB pump recirc valves in auto 1CB113A-D on running pumps Dispatch operators to perform BwOP HD-2 for 1A HD pump Shutdown CD/CB pump (if started during procedure performance)
US Notify chemistry to monitor secondary plant chemistry Notify SM to perform risk assessment Check reactor power change > 15% in one hour o
Notify chemistry to perform TS 3.4.16 sampling o
Notify rad protection to perform RETS 12.4.1.A sampling o
Determine TS 3.1.6, condition A entry required if control rods below LO - 2 rod insertion limit The next event (PZR PORV 1RY455A partially opening) will automatically insert 90 seconds after the HD pump trip.
Comments:
Braidwood NRC 13-2 Page 14 Scenario No:
NRC 13-2 Event No.
5 Event
==
Description:==
1RY455A partially opens/1RY8000A block valve breaker trips Time Position Applicants Actions or Behavior CUE Annunciator 1-12-B2, PZR PORV OR SAF VLV OPEN o Annunciator 1-12-C1 PZR PRESS CONT DEV LOW HTRS ON Annunciator 1-12-C6 PZR PORV DSCH TEMP HIGH 1RY455A open and closed lights lit.
PZR pressure dropping on 1PI-455 - 458.
- Perform the following at 1PM05J:
- Recognize 1RY455A PORV has opened prior to reaching lift setpoint.
o Place 1RY455A, PZR PORV, C/S to CLOSE.
o Determine 1RY455A will not close.
- Place 1RY8000A, PZR PORV block valve, C/S to close.
o Report failure to US.
o Recognize/reports DNB LCO 3.4.1 pressure exceeded (<2209 psig) if applicable.
o Recognize loss of indication of 1RY8000A breaker following valve closure.
o Report when DNBR LCO can be exited, if applicable.
o Dispatch operator to investigate 1RY8000A breaker.
BOP o Perform the following:
o Dispatch operators to 1RY8000A breaker.
o Assist US by making notifications.
o Refer to BwARs.
US Acknowledge PORV failure and concur with actions to close PORV and/or PORV block valve.
Determine LCO 3.4.11 Condition B and C are applicable.
o TRM 3.4.d does not apply.
o Acknowledge DNB LCO status (if applicable).
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
EVALUATOR NOTE: After the actions for the PZR PORV failure are complete and the lead examiner is satisfied with the reactivity change, then enter next event.
Comments:
Braidwood NRC 13-2 Page 15 Scenario No:
NRC 13-2 Event No.
6, 7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior CUE Annunciator CNMT PRESS HIGH SI/RX TRIP (1-11-E1)
All SG pressures dropping RCS Tave dropping Rx Trip breakers open US Notifies SM of plant status and procedure entry o Requests evaluation of Emergency Plan conditions Enter/Implement 1BwEP-0 and direct operator actions of 1BwEP-0 RO Perform immediate operator actions of 1BwEP-0:
Verify reactor trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux - DROPPING BOP Perform immediate operator actions of 1BwEP-0:
Verify Turbine Trip All Turbine throttle valves - CLOSED All Turbine govenor valves - CLOSED BOP Perform immediate operator actions of 1BwEP-0:
Verify power to 4KV busses ESF Buses - BOTH ENERGIZED RO Perform immediate operator actions of 1BwEP-0:
Check SI status o SI First OUT annunciator - Annunciator CNMT PRESS HIGH SI/RX TRIP (1 E1) LIT o SI ACTUATED Permissive Light - LIT o SI Equipment - AUTOMATICALLY ACTUATED o Either SI pumps - RUNNING o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B Manually actuate SI from 1PM05J and 1PM06J US Direct BOP to perform Attachment B of 1BwEP-0 EVALUATOR NOTE: US and RO will continue in 1BwEP-0 while BOP is performing Attachment B:
Comments:
Braidwood NRC 13-2 Page 16 Scenario No:
NRC 13-2 Event No.
6,7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior BOP 1BwEP-0 ATTACHMENT B Verify FW isolated at 1PM04J:
FW pumps - TRIPPED.
Isolation monitor lights - LIT.
FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.
Verify DGs running at 1PM01J:
DGs - BOTH RUNNING.
1SX169A/B OPEN.
Dispatch operator locally to check operation Verify Generator Trip at 1PM01J:
OCB 1-8 and 7-8 open.
PMG output breaker open.
Verify Control Room ventilation aligned for emergency operations at 0PM02J:
VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.
Operating VC train equipment - RUNNING.
0B Supply fan 0B Return fan 0B M/U fan 0B Chilled water pump 0B Chiller Operating VC train dampers - ALIGNED.
M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.
0B VC train M/U filter light - LIT.
0VC09Y - OPEN 0VC313Y - CLOSED Operating VC train Charcoal Absorber aligned for train B.
0VC44Y - CLOSED 0VC05Y - OPEN 0VC06Y - OPEN Control Room pressure greater than +0.125 inches water on 0PDI-VC038.
Verify Auxiliary Building ventilation aligned at 0PM02J:
Two inaccessible filter plenums aligned.
Plenum A:
- 0VA03CB - RUNNING
- 0VA023Y - OPEN
- 0VA436Y - CLOSED
Comments:
Braidwood NRC 13-2 Page 17 Scenario No:
NRC 13-2 Event No.
6,7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior Plenum C:
- 0VA03CF RUNNING
- 0VA072Y - OPEN 0VA438Y - CLOSED Verify FHB ventilation aligned at 0PM02J:
- 0VA04CB - RUNNING
- 0VA055Y - OPEN
- 0VA062Y - OPEN
- 0VA435Y - CLOSED
- Secure 1C HD pump
- Initiate Periodic Checking of Spent Fuel Cooling
- Notify US Attachment B complete RO/
BOP Verify ECCS pumps running Both CV pumps - RUNNING Both RH pumps - RUNNING Both SI pumps - RUNNING RO/
BOP Verify RCFCs running in Accident Mode - Group 2 RCFC Accident Mode lights - LIT Verify Phase A isolation - Group 3 Cnmt Isol monitor lights - LIT Verify Cnmt Vent isolation - Group 6 Cnmt Vent Isol monitor lights - LIT Verify AF system:
AF pumps - BOTH RUNNING AF isolation valves - OPEN 1AF13A-H AF flow control valves - THROTTLED 1AF005A-H Verify CC pumps - BOTH RUNNING Verify SX pumps - BOTH RUNNING RO/
BOP Check Main Steamlines Should Be Isolated CNMT pressure > 8.2 psig OR SG pressure <640 psig Verify MS isolation MSIVs open Manually actuate MS isolation MSIVs remain open Place C/Ss to close for all MSIVs (all MSIVs remain open)
Comments:
Braidwood NRC 13-2 Page 18 Scenario No:
NRC 13-2 Event No.
6,7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior BOP/
RO Check if CS is required CNMT pressure > 20 psig Group 6 CS monitor lights - NOT ALL LIT Manually actuate CS and Phase B Isolation Group 6 CS monitor lights remain - NOT ALL LIT, Go to attachment C Note: RCPs may be stopped by crew any time after recognizing a Phase B isolation has occurred.
US Implement 1BwEP-0, Attachment C, MANUAL CS ACTUATION
Comments:
Braidwood NRC 13-2 Page 19 Scenario No:
NRC 13-2 Event No.
6,7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior 1BwEP-0, Attachment C, MANUAL CS ACTUATION RO/
[CT]
E-0--E Check CS alignment (NOTE: The examinees will also attempt to align the B train of CS, however only the A train will properly align as outlined below)
Check 1CS001A - OPEN Check 1CS007A - OPEN Manually open 1CS007A Check 1CS019A - OPEN Place 1A CS pump test switch in test Manually open 1CS019A Place 1A CS pump test switch in normal Check 1CS010A - OPEN Check CS pumps - AT LEAST ONE RUNNING 1A CS pump running o
Place 1B CS pump in PTL US Return to main body, step 14.c.
RO/
BOP Check if CS is required Group 6 phase B monitor lights - ALL LIT Verify/Stop all RCPs (may have been done previously)
Check CS eductor suction flow - 1FI-CS013 > 15 gpm Check CS eductor additive flow - 1FI-CS015 > 5 gpm RO/
AF flow > 500 gpm Check status of S/G NR levels - not rising in an uncontrolled manner RO/
BOP Verify ECCS valve alignment Group 2 Cold Leg Injection monitor lights required for injection - LIT RO/
BOP Verify ECCS flow High Head SI flow >100 gpm (1FI-917)
RCS pressure < 1700 psig SI pump flow > 200 gpm RCS pressure > 325 psig
Comments:
Braidwood NRC 13-2 Page 20 Scenario No:
NRC 13-2 Event No.
6,7 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Failure of both CS trains to actuate Time Position Applicants Actions or Behavior RO Check PZR PORVs and SPRAYs:
PORVs CLOSED (1RY455A OPEN).
PORV isolation valves - 1RY8000A (closed and de-energized) and 1RY8000B ENERGIZED PORV relief path - PORV 1RY456 in AUTO, PORV isolation valve OPEN Normal Spray valves CLOSED.
RO Maintain RCS temperature control Check RCPs - NONE RUNNING RCS Tcold temperature is NOT stable at or trending to 557o Stop dumping steam Throttle AF flow while maintaining > 500 gpm MSIVs open - verify closed (will not close) o Crew may throttle AFW flow to 45 gpm per SG RO/
Check if SG secondary pressure boundaries are intact:
All SG pressures dropping in an uncontrolled manner CREW Transitions to 1BwEP-2, FAULTED STEAM GENERATOR ISOLATION
Comments:
Braidwood NRC 13-2 Page 21 Scenario No:
NRC 11113-2 Event No.
6 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs Time Position Applicants Actions or Behavior 1BwEP-2, FAULTED STEAM GENERATOR ISOLATION US Notifies SM of plant status and procedure entry Requests evaluation of Emergency Plan conditions Request STA evaluation of status trees Enter/Implement 1BwEP-2 and direct operator actions of 1BwEP-2 to establish the following conditions RO/
- Check MS isolation MSIVs remain open CREW Check if any secondary pressure boundary intact No SG pressure stable or rising All SGs depressurizing in an uncontrolled manner GO TO 1BwCA-2.1, 'UNCONTROLLED DEPRESSURIZATION OF ALL SGs CREW Transitions to 1BwCA-2.1, UNCONTROLLED DEPRESSURIZATION OF ALL STEAM GENERATORS
Comments:
Braidwood NRC 13-2 Page 22 Scenario No:
NRC 13-2 Event No.
6, 8 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Subsequent 1A and 1D MSIV closure Time Position Applicants Actions or Behavior 1BwCA-2.1, UNCONTROLLED DEPRESSURIZATION OF ALL STEAM GENERATORS US Notifies SM of plant status and procedure entry Requests evaluation of Emergency Plan conditions Enter/Implement 1BwCA-2.1 and direct operator actions of 1BwCA-2.1 to establish the following conditions RO/
BOP Check secondary pressure boundary MSIVs open - attempt to close w/control switch (may have been previously tried)
MSIV bypass valves - CLOSED SG PORVs - CLOSED Check FW isolation monitor lights - LIT Check 1SD002A-H - CLOSED Check 1SD005A-D - CLOSED Examiner note: Throttling AF flow to 45 gpm per SG will result in a red path on the heat sink status tree and require transition to 1BwFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK. 1BwFR-H.1 will be entered and immediately exited due to operator action lowering AF flow to < 500 gpm.
RO/
[CT]
ECA-2.1-
-A Control feed flow to minimize RCS cooldown Throttle AF to 45 gpm per SG Check hot leg temperatures - Stable or Dropping Check RCPs -NONE RUNNING Check Pzr PORVs and Isolation Valves PORV Isolation Valves - 1RY8000A closed/de-energized; 1RY8000B open/energized.
PORVs - 1RY455A OPEN; 1RY456 CLOSED Note: When the crew recognizes 1A & 1D SG MSIVs have closed and pressure is rising in the 1A & 1D SGs, transition is made back to 1BwEP-2 per the OAS.
CREW Transitions to 1BwEP-2, FAULTED STEAM GENERATOR ISOLATION once they recognize 1A & 1D MSIVs closed. (continuation actions in 1BwCA-2.1 are in italics below)
RO/BO P
Check if RCPs should be stopped-No RCPs running Check Secondary Radiation
Comments:
Braidwood NRC 13-2 Page 23 Scenario No:
NRC 13-2 Event No.
6, 8 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Subsequent 1A and 1D MSIV closure Time Position Applicants Actions or Behavior Reset Phase A Open 1SD005A-D Check secondary radiation trends on RM-11 or PPC-ALL Normal Check if RH Pumps Should be Stopped RH Pumps-BOTH Running o Check RCS pressure-Greater than 325 psig If RCS pressure stable or rising and > 325 psig reset SI and stop RH pumps/place in standby Check if CS Should be Stopped CS pumps-1A running Reset CS signal o Spray Add Tank LO-2 lights LIT and CNMT pressure < 15 psig o Secure CS pumps and close 1CS007A/B and 1CS019A/B valves o Spray Add Tank LO-2 lights NOT LIT or CNMT pressure > 15 psig o Go to step 8 Check RWST Level > 46%
Pzr Level > 28%
Note: By this point the crew should recognize 1A & 1D MSIV have closed and pressure is rising in the 1A & 1D SGs.
If the crew has NOT recognized 1A & 1D MSIV have closed and transitioned back to 1BwEP-2, the drill may be terminated at this point.
1BwEP-2 US Notifies SM of plant status and procedure entry o
Requests evaluation of Emergency Plan conditions Enter/Implement 1BwEP-2 and direct operator actions of 1BwEP-2 to establish the following conditions RO/
- Check MS isolation 2 MSIVs remain open CREW Check if any secondary pressure boundary intact Recognize 1A & 1D SG pressure are stable or rising.
RO/
BOP Identify Faulted SGs Recognize 1B & 1C SG pressures are lowering.
RO/
BOP Isolate the faulted SGs CLOSE 1AF013 B, C, F & G
Comments:
Braidwood NRC 13-2 Page 24 Scenario No:
NRC 13-2 Event No.
6, 8 Event
==
Description:==
Steam leak inside containment/uncontrolled depressurization of all SGs, Subsequent 1A and 1D MSIV closure Time Position Applicants Actions or Behavior Note: At this point the scenario may be terminated.
Final
Simulation Facility Braidwood Scenario No.:
NRC 13-3 Operating Test No.: 2013-1 Examiners:
Applicant:
SRO ATC BOP Initial Conditions:
IC-21 Turnover: Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. Online risk is yellow. 1A CW pump is OOS for impeller work. Expected back in service in one week. 1PR11J filter change planned early in shift. Rods are in manual due to rod control summing amplifier malfunction last shift.
Event No.
Malf. No.
Event Type*
Event Description Preload IOR ZDI1CW01PA PTL IRF ED051C OPEN IRF ED075C OPEN IMF ED06A IMF FW44 IMF FW48A IMF RX17 3.5 1A CW PP OOS 1CW001A OOS Breaker 1562 ABT failure 1B AF Pp Trip 1A AF Pp fails to auto start Rod control summing amp failure 1
None N-BOP TS-US 1PR11J filter change 2
IOR ZDI1WO01PA TRIP C-BOP, US TS-US 1A Containment Chilled Water Pump trip 3
IMF RX05 1500 30 IMF RX29C current value I-BOP, US Steam line pressure detector 1PT-507 fails high with 1C FRV controller failed as-is 4
IMF CV23A 80 180 C-ATC (or BOP),
US 1A letdown HX tube leak 5
IMF CV16 100 10 I-ATC, US VCT level channel 1LT-112 failure.
6 IMF RD02H08 R-ATC, US Emergency load drop of 200 MW/ Single Dropped Rod (H-8) 7 IMF RD02D04 M-All Multiple Dropped Rods (H-8 and D-4) 8 IMF TH03D 450 M-ALL 1D SGTR 9
Preload C-BOP 1A AF Pp auto start failure, 1B AF Pp trip
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
NRC 13-3 Page 2 of 31 SCENARIO OVERVIEW Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. RCS boron concentration is 805 ppm.
Online risk is yellow. 1A CW pump is OOS for impeller work. Expected back in service in one week.
1PR11J filter change planned early in shift. Rods are in manual due to rod control summing amplifier malfunction last shift.
After completing shift turnover and relief, a Radiation Protection Technician will contact the main control room and request the crew shutdown 1PR11J sample pump to support daily filter replacement. The Unit Supervisor will enter Tech Spec 3.4.15, condition B. Approximately two minutes later, the RP Technician will request restart of the 1PR11J skid. 1PR11J will be restarted. LCO 3.4.15 may be exited after filter change completion and monitor is operating normally for 90 minutes.
After changing the 1PR11J filter, the 1A Containment Chilled Water pump will trip, resulting in 1A Containment Chiller tripping. The crew will start the standby Chilled Water pump and Chiller per BwOP VP-1 after receiving a report that the 1A Chilled Water pump motor appears damaged. Containment pressure and temperature will slowly rise as a result of the loss of Containment Cooling. The US should reference LCO 3.6.4 and 3.6.5 and place priority to start the standby Chiller.
After the Containment Chilled Water malfunction has been addressed, steam line pressure detector 1PT-507 will fail high over a 30 second period. Simultaneously, the 1C feedwater regulating valve automatic controller output is failed as is. Both main feedwater pumps speed will rise, raising feedwater flow and causing all steam generator levels to begin rising. The crew will take actions to stabilize the plant by taking manual control of the main feedwater pumps and the 1C feedwater regulating valve. 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment J, will be implemented. 1PT-507 will remain unavailable for the remainder of the scenario.
After the steam line pressure detector failure has been addressed, the 1A letdown heat exchanger will develop a tube leak. Letdown flow and VCT level will lower and CC surge tank level and radiation will rise.
The crew will implement 1BwOA PRI-6, COMPONENT COOLING SYSTEM MALFUNCTION, and locate and isolate the leakage. The crew will align the 1B letdown heat exchanger in accordance with BwOP CV-22, OPERATION OF LETDOWN AND REGEN HEAT EXCHANGERS.
After the letdown heat exchanger failure is addressed, VCT level transmitter 1LT-112 will fail high, causing letdown to divert to the HUT. The RO will take manual control and close the letdown divert valve.
Tech Spec 3.3.9 does not apply in Mode 1. The instrument failure will prevent RMCS for operating in automatic mode. 1LT-112 will remain unavailable for the remainder of the scenario.
After the VCT level channel has been addressed, an emergency load reduction of 200 MW within 15 minutes is requested by TSO. After the crew has completed part of the load reduction, rod H-8 will drop into the core causing Tave to drop and reactor power to further drop. The crew will implement 1BwOA ROD-3, DROPPED OR MISALIGNED ROD. After the crew has made sufficient reactivity manipulation to stabilize plant conditions, either by adjusting Tave to within 3oF of Tref, or commencing a load reduction to reduce power to within the range allowable for the dropped rod recovery, a second rod (D-4) will drop into the core. The crew should identify that two rods have dropped into the core and trip the reactor. The crew will take immediate actions per 1BwEP-0, REACTOR TRIP OR SAFETY INJECTION and transition to 1BwEP ES-0.1, REACTOR TRIP RESPONSE.
NRC 13-3 Page 3 of 31 After the transitions to 1BwEP ES-0.1, the thermal hydraulic shock from the reactor trip results in a SGTR. When the main generator trips, an ABT failure of breaker 1562 results in the 1B RCP being de-energized. The crew will manually actuate safety injection and return to 1BwEP-0. The 1B AF pump will start and then trip. The 1A AF pump fails to auto-start. The crew will manually start the 1A AF pump.
The scenario is complete when the crew has terminated high head injection and established normal charging flow in 1BwEP-3.
Critical Tasks
- 1. Manually trip the reactor upon discovery of multiple dropped control rods prior to completion of step 4 in 1BwOA ROD-3 (if crew re-enters the procedure at step 1) upon second dropped rod, or upon verification that the DRPI indication for the second dropped rod is valid (per INPO SER 15-90 & SER 19-89) (K/A number - APE003A2.01 importance - 3.7/3.9)
- 2. Identify the 1D SG as the ruptured SG and isolate prior to a transition to 1BwCA-3.1 is required.
(ERG Critical Task number - E-3--A) (K/A number - EPE038EA1.32 importance 4.6/4.7)
- 3. Depressurize RCS to restore RCS inventory prior to 1D SG PORV or safety valve water release. (ERG Critical Task number - E-3--C) (K/A number EPE038EA1.09 importance 3.2/3.3)
- 4. Establish the minimum required AFW flowrate to the SGs before transition out of E-0 series. (ERG Critical Task number - E -F) (K/A number - 061000A2.05 importance - 3.1/3.4)
Comments:
NRC 13-3 Page 4 of 31 SIMULATOR SETUP GUIDE:
Verify/perform TQ-BR-201-0113, BRAIDWOOD TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.
Establish the conditions of IC-21, 100% power, BOL, steady state, equilibrium xenon.
Verify VA plenums A & C in service.
Verify RM-11 on Grid 1.
Complete items on Simulator Ready for Training Checklist.
Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.
Place simulator in RUN (allow simulator to run during board walk down and turnover).
Place ROD BANK SELECT switch to MAN Wait until 1CW001A valve is fully closed, THEN Run caep NRC 13-3 SETUP from disk and verify the following actuate:
IOR ZDI1CW01PA PTL IRF ED051C OPEN IRF ED075C OPEN IMF ED06A IMF FW44 IMF FW48A IMF Rx17 3.5 Place info tag on 1A CW pump C/S Provide students with turnover sheets and 1BwOS NR-1.
For Emergency Load drop of 200 Mw record the boration range on page 19 where blanks are designated, from the operator aid book and notify the examiners of the values or enter into their copies on page 20.
INSTRUCTOR/SIMULATOR RUN AID GUIDE Comments:
NRC 13-3 Page 5 of 31 Event 1: 1PR11J filter change As rad protection, contact the MCR by phone (X-2209) shortly after completion of shift turnover and request shutdown of 1PR11J to obtain sample (change of particulate and iodine filter cartridges. The rad protection procedure governing the filter change is RP-BR-911).
Two minutes after 1PR11J is shutdown, contact the MCR by phone and request startup of 1PR11J. If asked, report the bypass/normal switch on 1PS36J CASP panel is in bypass. Following start of 1PR11J, provide MCR feedback that 1PR11J is operating properly.
Acknowledge as SM LCO 3.4.15, condition B entry for 1PR11J.
Events 2: 1A Containment Chilled Water pump trip Insert IOR ZDI1WO01PA TRIP to trip the 1A Containment Chill Water pump.
After the 1A Chill Water pump is off, DELETE override DOR ZDI1WO01PA If dispatched as EO to investigate 1A Chilled Water pump breaker, wait 2 minutes and report the breaker tripped on overvcurrent.
If dispatched as EO to investigate 1A Chilled Water pump, wait 3 minutes and report the pump motor smells acrid and there is a haze above the motor (no fire). Cause of 1A Containment Chiller trip is EVAP LOW WATER FLOW.
If asked as EO report 1TIS-WO018 reads about 44oF.
As SM, acknowledge the trip of 1A Containment Chilled Water pump and Chiller, on line risk assessment, maintenance support, and IR initiation. When notified, direct the crew to start the 1B Chiller remotely from the MCR rather than locally (reasoning is to limit time frame to restore Containment cooling).
As EO, provide local operator actions for starting the 1B Containment Chilled Water Pump and Chiller (BwOP VP-1):
(step F.1) As EO, Oil Heater Breaker is on. If contacted as WEC supervisor, your are tracking 1B Chiller Oil Htr energization time.
(step F. 4) Pump suction pressure is 22 psig. WO Expansion Tank level is 55%.
(step F. 6) 1WO005B is throttled. 1FIS-WO027 indicates 3000 gpm.
(step F. 7) Chiller Oil level is 50% in sightglass.
(step F.8) Lamp test was satisfactory for all light bulbs.
(step F. 9) Chiller oil temperature is in band and Low Oil Temp alarm NOT lit locally.
(step F. 10) Electrical Demand Selector is in the 60% demand position.
(step F. 11) LCD on the purge control unit displays ADAPTIVE mode.
INSTRUCTOR/SIMULATOR RUN AID GUIDE Comments:
NRC 13-3 Page 6 of 31 (step F. 12) RESET pushbutton has been depressed for 2 seconds, no trip lights lit.
(step F.14) IF asked to start the Chiller locally, report that the Local/Remote transfer switch is physically stuck in the REMOTE position (the intent is for the MCR to start the chiller per step F.15).
(step F.15) Report that as EO you are standing by the 1B Containment Chiller ready for a remote start (START/STOP Switch is in STOP; Local/Remote switch is in REMOTE).
(step F. 16) The Program Timer Light at the Local Control Panel is lit.
Report that you will complete the local steps (F.17 - F.27)
Event 3: Steam line pressure detector 1PT-507 fails high with 1C FRV controller failed as-is.
- 1) Insert IMF RX29C for the current value for 1C FRV controller failed as is, then
- 2) Insert IMF RX05 1500 30 for 1PT-507 failed high.
If dispatched as EO to investigate 1PT-507, wait two minutes report no visible damage to 1PT-507.
Acknowledge as SM 1PT-507 failure, on line risk assessment, request for maintenance support, and IR requests.
Event 4: 1A letdown HX tube leak.
Insert IMF CV23A 80 180 to initiate a 80 gpm tube leak in the 1A letdown HX over a 3 minute period.
Acknowledge as Chemistry request to sample CC system for activity.
If dispatched as Equipment Operator to swap letdown heat exchangers in accordance with BwOP CV-22, report 1B letdown HX was previously filled and vented, then perform and report the following when directed by the crew:
MRF CC39 100 (open 1CC9452C, 1B letdown HX CC inlet isolation valve).
Verify RF CC43 50 (throttle 1CC9452D, 1B letdown HX CC outlet isolation valve).
Verify RF CV64 100 (open 1CV8467B, 1B letdown HX outlet isolation valve).
MRF CC37 0 (close 1CC9452A, 1A letdown HX CC inlet isolation valve).
MRF CC40 0 (close 1CC9452B, 1A letdown HX CC outlet isolation valve).
MRF CV63 0 (close 1CV8467A, 1A letdown HX outlet isolation valve).
If dispatched as Equipment Operator to drain the CC surge tank, run caep DRAINCCSurge from disk and verify the following actuate:
INSTRUCTOR/SIMULATOR RUN AID GUIDE Comments:
NRC 13-3 Page 7 of 31 IRF CC15 100 IRF CC16 100 trgset 29 "CCLSRGTNKP(1) < 56" trg 29 "MRF CC15 0" trgset 30 "CCLSRGTNKP(1) < 56" trg 30 "MRF CC16 0" Acknowledge as Chemistry request to sample letdown for placing letdown mixed bed demin back on line.
Acknowledge as Shift Manager the failures, request for maintenance support, and IR request.
Event 5: VCT level channel 1LT-112 failure.
Insert IMF CV16 100 10 to fail VCT level transmitter 1LT-112 high over a 10 second period.
If dispatched as EO to investigate 1LT-112, wait 2 minutes and report no visible damage to 1LT-112.
As SM, acknowledge failure of 1LT-112, dequip entry, and requests for on line risk assessment, maintenance support, and IR initiation.
Event 6: Emergency load drop of 200 MW/Single Dropped Rod (H-8).
Emergency Load Drop: Contact Unit 1 on the TSO phone as Bill Collins and direct Unit 1 to complete an emergency load reduction of 200 MW within 15 minutes due to an overload condition on grid transmission lines. Inform Unit 1 that Unit 2 has been contacted and Unit 2 is also initiating a 200 MW load drop in response to the grid emergency.
As Nuclear Engineer, inform examinees Beacon Prediction is available for Emergency Offsite Line Drop Ramp in Operator Aid Book. Examinees are to use Beacon Prediction for load drop.
Acknowledge as Shift Manager initiation of load reduction.
Acknowledge as chemistry/rad protection requests for RCS samples (if required).
Acknowledge as Power Team initiation of ramp.
NOTE: When contacted as SM or POWER Team after the H-8 rod drops concerning the necessity for Braidwood Unit 1 to continue ramping down, let the crew know that the other plant load reductions and the load reduction that Unit 1 already completed, have sufficiently stabilized the grid.
Single Dropped Rod (H-8): At the completion of the load ramp, insert the following 10 seconds later:
Insert IMF RD02H08 to cause rod H8 to drop into the core.
INSTRUCTOR/SIMULATOR RUN AID GUIDE Comments:
NRC 13-3 Page 8 of 31 As SM, acknowledge entry into 1BwOA ROD-3, requests for on line risk assessment, notification of Station Duty Manager, Station Duty Officer, Nuclear Duty Officer, Work Week Manager, and IR initiation As Reactor Engineering acknowledge receipt of Attachment A information.
As SM offer that an extra NSO will perform 1BwOSR 3.1.1.1-2, SHUTDOWN MARGIN SURVEILLANCE DURING OPERATION if asked.
When notified of need to ramp to less than 70% power, as QNE or SM the QNE has recommended use of the Operator Aid for a 350 Mwe Load Swing for the ramp.
As SM, acknowledge entry into 1BwOA ROD-3, requests for on line risk assessment, notification of Station Duty Manager, Station Duty Officer, Nuclear Duty Officer, Work Week Manager, and IR initiation.
If contacted as TSO about continued need for load drop, provide one of the following conditional responses:
o If the crew has stabilized Tave matched to Tref, inform them that load reductions from other units plus Braidwood Unit 1 have stabilized the grid.
o If Tave is low/not matched to Tref, inform them that the emergency/additional load reduction is still necessary.
Event 7: Multiple Dropped Rods.
NOTE: Prior to initiating this event, ensure the lead examiner is satisfied with the amount of reactivity change that the crew has performed in order to satisfactorily evaluate the ATC.
Ten minutes after initiation of ramp insert the following:
IMF RD02D04 Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
After STA requested, as STA report CSF status.
Event 8: 1D SGTR When the crew enters 1BwEP ES-0.1, initiate IMF TH03D 450 to initiate a 450 gpm tube rupture in the 1D SG.
Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
Bus 156 status: no breaker targets are present.
1B AF pump: tripped on overcrank.
Comments:
NRC 13-3 Page 9 of 31 Scenario No:
NRC 13-3 Event No.
1 Event
==
Description:==
1PR11J filter change Time Position Applicants Actions or Behavior CUE
- Request from RP to shutdown 1PR11J for filter change BOP Refer to BwOP AR/PR-19, ROUTINE SKID MOUNTED PROCESS RADIATION MONITOR OPERATIONS Notify US of 1PR11J filter change request.
To Secure 1PR11J:
Select Grid 2 on RM-11 Select 1PR11J Depress flow button to secure 1PR11J.
US Recognize entry conditions for TS LCO 3.4.15, condition B.
o Inform SM of TS 3.4.15 entry CUE
- Request from RP to startup 1PR11J following filter change BOP Refer to BwOP AR/PR-19 To Start 1PR11J:
Select Grid 2 on RM-11 Select 1PR11J Depress flow button to start 1PR11J Verify flow indicated on 1PR11J Notify US of completion of 1PR11J filter change US o Inform SM of TS 3.4.15 exit 90 minutes after 1PR11J is restarted and no associated alarms have occurred.
NOTE: After the actions for 1PR11J are complete and with lead examiner concurrence, enter next event.
Comments:
NRC 13-3 Page 10 of 31 Scenario No:
NRC 13-3 Event No.
2 Event
==
Description:==
1A Containment Chill Water pump trip Time Position Applicants Actions or Behavior CUE Annunciator CNMT CHLR UNIT TROUBLE (0-33-D3) 1A Containment Chiller trip light-LIT 1A Chilled Water pump trip light - LIT US Direct BOP to respond to Annunciator 0-33-D3 Direct BOP to start 1B Containment Chilled Water Pump and Chiller o Evaluate Containment conditions against LCO 3.6.4 and 3.6.5 BOP Determine 1A Chiller and Chilled Water pump tripped Reference BwARs o Place 1A Chilled Water Pump C/S in PTL Start 1B Containment Chilled Water Pump and Chiller per BwOP VP-1 BOP BwOP VP-1 Actions:
Directs EO to locally energize oil heaters and notifies WEC to track energization time of heaters-verify heaters energized for 1B VP chiller.
Verifies OPEN:
1SX112B, Cnmt Chillers SX Inlet Vlv 1SX114B, Cnmt Chillers SX Return Vlv 1SX147B, Cnmt Chillers SX Bypass Vlv 1SX016B, RCFC SX Supply Vlv 1SX027B, RCFC SX Return Vlv Verifies OPEN:
1WO006B, RCFC Chill Wtr Inlet Cnmt Isol Vlv 1WO020B, RCFC Chill Wtr Outlet Cnmt Isol Vlv 1WO56B, RCFC Chill Wtr Outlet Cnmt Isol Vlv Directs local EO to perform steps F.4 (verify Pump suction pressure and Expansion Tank level)
Start 1WO01PB, Chilled Water Pump Directs EO to locally complete BwOP VP-1 steps F.6 - F.12 Verify/place 1B Byp Isol Vlv 1SX147B in AUTO at 0PM02J Start the 1B Containment Chiller from the MCR:
Has EO locally verify START/STOP switch in STOP and Local/Remote switch in Remote and is prepared to record initial data locally Place 1WO01CB, Chiller B Control Switch, at 0PM02J to AFTER CLOSE.
Directs EO to locally complete steps F.16 to F.27 EVALUATOR NOTE: After the actions for the Containment Chiller trip are complete and with lead examiners concurrence, insert the next event.
Comments:
NRC 13-3 Page 11 of 31 Scenario No:
NRC 13-3 Event No.
3 Event
==
Description:==
Steam line pressure detector 1PT-507 fails high with 1C FRV controller failed as-is.
Time Position Applicants Actions or Behavior CUE Annunciator 1-15-C3 S/G 1C FLOW MISMATCH STM FLOW LOW.
Annunciators S/G 1A/B/C/D LEVEL DEVIATION HIGH/LOW (1-15-A9/B9/C9/D9).
BOTH main feedwater pump speed/flow - RISING.
1PI-507, S/G HDR PRESS, - RISING.
1PI-509 MS/FW HDR DP PRESS - LOWERING.
1C FRV position not changing/1C feed flow significantly lower than other 3 SGs.
CREW
- Refer to BwARs
- Determine 1PT-507 failing high at 1PM04J.
- Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.
o Dispatch operators to investigate 1PT-507 failure.
US
- Notify SM of plant status and procedure entry
- Request evaluation of Emergency Plan conditions
- Implement 1BwOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment J "FW PUMP SPEED CONTROL MALFUNCTION" and direct operator actions of 1BwOA INST-2 to establish the following conditions.
BOP Perform the following at 1PM04J:
- Lower demand on 1SK-509A.
o Aligns/verify steam dumps in Tave mode.
- Place 1FK530 in manual
- Lower 1FK530 demand to maintain 1C SG level.
o Place 1FK530D in automatic to allow the 1FW530A to automatically maintain 1C SG level (if directed by US)
ATC/B OP
- Check Rx power < 100%
o Initiate 5 Mwe load reduction at 5 Mwe/min.
ATC Perform the following at 1PM05J:
Monitor reactor power response to SG under and overfeeding transient.
US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
o If PZR pressure dropped below 2209 psig during transient, LCO 3.4.1 applies.
o Direct BOP to place 1C FRBV (1FW530A) in service in automatic to automatically maintain 1C SG level (per 1BwGP 100 -3 E.5.h)
EVALUATOR NOTE: After the actions for the 1PT-507 failure are complete and with lead examiners concurrence, insert the next event.
Comments:
NRC 13-3 Page 12 of 31 Scenario No:
NRC 13-3 Event No.
4 Event
==
Description:==
1A letdown HX tube leak.
Time Position Applicants Actions or Behavior CUE Annunciator 1-2-A5, CC SURGE TANK LEVEL HIGH/LOW 0/1PR09J, CC HX OUTLET RAD MONITOR, alarming at the RM-11 console.
Letdown flow lowering on 1FI-132 at 1PM05J.
CC surge tank level rising on 1LI-670 & 1LI-676 at 1PM06J.
1CC017, CC surge tank vent valve, CLOSED at 1PM06J.
CREW Reference BwARs.
Identify entry conditions for 1BwOA PRI-6, COMPONENT COOLING MALFUNCTION.
US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Evaluates applicability of LCO 3.4.13 Condition A.
Implement 1BwOA PRI-6, COMPONENT COOLING MALFUNCTION, and direct operator actions of 1BwOA PRI-6:
NOTE: Another procedure based option is for the crew to enter 1BwOA PRI-1, EXCESSIVE PRIMARY PLANT LEAKAGE. The actions for this procedure are in italics.
BOP Check CC surge tank level at 1PM06J:
CC surge tank level > 13% and rising on 1LI-670 & 1LI-676.
US Determine 1BwOA PRI-6, Attachment B, ABNORMAL CC SURGE TANK LEVEL, needs to be implemented.
BOP Check CC surge tank level at 1PM06J:
CC surge tank level > 13% and rising on 1LI-670 & 1LI-676.
o Dispatch operators to drain CC surge tank.
CREW Check for leakage from RCP thermal barrier at 1PM05J:
Annunciator 1-7-E4, RCP THERM BARR CC WTR FLOW HIGH/LOW - NOT LIT.
Seal injection flows stable on 1FI-142A - 1FI-145A.
CREW Isolate CC system inleakage:
0/1PR09J, CC HX OUTLET RAD MONITOR, radiation level rising and/or alarming at the RM-11 console.
Notify chemistry to sample CC system.
Determine leak exists in letdown heat exchanger.
Letdown flow lowering on 1FI-132 at 1PM05J.
Comments:
NRC 13-3 Page 13 of 31 Scenario No:
NRC 13-3 Event No.
4 Event
==
Description:==
1A letdown HX tube leak.
Time Position Applicants Actions or Behavior VCT level lowering on 1LR-185 at 1PM05J.
o Place 1CV-112A, letdown to VCT or HUT divert valve, in the HUT position to divert letdown to the HUT.
ATC o Isolate normal CV letdown at 1PM05J:
o Close 1CV8149A, B, & C, letdown orifice isolation valves.
o Close 1CV459 & 1CV460, letdown line isolation valves.
o Close 1CV8152 & 1CV8160, letdown line CNMT isolation valves.
o Place 1FK-121, CV pumps flow control valve, in manual and lower demand on 1FK-121 while concurrently adjusting 1CV182, charging header backpressure control valve, to control RCP seal injection 8-13 gpm per RCP.
o Close 1CV8105 & 1CV8106, charging line CNMT isolation valves.
Monitor RMCS during manual VCT makeup:
Proper flow indicated on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110).
EVALUATOR NOTE: The crew may elect to place excess letdown on line. The steps for placing excess letdown on line are on page 17.
US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Implement 1BwOA PRI-1, EXCESSIVE PRIMARY PLANT LEAKAGE, and direct operator actions of 1BwOA PRI-1:
ATC/
BOP Check SI status Check if SI required:
o PZR press < 1829 psig-not met o
Steamline press < 640 psig-not met o
CNMT press > 3.4 psig-not met PZR level: Stable or rising-lowering Isolate letdown:
Verify/close 1CV8149A, B, & C, letdown orifice isolation valves Crew Check unit in Mode 1 Check PZR pressure-not less than 2220 psig Monitor PZR level-rising Check if leak is downstream of seal injection line flow transmitter-no individual seal injection flow Check letdown isolated-isolated previously-step also verifies closed 1CV459 and 1CV460 which previous step did not BOP Close 1CV459 and 1CV460 NOTE: A NOTE ALLOWS TRANSITION TO STEP 30 (CHECK NORMAL CHARGING FLOWPATH ESTABLISHED) WITH SHIFT MANAGER PERMISSION IF LEAK IS IDENTIFIED AND VERIFIED ISOLATED.
ATC/
Verify leak is not in charging header downstream of 1CV121:
Comments:
NRC 13-3 Page 14 of 31 Scenario No:
NRC 13-3 Event No.
4 Event
==
Description:==
1A letdown HX tube leak.
Time Position Applicants Actions or Behavior BOP Close 1CV8324A Establish seal injection between 10 and 15 gpm per pump Maintain 1CV182 at least 20% open Check charging flow-approximately equals total seal injection flow ATC/
BOP Check if Leak isolated:
PZR level-rising PZR level rise - approximately equals charging flow minus seal return Check if Leak was in Containment:
No abnormal Containment leakage or radiation indications Check if Leak is in Cent Chg pump room:
Grid 2 Cent Chg pump Cubicle rad monitors-less than ALERT setpoint Check if Leak is in Aux Building or Curved Wall area:
No Grid 2, Grid 3, or Grid 4 Aux Building rad alarms Check if SG tubes are intact:
PPC and RM-11 secondary trends and indications-normal Check Reactor Vessel Flange Leakoff:
Alarm 1-14-E5 RX VESSEL FLNG LEAKOF TEMP HIGH-not lit Check PRT conditions-Temp/Press/Level-normal Check Containment conditions-no leakage indicated Monitor VCT level Verify adequate makeup-auto makeup NOT available-maintain manual makeup Check normal charging flow path established-open 1CV8324A Control charging flow using 1CV121 and 1CV182 to maintain PZR level within 5% of program and 8-13 gpm seal injection per pump Control PZR pressure: Operate PZR heaters and sprays as necessary Check Letdown status: none established CREW
- Swap letdown heat exchangers in accordance with BwOP CV-22, OPERATION OF LETDOWN & REGEN HEAT EXCHANGERS:
- Contact operators to locally align and vent 1B letdown HX.
- Open 1CV8401B, letdown HX 1B inlet valve, at 1PM05J.
- Close 1CV8401A, letdown HX 1A inlet valve at 1PM05J.
o 1CC9452B, letdown HX 1A CC outlet isolation valve.
o Contact operators to locally close 1CV8467A.
ATC/
BOP o Perform the following at 1PM05J to establish normal letdown flow through the 1B letdown heat exchanger in accordance with BwOP CV-17, ESTABLISHING AND SECURING NORMAL AND RH LETDOWN FLOW: (N/A if excess letdown established)
Verify/close 1CV8149A, B, & C, letdown orifice isolation valves.
Comments:
NRC 13-3 Page 15 of 31 Scenario No:
NRC 13-3 Event No.
4 Event
==
Description:==
1A letdown HX tube leak.
Time Position Applicants Actions or Behavior o Contact operators to locally verity CC locally aligned to 1B letdown HX.
Place 1PK-131, letdown line pressure controller, in manual and raise demand to 40%.
Place 1CC-130A, letdown HX outlet temperature controller, in manual and raise demand to 60%.
Open 1CV459 & 1CV460, letdown line isolation valves.
Open 1CV8324A, charging to regen HX 1A isolation valve.
Open 1CV8389A, letdown to regen HX 1A isolation valve.
Open 1CV8152 & 1CV8160, letdown line CNMT isolation valves.
Verify OFF light is lit above BTRS mode selector C/S.
Verify/open 1CV8401B, letdown HX 1B inlet valve.
Verify/closed 1CV8147, PZR aux spray valve.
Verify/open 1CV8145, charging to loop 1A isolation valve.
Open 1CV8105 & 1CV8106, charging line CNMT isolation valves.
Control 1FK-121, CV pumps flow control valve, in manual to raise letdown flow to 100 gpm while concurrently adjusting 1CV182, charging header backpressure control valve, to control RCP seal injection 8-13 gpm per RCP.
Open 1CV8149A/B/C, letdown orifice isolation valves, as necessary to establish desired letdown flow while concurrently and controlling 1PK-131, letdown line pressure controller, in manual to maintain letdown pressure 360-380 psig.
Control 1CC130A, letdown HX outlet temperature controller, in manual to maintain letdown temperature 90-115°F.
Place 1FK-121, 1PK-131 & 1CC130A in auto.
Verify 1PR06J in service at the RM-11 console.
BOP ACTIONS TO ESTABLISH EXCESS LETDOWN o Perform the following at 1PM05J to establish excess letdown flow in accordance with BwOP CV-15, EXCESS LETDOWN OPERATIONS: (N/A if normal letdown established)
Verify/open 1CV8100 & 1CV8112, seal water return CNMT isolation valves, at 1PM05J.
Open 1CC9437A & 1CC9437B, CC to excess letdown HX isolation valves, at 1PM06J.
Verify/close (at 0% demand) 1HCV-CV123, excess letdown HX flow control valve, at 1PM05J.
Verify/place in VCT position 1CV8143, excess letdown to seal filter or RCDT valve, at 1PM05J.
Open 1RC8037A, B, C, & D, RCS loop drain valves, at 1PM05J.
Open 1CV8153A & 1CV8153B, excess letdown HX 1A & 1B inlet isolation valves, at 1PM05J.
Raise demand on 1HCV-CV123, excess letdown HX flow control valve, while
Comments:
NRC 13-3 Page 16 of 31 Scenario No:
NRC 13-3 Event No.
4 Event
==
Description:==
1A letdown HX tube leak.
Time Position Applicants Actions or Behavior maintaining excess letdown outlet temperature < 165°F on 1TI-122A at 1PM05J.
US Inform SM/Maint of 1A letdown HX leak, IR, EAL evaluation, and contact maintenance to investigate/correct letdown HX leak.
o Evaluate Tech Spec 3.4.13 for applicability.
EVALUATOR NOTE: After the actions for letdown heat exchanger leak are complete and with lead examiners concurrence, enter next event.
Comments:
NRC 13-3 Page 17 of 31 Scenario No:
NRC 13-3 Event No.
5 Event
==
Description:==
VCT level channel 1LT-112 failure Time Position Applicants Actions or Behavior CUE Annunciator VCT LEVEL HIGH-HIGH LOW (1-9-A2)
VCT level indicator 1LI-112 rising at 1PM05J.
1CV112A, Letdown to VCT or HUT Divert Valve - HUT light lit at 1PM05J.
VCT level recorder 1LT-0185 indication lowering at 1PM05J.
ATC/
BOP Determine 1LT-112 has failed high.
Reference BwAR.
o Dispatch operators to investigate 1LT-112.
US Notify SM of plant status.
ATC Take manual control of VCT level at 1PM05J:
o Place 1CV112A in manual and lower demand to close 1CV112A.
o Place 1CV112A control switch in VCT.
o Determine RMCS auto makeup - NOT AVAILABLE.
o May restore VCT level in manual per BwOP CV -7.
US o Determines TS 3.3.9 is NOT applicable.
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
EVALUATOR NOTE: After the actions for the VCT level channel malfunction are complete and with lead examiners concurrence, insert the next event.
Comments:
NRC 13-3 Page 18 of 31 Scenario No:
NRC 13-3 Event No.
6 Event
==
Description:==
Emergency Load drop of 200 MW/Single Dropped Rod (H-8)
Time Position Applicants Actions or Behavior CUE Call from TSO to perform emergency load drop of 200 MW.
US Acknowledge request to lower power 200 MW.
o Perform abbreviated pre-job brief per HU-AA-1211 PRE-JOB, HEIGHTENED LEVEL OF AWARENESS, INFREQUENT PLANT ACTIVITY, AND POST JOB BRIEFINGS for load ramp.
CREW Review applicable Precautions, and Limitations and Actions of 1BwGP 100-4.
o Address monitoring/resetting 1AR011(12)J setpoints or enter 0BwOL TRM 3.3.p o Notification for sampling 2-6 hours following power change of 15% or greater per SR 3.4.16.2 EVALUATOR NOTE: The following step may be repeated as necessary to borate the RCS during the power descension. Examinees may use hard cards for borations.
ATC Verify rod position and boron concentration.
Initiate boration, if required. (BwOP CV-6) (PER Op Aid ___ to ___ gal).
Determine required boric acid volume.
o Perform boration boundary calculation per 1BwGP 100-4T2.
o Refer to operator aid for ramp.
Determine desired boric acid flow rate.
Perform the following at 1PM05J:
- Set 1FK-110 BA Flow Control to desired boration rate.
- Set 1FY-0110 BA Blender Predet Counter to desired volume.
- Place MAKE-UP MODE CONT SWITCH to STOP position.
- Place MODE SELECT SWITCH to BORATE position.
- Place MAKE-UP MODE CONT SWITCH to START.
- Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION.
OR ATC Batch addition of Boric Acid:
- Open 1CV110B.
- Open 1CV110A.
- Start the BA Transfer pump.
- When desired amount of BA has been added, stop the BA Transfer Pump.
Comments:
NRC 13-3 Page 19 of 31 Scenario No:
NRC 13-3 Event No.
6 Event
==
Description:==
Emergency Load drop of 200 MW/Single Dropped Rod (H-8)
Time Position Applicants Actions or Behavior
- Close 1CV110A.
- Close 1CV110B.
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION.
BOP Lower turbine load at 1PM02J or OWS drop 210 by performing the following:
- Select SETPOINT.
- Enter desired MW into REF DEMAND window.
- Select ENTER.
- Enter desired MW/min into the RATE window.
- Select ENTER.
- Select EXIT.
o Notify US and ATC of pending ramp.
- Select GO/HOLD.
- Verify GO/HOLD button illuminates.
- Verify HOLD illuminated RED.
- Select GO.
- Verify GO illuminates RED.
Verify main turbine load begins to lower.
ATC/
BOP Monitor reactor power and turbine load lowering:
Monitor NIs, Tave, I, Pzr press/level at 1PM05J.
Monitor MWe and DEHC system response at 1PM02J or OWS drop 210.
During boration, monitor the following at 1PM05J and PPC:
o Monitor VCT level.
o Monitor BA predet counter.
o Verify boration auto stops at preset value.
o Return Reactor Makeup System to manual at current boron concentration.
EVALUATOR NOTE: After measurable change in power and with lead examiner approval, initiate the dropped rod (H-8), preferably during rod motion.
Comments:
NRC 13-3 Page 20 of 31 Scenario No:
NRC 13-3 Event No.
6 Event
Description:
Emergency Load drop of 200 MW/Single Dropped Rod (H-8)
Time Position Applicants Actions or Behavior CUE Tave dropping PZR pressure dropping Rod Bottom light for rod H-8 LIT Annunciator ROD AT BOTTOM (1-10-E6)
Annunciator TAVE CONT DEV LOW (1-14-E1)
ATC Determine Rod H-8 has dropped Reference BwARs US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Implement 1BwOA ROD-3, DROPPED OR MISALIGNED ROD, and direct operator actions of 1BwOA ROD-3.
CREW
- Stop Reactivity Changes:
- Rods in Manual (already in manual)
- Stop unnecessary turbine load changes
- Stop unnecessary boration or dilution ATC/BOP
- As directed by US:
- Check DRPI not failed:
- ROD CONTROL URGENT FAILURE alarm (1-10-C6) - NOT LIT
- ROD CONTROL NON-URGENT FAILURE alarm (1-10-D6) - NOT LIT
- URGENT ALARM light (s) on DRPI panel - NOT LIT
- Check Reactor power: Greater than 5%
- Power - Less than 100%
- Check for dropped rod:
DRPI Rod Bottom Light LIT Tave dropping
- Stabilize RCS Temperature:
- Check Tave greater than 550oF
- Maintain Tave - Tref deviation - within 3oF: Crew may adjust turbine load or dilute to restore Tave to within 3oF of Tref.
NOTE: If Examiner is satisfied with the magnitude of reactivity manipulation the crew performs to adjust Tave at this point, then at examiners option, continue with the next event in the scenario. Otherwise the crew will initiate a ramp to reduce power below 70% at step 11 of 1BwOA ROD-3.
US
- Direct ATC/BOP to perform actions listed:
- Check DRPI not failed:
Comments:
NRC 13-3 Page 21 of 31 Scenario No:
NRC 13-3 Event No.
6 Event
Description:
Emergency Load drop of 200 MW/Single Dropped Rod (H-8)
Time Position Applicants Actions or Behavior
- ROD CONTROL URGENT FAILURE alarm (1-10-C6) - NOT LIT
- ROD CONTROL NON-URGENT FAILURE alarm (1-10-D6) - NOT LIT
- URGENT ALARM light (s) on DRPI panel - NOT LIT
- Check Reactor power: Greater than 5%
- Power - Less than 100%
- Check for dropped rod:
DRPI Rod Bottom Light LIT Tave dropping
- Stabilize RCS Temperature:
- Check Tave greater than 550oF
- Maintain Tave - Tref deviation - within 3oF: Crew may adjust turbine load or dilute to restore Tave to within 3oF of Tref.
- Notify the Shift Manager to perform risk evaluation, notify appropriate personnel (Station Duty Manager, Station Duty Officer, Nuclear Duty Officer, Work Week Manager) and initiate IR.
- Check Flux Rate Trip Alarm 1-10-C3 PWR RNG FLUX RATE RX TRIP ALERT -
NOT LIT
- RECORD DATA ON ATTACHMENT A:
- Check Core Power Distribution:
PDMS INOPERABLE (1-10-E8) NOT LIT 1BwOS PDMS-1a, AAR POWER DISTRIBUTION MONIORING SYSTEM NOT IMPLEMENTED PDMS LIMIT EXCEEDED (1-10-D7) NOT LIT
- Refer to Tech Specs: Identify LCO 3.1.4 Condition B applies (action B.2 does NOT apply) and 3.4.1 Condition A.
- Verify Reactor Power Proper for Rod Recovery Check if DRPI indicates affected rod MISALIGNED GREATER THAN 12 STEPS Perform 1BwOSR 3.1.1.1-2, SHUTDOWN MARGIN SURVEILLANCE DURING OPERATION-WITHIN 1 HOUR CHECK Reactor Power-Less than 70%-NO Directs crew to initiate ramp to less than 70%
ATC/BOP As directed by US:
- Check Flux Rate Trip Alarm 1-10-C3 PWR RNG FLUX RATE RX TRIP ALERT -
NOT LIT
- Check Core Power Distribution:
PDMS INOPERABLE (1-10-E8) NOT LIT 1BwOS PDMS-1a, AAR POWER DISTRIBUTION MONIORING SYSTEM NOT IMPLEMENTED PDMS LIMIT EXCEEDED (1-10-D7) NOT LIT
- Verify Reactor Power Proper for Rod Recovery Check if DRPI indicates affected rod MISALIGNED GREATER THAN 12 STEPS Perform 1BwOSR 3.1.1.1-2, SHUTDOWN MARGIN SURVEILLANCE DURING
Comments:
NRC 13-3 Page 22 of 31 Scenario No:
NRC 13-3 Event No.
6 Event
Description:
Emergency Load drop of 200 MW/Single Dropped Rod (H-8)
Time Position Applicants Actions or Behavior OPERATION-WITHIN 1 HOUR CHECK Reactor Power-Less than 70%-NO Initiate ramp to less than 70% power When the examiner is satisfied with the reactivity change, continue with the next event.
Comments:
NRC 13-3 Page 23 of 31 Scenario No:
NRC 13-3 Event No.
7 Event
==
Description:==
Multiple Dropped Rods (H-8 and D-4)
Time Position Applicants Actions or Behavior CUE Annunciator 1-10-C4, PWR RNG CHANNEL DEV DRPI Rod at Bottom lights for rod H-8 and D-4 LIT ATC Identify/report multiple alarms with indications of dropped rods CREW Identify conditions requiring reactor trip US/AT C
[CT]
Direct/Initiate a manual reactor trip and transition to 1BwEP-0 US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BwEP-0 and direct operator actions of 1BwEP-0 ATC Perform immediate operator actions of 1BwEP-0:
Verify reactor trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux - DROPPING BOP Perform immediate operator actions of 1BwEP-0 at 1PM02J or Operator Work Station drop 210 (DEH computer terminal located behind Unit 1 desk):
Verify Turbine Trip.
All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED BOP Perform immediate operator actions of 1BwEP-0 at 1PM01J:
Verify power to 4KV busses ESF Buses - BOTH ENERGIZED (141 & 142)
NOTE: BUS 156 ABT failure following the reactor trip will cause a loss of the 1B RCP.
CREW Perform immediate operator actions of 1BwEP-0 at 1PM04J, 1PM05J, & 1PM06J:
Check if SI actuated at 1PM05J and 1PM06J:
Any SI first out Annunciator - NONE LIT.
SI ACTUATED Bypass Permissive - NOT LIT.
SI equipment automatically actuated:
1A or 1B SI pump - NOT RUNNING.
1SI8801A or B, CV pump cold leg injection valve - CLOSED.
Comments:
NRC 13-3 Page 24 of 31 Scenario No:
NRC 13-3 Event No.
7 Event
==
Description:==
Multiple Dropped Rods (H-8 and D-4)
Check if SI required:
PZR pressure > 1829 psig.
Steamline pressure > 640 psig.
Containment pressure < 3.4 psig.
Determine SI not required.
CREW Transition to 1BwEP ES-0.1
Comments:
NRC 13-3 Page 25 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip Time Position Applicants Actions or Behavior CUE RM-11 Secondary rad monitor alarms/levels rising o SJAE/GLAND STEAM EXHAUSTER HIGH - 1PR027J o MAIN STEAM LINE RAD HIGH - 1AR022J/23J o PZR level dropping o PZR pressure dropping o Charging/letdown mismatch US Per OAS of 1BwEP ES-0.1 orders manual SI and return to 1BwEP-0 step 1 based on o RCS subcooling not acceptable, or o PZR level cannot be maintained > 4%
NOTE: The crew may identify the failure of AFW to start on LO-2 SG level at this point and attempt to start manually start AFW pumps now.
CREW Identify entry conditions for 1BwEP-0, REACTOR TRIP OR SAFETY INJECTION.
ATC Manually actuate SI as directed US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Enter/Implement 1BwEP-0 and direct operator actions of 1BwEP-0 to establish the following conditions:
ATC Perform immediate operator actions of 1BwEP-0 at 1PM05J:
Verify reactor trip:
- Rod bottom lights - ALL LIT.
- Reactor trip & Bypass breakers - OPEN.
- Neutron flux - DROPPING.
BOP Perform immediate operator actions of 1BwEP-0 at 1PM02J:
Verify Turbine Trip:
- All Turbine throttle valves -CLOSED.
- All Turbine governor valves -CLOSED.
BOP Perform immediate operator actions of 1BwEP-0 at 1PM01J:
Verify power to 4KV busses:
- ESF bus 141 - ENERGIZED.
SI First OUT annunciator - LIT.
Comments:
NRC 13-3 Page 26 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip SI ACTUATED Permissive Light - LIT.
SI Equipment - AUTOMATICALLY ACTUATED Manually actuate SI at 1PM05J & 1PM06J.
EVALUATOR NOTE: US and RO will continue in 1BwEP-0 while BOP is performing Attachment B:
BOP 1BwEP-0 ATTACHMENT B Verify FW isolated at 1PM04J FW pumps - TRIPPED.
Isolation monitor lights - LIT.
FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.
Verify DGs running at 1PM01J:
DGs - BOTH RUNNING.
1SX169A/B OPEN.
Dispatch operator locally to check operation Verify Generator Trip at 1PM01J:
OCB 1-8 and 7-8 open.
PMG output breaker open.
Verify Control Room ventilation aligned for emergency operations at 0PM02J:
VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.
Operating VC train equipment - RUNNING.
0B Supply fan 0B Return fan 0B M/U fan 0B Chilled water pump 0B Chiller Operating VC train dampers - ALIGNED.
M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.
0B VC train M/U filter light - LIT.
0VC09Y - OPEN 0VC313Y - CLOSED Operating VC train Charcoal Absorber aligned for train B.
0VC44Y - CLOSED 0VC05Y - OPEN 0VC06Y - OPEN Control Room pressure greater than +0.125 inches water on 0PDI-VC038.
Verify Auxiliary Building ventilation aligned at 0PM02J:
Two inaccessible filter plenums aligned.
Plenum A:
0VA03CB - RUNNING 0VA023Y - OPEN 0VA436Y - CLOSED
Comments:
NRC 13-3 Page 27 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip Plenum C:
0VA03CF - RUNNING 0VA072Y - OPEN 0VA438Y - CLOSED Verify FHB ventilation aligned at 0PM02J:
0VA04CB - RUNNING 0VA055Y - OPEN 0VA062Y - OPEN 0VA435Y - CLOSED Trip all running HD pumps.
Initiate monitoring of SFP cooling.
Notify US Attachment B complete ATC /
BOP Verify ECCS pumps running at 1PM05J/1PM06J:
BOTH CV pumps - RUNNING.
BOTH RH pumps - RUNNING.
BOTH SI pumps - RUNNING.
ATC /
BOP Perform the following at 1PM06J:
RCFCs running in accident mode RCFC accident mode status light lit CNMT Phase A valves closed ATC /
[CT]
E-0-F Perform the following at 1PM06J:
Verify Cnmt Vent isolation:
Group 6 Cnmt Vent Isol monitor lights - LIT.
Verify AF system:
AF pumps - NEITHER RUNNING.
Manually Start 1A AF pump. (may have been performed earlier)
AF isolation valves - 1AF13A-H OPEN.
AF flow control valves - 1AF005A-D are throttled OPEN. 1AF005E-H are OPEN (no flow).
Verify CC pumps running:
Both CC pumps - RUNNING Verify SX pumps running:
BOTH SX pumps - RUNNING.
ATC /
BOP Check if Main Steamline Isolation required:
o S/G pressures > 640 psig at 1PM04J.
o CNMT pressure < 8.2 psig at 1PM06J.
ATC /
CNMT pressure remained < 20 psig.
Comments:
NRC 13-3 Page 28 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip ATC /
AF flow > 500 gpm o If 1D SG level > 10% and tube rupture is recognized then:
o CLOSE 1AF013D o CLOSE 1AF013H NOTE: The crew may also isolate the 1B SG AF lines by closing 1AF013B and F.
Level will be rising in this SG due to the loss of power to the 1B RCP from ABT failure of breaker 1562. Eventually, the crew should recognize that this SG is not ruptured (once they have throttled AF flow to it and the SG level stops rising)
ATC /
BOP Verify ECCS valves aligned Group 2 cold leg injection monitor lights lit.
Verify ECCS FLOW
> 100 gpm on indicator 1FI-917 ATC Check PZR PORVs and SPRAYs:
PORVs CLOSED.
PORV isolation valves - BOTH ENERGIZED PORV relief paths - PORVs in AUTO, PORV isolation valves OPEN Normal Spray valves CLOSED.
ATC /
BOP Check RCS Temperature o RCPs running Tave at or trending to 557°F o RCPs NOT running Tcold at or trending to 557°F o Throttle AF to control cooldown.
ATC /
BOP Verify RCPs running. (1B RCP de-energized)
Verify RCP trip criteria NOT met.
ATC /
BOP Check if SG secondary boundaries are intact.
Verify NO SG depressurizing uncontrollably or completely depressurized.
ATC /
BOP Check if SG tubes are intact.
Recognize 1PR27J and 1D MS line indicate high rads.
CREW Identify entry conditions for 1BwEP-3, STEAM GENERATOR TUBE RUPTURE.
US Notify SM of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Request STA evaluation of status trees.
US Enter/Implement 1BwEP-3, STEAM GENERATOR TUBE RUPTURE, and direct operator actions of 1BwEP-3 to establish the following conditions:
ATC /
Check Status of RCPs:
Comments:
NRC 13-3 Page 29 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip BOP RCPs - running (1B RCP de-energized due to Bus 156 ABT failure).
ATC /
[CT]
E-3--A Identify ruptured SG 1D 1D Main steam line rad monitor ABNORMAL for plant conditions 1D SG level rising uncontrollably.
Isolate ruptured SG Verify 1MS018D CLOSED Verify 1SD002C & D CLOSED CLOSE MSIV and MSIV bypass valves for 1D SG Check ruptured SG level - Narrow Range > 10%
Verify/close 1AF013D&H - may have already been closed in 1BwEP-0.
ATC /
BOP Check ruptured SG pressure > 320 psig US Specify RCS temperature to which the RCS must be cooled down to allow depressurization of the RCS to ruptured SG pressure.
ATC /
BOP Dump steam at maximum rate via:
o Steam dumps in steam pressure mode o Intact SG PORVs Block MS Isolation after P-11 reached Bypass Steam Dump P-12 interlock when setpoint is reached by holding steam dump off/reset switch in bypass.
ATC /
BOP Check intact SG levels Control Aux feed flow to maintain intact SG levels Between 30% and 50%
ATC /
BOP Check PZR PORVs and ISOL Valves:
PORVs CLOSED.
PORV isolation valves - Both ENERGIZED PORV isolation valves OPEN ATC /
BOP Reset SI Depress BOTH SI Reset Pushbuttons at 1PM06J Verify SI ACTUATED BP light NOT lit at 1PM05J Verify AUTO SI BLOCKED BP light lit at 1PM05J ATC /
BOP Reset Phase A Depress BOTH Phase A Reset Pushbuttons at 1PM06J ATC /
BOP Restore IA to Cnmt Verify a station air compressor is running at 0PM01J OPEN 1IA065 and 1IA066 at 1PM11J ATC /
BOP Check if RH pumps should be stopped Check RCS pressure > 325 psig Stop BOTH RH pumps ATC /
BOP Check if RCS cooldown should be stopped
Comments:
NRC 13-3 Page 30 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip Check CETCs < required temperature Reduce steam flow from steam dumps or intact SG PORVs Maintain CETCs < required temperature Check ruptured SG pressure stable or rising Check RCS subcooling acceptable ATC /
[CT]
E-3--C Depressurize RCS to refill Pzr OPEN PZR sprays/1 PZR PORV at 1PM05J until any of the following are met:
o RCS press < ruptured SG press and PZR level > 14%
o PZR level > 68%
o RCS subcooling is unacceptable CLOSE PZR sprays/1 PZR PORV at 1PM05J Check RCS pressure rising ATC /
BOP Check if ECCS flow should be terminated Check subcooling acceptable Check Aux feed flow >500 gpm OR NR level in 1 intact SG >10% level Check RCS pressure rising Check Pzr level >14%
Stop ECCS pumps Stop Both SI pumps and 1 CV pump ATC /
BOP Terminate high-head ECCS & establish charging flow Depress BOTH SI recirc sump reset pushbuttons at 1PM06J Depress BOTH CV pump recirc valve reset pushbuttons at 1PM05J Check CV pump recirc valves OPEN at 1PM05J:
1CV8110, 1CV8111, 1CV8114, 1CV8116 ATC /
BOP CLOSE 1SI8801A & B at 1PM05J Place 1CV182 controller demand at 0%
OPEN 1CV8105 & 1CV8106 at 1PM05J Adjust 1CV121 and 1CV182 to maintain desired charging and seal injection flow.
NOTE: At examiner discretion, the scenario may be terminated at this point. The following steps address the second depressurization.
ATC /
BOP Control charging to maintain PZR Level stable Verify ECCS flow not required:
o Subcooling acceptable o PZR level > 14%
Check RMCS:
Makeup set for automatic control (not available due to previous failure)-
continue manual RMCS control Check if Letdown can be established:
PZR level > 27%
BOP to establish letdown per 1BwOA ESP-2 (crew must align the 1B letdown heat exchanger due to the previous 1A letdown heat exchanger tube leak)
Adjust charging and letdown to maintain subcooling and avoid SG overfill
Comments:
NRC 13-3 Page 31 of 31 Scenario No:
NRC 13-3 Event No.
8, 9 Event
==
Description:==
1D SGTR, 1A AF Pp auto start failure, 1B AF Pp trip ATC /
BOP Align cent chg pump suction to VCT:
Check VCT level > 37% (if not manually adjust using manual RMCS makeup)
Check VCT pressure 15-65 psig Open 1CV112B and 1CV112C Close 1CV112D and 1CV112E Check 1CV8804A - closed Check SI and cent chg pumps suction header crosstie valves:
o 1SI8807A and B - closed; or o 1SI8924 - closed Check if SI Accumulators should be isolated:
RCS pressure < 800 psig - not met continue to step 29 Control RCS Pressure and Charging flow to minimize RCS to Secondary Leakage:
o PZR level < 27% and 1D SG level rising: raise charging flow and depressurize RCS using available PZR spray.
o PZR level 27-50% and 1D SG level rising: depressurize RCS using available PZR spray.
o PZR level 50-68% and 1D SG level rising: depressurize RCS using available PZR spray and reduce charging flow.
Terminate the scenario at examiners discretion.
(Final)
Simulation Facility Braidwood Scenario No.:
NRC 13-4 Operating Test No.: 2013 -1 Examiners:
Applicant:
_____________________ SRO
_____________________ ATC
_____________________ BOP Initial Conditions:
IC-21 Turnover: Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. Online risk is green.
Following completion of turnover, the crew is to perform 1BwOS FW-W1, UNIT 1 TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE.
Event No.
Malf. No.
Event Type*
Event Description Preload IMF RP14A IMF RP14B TRGSET 1 ZDISIA1 = = 1 TRG 1 DMF RP14A TRGSET 2 ZDISIA1 = = 1 TRG 2 DMF RP14B TRGSET 3 ZDISIA2 = = 1 TRG 3 DMF RP14A TRGSET 4 ZDISIA2 = = 1 TRG 4 DMF RP14B IMF RH04B IMF RH01A IMF RH12B IMF FW01 IOR ZLO1RY8010A1 OFF SI actuation failure (Train A)
SI actuation failure (Train B) 1SI8811B fails to auto open 1A RH Pp trip 1B RH Pp auto start failure 1A FW Pp fail to start/trip Failed indication for 1RY8010A PZR Safety Valve 1
None N-BOP, US TS-US Perform 1BwOS FW-W1 and determine PZR Safety Valve TRM/Tech Spec requirements 2
IMF RX01J 0 300 I-BOP, US TS-US 1PT-544, 1D SG steam pressure channel fails low 3
IMF RX13A 100 10 I-ATC, US TS-US PZR level channel 1LT-459 fails high (Tech Spec) 4 IOR ZAI1TK130 95 60 I-ATC, US 1TK-130 controller faillure 5
IMF FW02A C-BOP, US R-ATC 1B FW Pump trip requiring turbine runback 6
IMF TH18B 1B RCP shaft break 7
IMF TH06B (0 30) 540000 M-ALL Large break RCS LOCA (1B RCS cold leg) 8 Preload Failure of SI to automatically actuate 9
Preload C-ATC, BOP 1SI8811B fails to auto open (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
SCENARIO OVERVIEW Unit 1 is at 100% power, steady state, equilibrium xenon, BOL. Online risk is green.
After completing shift turnover and relief, the BOP will perform 1BwOS FW-W1, UNIT 1 TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE and the US will address the TRM/Tech Spec requirements for the loss of PZR safety valve indication (TRM 3.3.i Condition A & C).
After completing 1BwOS FW-W1, 1D SG steam pressure channel, 1PT-544, fails low. The crew should take actions to stabilize the plant per 1BwOA INST-2. Technical Specifications 3.3.2 and 3.3.4 apply.
After the 1D SG steam pressure failure has been addressed, PZR level channel 1LT-459 will fail high.
1CV121, charging header flow control valve, will lower charging flow and pressurizer level will lower. The ATC will take manual control of PZR level and stabilize PZR level. 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment C, will be implemented. The ATC will restore PZR level control to automatic after PZR level is restored to normal and an operable PZR level control channel is selected. Technical Specifications 3.3.1, conditions A and K apply.
After the 1LT-459 failure is addressed, 1TK-130 output, Letdown Heat Exchanger Outlet Temperature Controller, will fail causing high letdown temperature. The BwAR should be referenced and the RO should take manual control to restore letdown temperature to normal. The crew may elect to isolate letdown due to high temperature. If isolated, letdown may be restored per BwOP CV-17.
After the 1TK-130 Controller has been addressed, 1B Feedwater Pump will trip. 1BwOA SEC-1, SECONDARY PUMP TRIP-Attachment A will be entered. The BOP will initiate a turbine load reduction to 700 MW at 250 MW/minute. The ATC will borate the RCS as necessary to stabilize RCS temperature.
After the crew stabilizes the plant from the FW pump trip, the 1B RCP shaft will fail. RCS flow in the 1B loop will drop until an automatic reactor trip occurs due to low RCS loop flow. The 1B RCP will dislodge components into the RCS, followed shortly (30 sec) by a large break LOCA in RCS loop 1B due to the dislodged RCP components. Pressurizer pressure will fall to the auto SI setpoint, but auto SI actuation will fail requiring a manual SI actuation. 1A RH pump will trip when starting. The crew must manually start 1B RH pump to establish low head ECCS flow. The crew will take actions per 1BwEP-0, REACTOR TRIP OR SAFETY INJECTION. The crew will transition to 1BwEP-1 after determining that the RCS is not intact.
When the RWST level reaches the low-2 setpoint, the crew will transition to 1BwEP ES-1.3, TRANSFER TO COLD LEG RECIRCULATION. Upon transition to 1BwEP ES-1.3, 1SI8811B will not automatically open due to failure of relay K648. The crew will align the 1B RH pump for cold leg recirculation per attachment A of 1BwEP ES-1.3 to ensure long term core cooling.
Completion criteria is performance of 1BwEP ES-1.3, step 5.
Critical Tasks
- 1. Manually actuate Safety Injection prior to transition to 1BwEP-1 or past step 7.a of 1BwEP ES-0.1.
(ERG Critical Task number - E-0--D) (K/A number - 000040AA1.01 importance - 4.6/4.6)
- 2. Manually start 1B RH pump prior to completion of step 6 of 1BwEP-0. (ERG Critical Task number - E-0--H) (K/A number - 000011EA1.13 importance - 4.1/4.2)
- 3. Transfer to cold leg recirculation and establish ECCS recirculation flow that at least meets the assumptions of the plant specific LOCA analysis. (ERG Critical Task number - ES-1.3--A) (K/A number
- 006000A4.05 importance - 3.9/3.8)
SIMULATOR SETUP GUIDE:
Verify/perform TQ-BR-201-0113, BRAIDWOOD TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.
Establish the conditions of IC-21, 100% power, steady state, equilibrium xenon.
Complete items on Simulator Ready for Training Checklist.
Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.
Place simulator in RUN (allow simulator to run during board walk down and turnover).
Verify/place 0A and 0C VA plenums in service.
Run caep NRC 13-4 SETUP from disk and verify the following active:
IMF RP14A IMF RP14B TRGSET 1 ZDISIA1 = = 1 TRG 1 DMF RP14A TRGSET 2 ZDISIA1 = = 1 TRG 2 DMF RP14B TRGSET 3 ZDISIA2 = = 1 TRG 3 DMF RP14A TRGSET 4 ZDISIA2 = = 1 TRG 4 DMF RP14B IMF RH04B IMF RH01A IMF RH12B IMF FW01 IOR ZLO1RY8010A1 OFF Place a flag on 1RY8010A indication at 1PM05J.
Verify/Set I Target Curve slopes to +2% of I.
EXAMINERS BRIEF: This scenario is scheduled for groups involving a surrogate. Brief the surrogate to NOT perform a manual SI and NOT to perform the actions of 1BwEP ES-1.3 to allow the examinee in the ATC to perform these actions.
Provide examinees with turnover sheets and 1BwOS NR-1.
Look up boric acid range for runback in response to a single FW pump trip in the Operator Aid book and enter on page 14 where it states: per Operator Aid book _____ gallons. Provide this information to the examiners or enter in their copy of the scenario guide on page 14.
As off-going RO/US during the turnover, verbally inform the crew that you noticed indication for 1RY8010A dark and replaced the bulb for the closed light after you had already completed your turnover sheets and you have NOT investigated any applicable administrative requirements.
INSTRUCTOR/SIMULATOR RUN AID GUIDE
Event 1: Perform 1BwOS FW-W1, UNIT 1 TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE.
As off-going RO/US during the turnover, verbally inform the crew that you noticed indication for 1RY8010A dark and replaced the bulb for the closed light after you had already completed your turnover sheets and you have NOT investigated any applicable administrative requirements If dispatched as Equipment Operator to observe main feedwater pump stop valve operation, report stop valves respond normally as they are tested.
Acknowledge as SM commencement and completion of surveillance, and TRM 3.3.i Condition A & C for the loss of Safety Valve Indication.
Event 2: 1D SG steam pressure channel fails low IMF RX01J 0 300 As SM acknowledge 1PT-544 failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.
As SM, if requested support for tripping bistables, report that bistables are not to be tripped until work analyst and NSO support can be obtained (i.e. not at this time) and that the abnormal operating procedure should be continued. Bistable tripping will be conducted later.
Event 3: PZR level channel 1LT-459 fails high.
Insert IMF RX13A 100 10 to fail 1LT-459 high over a 10 second period.
As SM, if requested support for tripping bistables in AEER, report that AEER bistables are not to be tripped until work analyst and NSO support can be obtained (in approx. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />) and that the abnormal operating procedure should be continued. AEER bistable tripping will be conducted later.
If lead examiner desires the bistables tripped, participate in brief and perform the following:
As extra NSO contact Unit 1 (X-2209)
Insert the following:
MRF RP20 OPEN (open protection cabinet #1 door)
MRF RX029 TEST (C1-751 PZR LEVEL TEST SWITCH 459)
MRF RP20 CLOSE (close protection cabinet #1 door)
Acknowledge as Shift Manager the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.
INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 4: 1TK-130 fails high Insert: IOR ZAI1TK130 95 60 Open monitor file for 1CC130A/B valve position (CCV1CC130A/B)
Acknowledge as SM requests for maintenance support, on line risk assessment, and IR for 1TK-130 failure.
If dispatched as EO to 1CC130A/B, report valve position as indicated in monitor file.
As chemistry (if called), report that the in-service mixed bed demin will remain off until it can be sampled.
Event 5: 1B Feedwater Pump trip Insert IMF FW02A As SM, acknowledge the failure, 1BwOA SEC-1 entry, request for E Plan evaluation, and requests for on line risk assessment, maintenance support, and IR initiation.
If dispatched as EO, report 1B Feedwater pump is tripped but no visible cause is apparent. 1A feedwater pump breaker has a ground overcurrent target up.
Events 6 & 7: 1B RCP shaft break & Large break LOCA (1B RCS cold leg) 30 seconds later.
Run caep NRC 13-4 EVENT 6 _ 7 from disk and verify the following actuate:
IMF TH18B IMF TH06B (0 30) 540000 10 Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
If dispatched as EO to 1A RH pp, report ground over current relay flag has dropped.
Events 8 & 9: Failure of SI to automatically actuate; 1SI8811B fails to auto open See Preload.
As SM, acknowledge notification of ESF actuation equipment failures.
Scenario No:
NRC 13-4 Event No.
1 Event
==
Description:==
Perform 1BwOS FW-W1 and determine PZR Safety Valve TRM/Tech Spec requirements Time Position Applicants Actions or Behavior CUE
- From turnover perform 1BwOS FW-W1, UNIT 1 TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE.
US
- Direct BOP to perform 1BwOS FW-W1.
- Identify that TRM 3.3.i condition A & C applies for 1RY8010A indication being inoperable.
- Refer to 1BwOS FW-W1.
- Update data sheet D-2 as each test is performed.
- Test 1B main FW pump at 1PM04J:
Depress left LP stop valve TEST pushbutton.
Observe left LP stop valve OPEN lamp goes out.
Observe left LP stop valve TEST button illuminates.
Observe left LP stop valve OPEN lamp illuminates.
Depress high pressure stop valve TEST pushbutton.
Observe high pressure stop valve OPEN lamp goes out.
Observe high pressure stop valve CLOSED and TEST buttons illuminate.
Observe high pressure stop valve CLOSED button goes out.
- Test 1C main FW pump at 1PM04J:
Depress left LP stop valve TEST pushbutton.
Observe left LP stop valve OPEN lamp goes out.
Observe left LP stop valve TEST button illuminates.
Observe left LP stop valve OPEN lamp illuminates.
Depress high pressure stop valve TEST pushbutton.
Observe high pressure stop valve OPEN lamp goes out.
Observe high pressure stop valve CLOSED and TEST buttons illuminate.
Observe high pressure stop valve CLOSED button goes out.
- Inform US 1BwOS FW-W1 complete.
US
- Acknowledge report.
o Notify SM 1BwOS FW-W1 complete.
EVALUATOR NOTE: After 1BwOS FW-W1 is complete and with lead examiners concurrence, insert the next event.
Scenario No:
NRC 13-4 Event No.
2 Event
==
Description:==
1D SG steam pressure channel fails low Time Position Applicants Actions or Behavior CUE
- Annunciator MS PRESS RATE STM LINE ISOL ALERT (1-15-E1)
- Annunciator S/G 1D LOW PRESS STEAMLINE ISOL ALERT (1-15-D1)
- Annunciator S/G 1D FLOW MISMATCH STM FLOW LOW (1-15-D3)
Scenario No:
NRC 13-4 Event No.
2 Event
==
Description:==
1D SG steam pressure channel fails low Time Position Applicants Actions or Behavior o Annunciator S/G 1D LEVEL DEVIATION HIGH LOW (1-15-D9)
- S/G 1D feed flow and NR level lowering BOP Determine SG 1D feed flow and/or NR level lowering Identify 1PI-544A indicates low steam pressure o Reference BwARs 1-15-D1/1-15-D3/1-15-E1 as time permits CREW Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL US Implement 1BwOA INST-2 "OPERATION WITH A FAILED INSTRUMENT CHANNEL", Attachment F "STEAM PRESSURE CHANNEL FAILURE" and direct operator action o Notify SM of SG pressure channel failure o Notify SM to evaluate for Emergency Plan.
BOP Stabilize 1D SG level at 1PM04J:
Place 1FK-540, FW Reg Valve 1FW540 controller, in manual.
Raise demand on 1FK-540 sufficiently to raise feedwater flow to restore 1D SG level.
Operate 1FK-540 in manual to stabilize 1D SG level in the normal operating band.
Verify 1PI-509 indicates adequate feedwater P.
Manually control FW pump speed to restore P, if necessary.
Select operable steam flow channel.
Place 1D SG steam flow channel select C/S to F-543. (may have been selected per BwAR response)
Establish automatic level control by placing 1FK-540 in auto.
ATC/B OP Perform the following:
Monitor reactor power at 1PM05J.
o Reduce turbine load by initiating 5 MW ramp at OWS 211 or 210 or per instruction of 1BwOA INST-2.
Assist US by making notifications.
o Refer to BwARs as time permits.
Note: The reactor may exceed 100% power during the secondary transient. The crew may choose to enter 1BwOA PRI-16 to lower reactor power. Steps for 1BwOA PRI-16 are in italics below.
US Determines TS 3.3.2 conditions A and D are applicable.
Determines TS 3.3.4 condition A is applicable. (May determine Tech Spec applicability by referring to 1BwOSR 3.3.4.1, UNIT ONE REMOTE SHUTDOWN INSTRUMENTATION MONTHLY CHANNEL CHECKS)
Contact SM to perform risk assessment, initiate IR, and contact appropriate personnel to investigate/correct instrument failure.
EVALUATOR NOTE: After the actions for SG pressure channel failure are complete and with lead examiners concurrence, enter next event.
Scenario No:
NRC 13-4 Event No.
2 Event
==
Description:==
1D SG steam pressure channel fails low Time Position Applicants Actions or Behavior CREW Identify entry conditions for 1BwOA PRI-16, RESPONSE TO OVERPOWER CONDITION US Implement 1BwOA PRI-16, RESPONSE TO OVERPOWER CONDITION and direct operator action.
Notify SM of procedure entry.
ATC/B OP
- Check Reactor trip setpoints not exceeded
- PR NIs < 109%
- DT < OTDT and OPDT setpoints ATC/B OP
- Check Reactor Power <100%
- PR NIs
- 10 min. Calorimetric computer point ATC/B OP o Reduce turbine load by initiating ramp at OWS 211 or 210.
US
- Contact SM to perform risk assessment, initiate IR, and contact appropriate personel.
Scenario No:
NRC 13-4 Event No.
3 Event
==
Description:==
PZR level channel 1LT-459 fails high.
Time Position Applicants Actions or Behavior CUE
- Annunciator 1-12-A3, PZR LEVEL HIGH RX TRIP STPT ALERT
- Annunciator 1-12-C3, PZR LEVEL CONT DEV HIGH HTRS ON
- Annunciator 1-9-D3, CHG LINE FLOW HIGH LOW
- PZR level and charging flow lowering.
ATC Determine PZR level and/or charging header flow lowering at 1PM05J.
Identify 1LI-459A is failing high.
Report failure to US.
Perform the following at 1PM05J:
Place 1LK-459, PZR master level controller, or 1FK-121, CV pumps flow control valve, in manual.
Raise demand on 1LK-459 or 1FK-121 sufficiently to raise charging flow and PZR level.
Operate 1LK-459 or 1FK-121 in manual to restore PZR level to normal operating band and maintain 8-13 gpm RCP seal injection flow.
CREW Reference BwARs 1-12-A3/1-12-C3/1-9-D3.
Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL.
US Notify Shift Manager of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
Implement 1BwOA INST-2 OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment C, PRESSURIZER LEVEL CHANNEL FAILURE, and direct operator actions of 1BwOA INST-2 to establish the following conditions:
ATC Check PZR level at 1PM05J:
PZR level - normal on 1LI-460 & 1LI-461.
Manually restore PZR level using 1LK-459 or 1FK-121.
Select operable PZR level control channel:
Place PZR level control select C/S to CH 461/460.
Select operable PZR level channel for PZR level recorder at 1PM05J:
Verify PZR level channel to recorder select switch in 460.
Check PZR level > 17% on 1LI-460 & 1LI0461.
Check letdown flow established:
o Check valve alignment.
o Letdown flow approximately 120 gpm on 1FI-132.
Check PZR heaters:
PZR heaters available in auto.
Check PZR level control in auto at 1PM05J:
1LK-459, master PZR level controller.
1FK-121, CV pumps flow control valve.
BOP Perform the following:
o Request operations support for tripping bistables.
Scenario No:
NRC 13-4 Event No.
3 Event
==
Description:==
PZR level channel 1LT-459 fails high.
Time Position Applicants Actions or Behavior o Assist US by making notifications.
o Refer to BwARs.
US Determine TS 3.3.1, conditions A and K are applicable.
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
EVALUATOR NOTE: After the actions for the pressurizer level channel failure are complete and with lead examiners concurrence, insert the next event.
Scenario No:
NRC 13-4 Event No.
4 Event
==
Description:==
1TK-130 Controller Failure Time Position Applicants Actions or Behavior CUE Annunciator LTDWN TEMP HIGH (1-9-E2)
Annunciator LTDWN HX OUTLT TEMP HIGH (1-8-C5) 1TI-130 indicates letdown temperature high 1CV-129, demin high temp letdown divert valve, in VCT position ATC
- Recognize 1TK-130 controller failure.
CREW o Refer to BwARs as time permits US
- Inform SM and ask for IR and additional personnel for assistance.
- Inform US of Letdown High temperature divert valve status US o Direct ATC to place divert valve to DEMIN position o
May contact chemistry to determine if demin should be returned to service. If
Scenario No:
NRC 13-4 Event No.
4 Event
==
Description:==
1TK-130 Controller Failure Time Position Applicants Actions or Behavior chemistry contacted, direction will be provided to leave demin bypassed pending sampling Note: The crew may elect to isolate letdown based on elevated temperature.
Following letdown isolation the crew may elect to establish excess letdown or re-establish normal letdown. The steps for restoring normal letdown are in italics below.
/BOP o
Establish normal letdown per BwOP CV-17 o Verify/close 1CV8149A/B/C o Verify CC aligned to letdown Hx (was previously aligned) o Place 1CV131 manual at 30% demand o Place 1CC130 in manual at 60% demand o Open 1CV8152/8160 o Open 1CV459/460 o Verify open 1CV8324A & 1CV8389A o Verify/open 1CV381B o Verify/close 1CV381A o Verify/open 1CV8401A o Verify/close 1CV8145 o Verify/open 1CV8146/8147 o Open 1CV8105/8106 o Adjust charging flow to approx. 100 gpm w/seal injection 8-10 gpm per RCP o Open 1CV8149A/B/C and control 1CV131 to maintain letdown pressure 360-380 psig o Control 1CC130 to maintain letdown temperature 90-115°F o Place controllers in auto o Verify 1PR06J in service o
Verify proper operation of RMCS during VCT makeup o
Proper flow indicated on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110).
o Restore PZR level to program The steps establishing excess letdown are in italics below.
/BOP o Establish excess letdown per BwOP CV-15 o
Verify Open 1CV8100/8112 o
Open 1CC9437A/B o
Verify Closed 1CV123 o
Verify 1CV8143 C/S in VCT position o
Open 1RC8037A/B/C/D o
Open 1CV8153A(B) o Slowly Open 1CV123 while monitoring excess letdown outlet temperature Initiate the next event when the lead examiner approves.
Scenario No:
NRC 13-4 Event No.
5 Event
==
Description:==
1B FW Pump trip Time Position Applicants Actions or Behavior CUE
- Annunciator FW PUMP 1B TRIP (1-16-B1)
- Recognizes 1B FW pump tripped o Refer to BwAR 1-16-B1 as time permits
- Reports failure to US CREW
- Identify entry conditions for 1BwOA SEC-1, SECONDARY PUMP TRIP US
- Acknowledge 1B FW pump trip
- Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct failure
- Implement 1BwOA SEC-1, SECONDARY PUMP TRIP Attachment A "FW PUMP TRIP" and direct operator actions of 1BwOA SEC-1 to establish the following conditions.
BOP CLOSE 1FW012B.
Check turbine load > 700 MW.
ONLY 1C FW pump running Attempt start of 1A MDFW pump.
Initiate turbine load reduction to 700 MW at 250 MW/min o Initiate FW runback on OWS graphic 5512 o Push Turbine Runback Pushbutton Verify turbine load lowering ATC Determine required boric acid volume: per Operator Aid book _____ gallons.
(BwOP CV-6 step 2 borate in automatic via procedure step or hard card Att. A)
Perform the following at 1PM05J:
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION
- Set 1FK-110 BA Flow Control to desired boration rate.
- Set 1FY-0110 BA Blender Predet Counter to desired volume.
- Place MAKE-UP MODE CONT SWITCH to STOP position.
- Place MODE SELECT SWITCH to BORATE position.
- Place MAKE-UP MODE CONT SWITCH to START.
- Verify proper operation of valves and BA transfer pump (1CV110B open, Boric Acid Transfer Pump running, 1CV110A throttles open, proper BA flow indicated on recorder).
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION.
Scenario No:
NRC 13-4 Event No.
5 Event
==
Description:==
1B FW Pump trip Time Position Applicants Actions or Behavior OR (BwOP CV-6 step 4 or hard card Att. A batch addition) Batch addition of Boric Acid:
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION.
- Open 1CV110B.
- Open 1CV110A.
- Start the BA Transfer pump.
o Adjust M/A station setpoint on 1LK-112 if desired.
- When desired amount of BA has been added, stop the BA Transfer Pump.
- Close 1CV110A.
- Close 1CV110B.
o Adjust M/A station setpoint on 1LK-112 if desired.
- Place 1CV110A in AUTO.
- Place 1CV 110B in AUTO.
o Turn on PZR backup heaters in accordance with BwOP RY-13, PRESSURIZER BACKUP HEATER OPERATION.
BOP Start standby CD/CB Aux oil pump Start standby CD/CB pump Check alarm 1-16-E1 NOT LIT Verify FW flow > Stm Flow SG levels stable at or trending to normal Deactivate turbine runback 1-16-D2 FW PUMP DSCH FLOW HIGH alarm - if lit:
o Reduce feed flow while restoring SG levels o Reduce turbine load at 20 MW/MIN or as required to reduce FW pump discharge flow US/AT C
Check PDMS operable Annunciator PDMS INOPERABLE not lit (1-10-E8) 1BwOS PDMS-1A not implemented Annunciator PDMS LIMIT EXCEEDED not lit (1-10-D7)
ATC Control I near target Monitor RCS parameters o
If RCS pressure lowers < 2209 psig, notify US to evaluate TS 3.4.1, RCS DNB Limits (no entry required) o If control rods < low - 2 rod insertion limit, notify US to enter TS 3.1.6, Control Bank Insertion Limits o
If Rod Bank Low Insertion Limit 1-10-B6 Lit:
o Borate as necessary o Refer to TS 3.1.6 Check C-7: Lit When all steam dumps are closed, momentarily place Steam Dump Mode selector in RESET
Scenario No:
NRC 13-4 Event No.
5 Event
==
Description:==
1B FW Pump trip Time Position Applicants Actions or Behavior US Notify chemistry to monitor secondary plant chemistry Notify SM to perform risk assessment Check reactor power change > 15% in one hour o
Notify chemistry to perform TS 3.4.16 sampling o
Notify rad protection to perform RETS 12.4.1.A sampling o
Determine TS 3.1.6, condition A entry required if control rods below low - 2 rod insertion limit The next event (1B RCP shaft break) is to be inserted when the Lead Examiner is satisfied the crew has adequately addressed the FW pump trip. Suggest the malfunction be inserted during latter part of the turbine runback.
Scenario No:
NRC 13-4 Event No.
6 Event
==
Description:==
1B RCP shaft failure Time Position Applicants Actions or Behavior CUE Annunciator LOOSE PARTS MONITORING SYSTEM TROUBLE (1-13-E9)
Annunciator RCP 1B BRKR OPEN OR FLOW LOW ALERT (1-13-B3)
Annunciator RCP LOW FLOW ABOVE P8 RX TRIP (1-11-C5) (RED FIRST OUT) o RCS loop 1B flow lowering CREW Identify entry conditions for 1BwEP-0, REACTOR TRIP OR SAFETY INJECTION US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BwEP-0 and direct operator actions of 1BwEP-0 ATC Perform immediate operator actions of 1BwEP-0:
Verify reactor trip Rod bottom lights - ALL LIT Reactor trip & Bypass breakers - OPEN Neutron flux - DROPPING o Trip 1B RCP after reactor trip is verified.
BOP Perform immediate operator actions of 1BwEP-0:
Verify Turbine Trip All Turbine throttle valves - CLOSED All Turbine governor valves - CLOSED BOP Perform immediate operator actions of 1BwEP-0:
Verify power to 4KV busses ESF Buses - BOTH ENERGIZED (141 & 142)
Scenario No:
NRC 13-4 Event No.
7 & 8 Event
==
Description:==
Large break RCS LOCA / Failure of SI to automatically actuate Time Position Applicants Actions or Behavior CREW
[CT]
E-0--D Check SI Status o SI First OUT annunciator - LIT o SI ACTUATED Permissive Light -NOT LIT o SI Equipment - NOT AUTOMATICALLY ACTUATED o
Either SI pumps -NEITHER RUNNING o
Either CV pump to cold leg isolation valve NOT OPEN - 1SI8801A/B Recognize SI Actuation DID NOT occur Manually actuate SI from 1PM05J or 1PM06J
Scenario No:
NRC 13-4 Event No.
7 & 8 Event
==
Description:==
Large break RCS LOCA / Failure of SI to automatically actuate Time Position Applicants Actions or Behavior ATC Determine RCP trip required o
CNMT phase B actuated o
RCS pressure < 1425 psig & High head SI flow (1FI-917) > 100 gpm Trip ALL RCPs US o Direct BOP to perform Attachment B of 1BwEP-0 EVALUATOR NOTE: US and ATC will continue in 1BwEP-0 while BOP is performing Attachment B:
BOP Verify FW isolated at 1PM04J:
FW pumps - TRIPPED.
Isolation monitor lights - LIT.
FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.
Verify DGs running at 1PM01J:
DGs - BOTH RUNNING.
1SX169A/B OPEN.
Dispatch operator locally to check operation Verify Generator Trip at 1PM01J:
OCB 1-8 and 7-8 open.
PMG output breaker open.
Verify Control Room ventilation aligned for emergency operations at 0PM02J:
VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT.
Operating VC train equipment - RUNNING.
0B Supply fan 0B Return fan 0B M/U fan 0B Chilled water pump 0B Chiller Operating VC train dampers - ALIGNED.
M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.
0B VC train M/U filter light - LIT.
0VC09Y - OPEN 0VC313Y - CLOSED Operating VC train Charcoal Absorber aligned for train B.
0VC44Y - CLOSED 0VC05Y - OPEN 0VC06Y - OPEN Control Room pressure greater than +0.125 inches water on 0PDI-VC038.
Verify Auxiliary Building ventilation aligned at 0PM02J:
Two inaccessible filter plenums aligned.
Plenum A:
- 0VA03CB - RUNNING
- 0VA023Y - OPEN
- 0VA436Y - CLOSED Plenum C:
- 0VA03CF - RUNNING
Scenario No:
NRC 13-4 Event No.
7 & 8 Event
==
Description:==
Large break RCS LOCA / Failure of SI to automatically actuate Time Position Applicants Actions or Behavior
- 0VA072Y - OPEN
- 0VA438Y - CLOSED Verify FHB ventilation aligned at 0PM02J:
- 0VA04CB - RUNNING
- 0VA055Y - OPEN
- 0VA062Y - OPEN
- 0VA435Y - CLOSED Secure 1A and 1C HD pumps Initiate Periodic Checking of Spent Fuel Cooling Notify US Attachment B complete ATC/
[CT]
E-0--H Verify ECCS pumps running Both CV pumps - RUNNING RH pumps - NONE RUNNING-Manually start 1B RH pump (attempt to start 1A RH pump)
Both SI pumps - RUNNING ATC Perform the following at 1PM06J:
Verify RCFCs running in Accident Mode:
Group 2 RCFC Accident Mode lights - ALL LIT.
Verify Phase A isolation:
Group 3 Cnmt Isol monitor lights - ALL LIT.
Verify Cnmt Vent isolation:
Group 6 Cnmt Vent Isol monitor lights - ALL LIT.
Verify AF system:
AF pumps - Both RUNNING.
AF isolation valves - 1AF13A-H OPEN.
AF flow control valves - 1AF005A-H THROTTLED.
Verify CC pumps - BOTH RUNNING.
Verify SX pumps - BOTH RUNNING.
Check if Main Steamline Isolation - required:
o All S/G pressures > 640 psig (at 1PM04J).
o CNMT pressure > 8.2 psig.
Verify MSIVs & MSIV bypass valves - CLOSED.
Check if CS is required:
CNMT pressure has risen > 20 psig.
Group 6 CS monitor lights - ALL LIT.
Group 6 phase B lights - ALL LIT.
Verify/Stop ALL RCPs (at 1PM04J).
CS eductor suction flow - > 15 gpm on 1FI-CS013 & 1FI-CS014.
CS eductor additive flow - > 5 gpm on 1FI-CS015 & 1FI-CS016.
BOP/
AF flow > 500 gpm S/G NR levels - NOT rising in an uncontrolled manner
Scenario No:
NRC 13-4 Event No.
7 & 8 Event
==
Description:==
Large break RCS LOCA / Failure of SI to automatically actuate Time Position Applicants Actions or Behavior ATC/
BOP Verify ECCS valve alignment Determine Group 2 Cold Leg Injection monitor lights required for injection - All lit ATC/
BOP Verify ECCS flow High Head SI flow >100 gpm (1FI-917)
RCS pressure < 1700 psig SI pumps discharge flow > 200 gpm RCS pressure < 325 psig 1B RH pump discharge flow > 1000 gpm ATC Check PZR PORVs and SPRAY VALVES at 1PM05J:
1RY455 & 1RY456 CLOSED PORV isol valves - 1RY8000A & 1RY8000B BOTH ENERGIZED PORV relief path - Both PORVs in AUTO, Both isolation valves - OPEN.
Normal PZR Spray Valves CLOSED ATC Maintain RCS temperature control at 1PM05J:
Check RCPs - NONE RUNNING.
Verify RCS cold leg temperature stable at or trending to 557oF.
o MSIVs closed.
o Throttle AF flow to SGs ATC Check status of RCPs at 1PM05J:
o All RCPs - NONE RUNNING.
o Any RCPs still running - TRIP All RCPs BOP/
ATC Check if SG secondary pressure boundaries are intact at 1PM04J:
- Check pressure in all SGs:
None dropping in an uncontrolled manner.
None completely depressurized.
BOP/
ATC Check S/G tubes are intact at RM-11 console:
- 1PR08J SG Blowdown.
- 1PR27J SJAE/GS.
1AR22/23A-D Main steam Lines.
CREW Determine RCS in NOT intact:
o CNMT area rad monitors > alert alarm setpoint at RM-11 console.
o CNMT pressure > 3.4 psig (1PI-CS 934-937) at 1PM06J.
o CNMT floor drain sump level > 46 inches (1LI-PC002/003) at 1PM06J.
CREW Transition to 1BwEP-1, LOSS OF REACTOR OR SECONDARY COOLANT US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Request STA evaluation of status trees Enter/Implement 1BwEP-1 and direct operator actions of 1BwEP-1 to establish the following conditions:
Scenario No:
NRC 13-4 Event No.
7 & 8 Event
==
Description:==
Large break RCS LOCA / Failure of SI to automatically actuate Time Position Applicants Actions or Behavior Examiners note: When RWST level reaches the low-2 setpoint, the crew will transition to 1BwEP ES-1.3 to align ECCS for cold leg recirc. 1BwEP ES-1.3 actions begin on page 24.
Scenario No:
NRC 13-4 Event No.
9 Event
==
Description:==
1SI8811B fail to auto open.
Time Position Applicants Actions or Behavior ATC
- Check Status of RCPs:
RCPs - NONE RUNNING ATC/
BOP Check if SG secondary pressure boundaries are intact:
- Check pressure in all SGs:
None dropping in an uncontrolled manner None completely depressurized Check intact SG levels SG levels maintained between 10% (31% Adverse) and 50%
Check secondary radiation normal.
- Reset Phase A
- Depress BOTH Phase A Reset Pushbuttons at 1PM06J OPEN 1SD005A-D at 1PM11J At RM-11 or PPC Check secondary rad trends on :
1PR08J SG Blowdown 1PR27J SJAE/GS 1AR22/23A-D Main steam lines ATC Check at least ONE PZR PORV relief path available:
PORV isol valves - BOTH ENERGIZED PORV relief path - BOTH PORVs in AUTO, 1RY8000A & B - OPEN CREW Check if ECCS flow should be reduced RCS subcooling - NOT acceptable Check if CS should be stopped Both CS pumps - RUNNING Reset CS Spray add tank lo-2 level light - NOT LIT CS termination requirements CNMT pressure < 15 psig Spray operating time > 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> (determine 8 hrs criteria not met)
Check if RH pumps should be stopped
- Reset SI
- Depress BOTH SI Reset Pushbuttons at 1PM06J
- Verify SI ACTUATED BP light NOT lit at 1PM05J
CREW Check RCS and SG Pressures for Faulted SG indications Pressure in all SGs: stable RCS pressure: dropping NOTE: DEPENDING ON TIMING OF THE LO-2 RWST CONDTION SOME STEPS WILL NOT BE PERFORMED PRIOR TO TRANSITION TO 1BwEP ES-1.3 CREW Check if DGs should be stopped:
All 4KV buses energized by offsite power
Scenario No:
NRC 13-4 Event No.
9 Event
==
Description:==
1SI8811B fail to auto open.
Time Position Applicants Actions or Behavior Stop any unloaded DG and place in standby per BwOP DG-12 Initiate Evaluation of Plant Status Cold Leg recirculation capability: B train available Auxiliary Building radiation trends: normal Make notifications to obtain various samples Evaluate plant equipment for long term recovery CUE Annunciator RWST LEVEL LO-2 (1-6-B7)
RWST level <46%.
CREW Transition to 1BwEP ES-1.3, TRANSFER TO COLD LEG RECIRCULATION US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Note - BwFRs should not be implemented during steps 1 thru 6 of 1BwEP ES-1.3 Enter/Implement 1BwEP ES-1.3 and direct operator actions of 1BwEP ES-1.3 to establish the following conditions:
ATC/
[CT]
ES-1.3--
A (Also see next page)
Establish CC flow to RH HXs 1CC9473A & B - OPEN CC pumps - TWO RUNNING Open 1CC9412A & B CC to RH HX flows - 1FI-0689 & 1FI-0688 > 5000 gpm Check CNMT floor level - 1LI-PC006 & 1LI-PC007 > 8 inches (13 inches Adverse)
Align RH pumps suction to CNMT sumps Place SVAG valve C/Ss to close Check RH pumps 1B RH pump - RUNNING 1A RH pump tripped (PTL)
Check CNMT sump isolation valves 1SI8811A - OPEN 1SI8811B - CLOSED - go to attachment A, step 1.
CREW Note: If RWST level drops < 9% during manual realignment of ECCS pumps to containment sump, any pump taking suction from RWST should be stopped, unless a suction flowpath also exists from the containment sump.
BOP/
[CT]
ES-1.3--
Check if 1A RH pump needs to be aligned to CNMT sump 1SI8811A - OPEN CLOSE 1SI8812A Check if 1B RH pump needs to be aligned to CNMT sump 1SI8811B - CLOSED Check train B recirc flowpath from CNMT sump available 1B RH pump - RUNNING 1SI8811B - energized Manually align 1B RH Pump suction to the containment sump.
Place 1B RH pump in PULL OUT
Scenario No:
NRC 13-4 Event No.
9 Event
==
Description:==
1SI8811B fail to auto open.
Time Position Applicants Actions or Behavior A
(Also see next page)
Close 1SI8812B Place 1B CS pump in PULL OUT Close 1CS001B Open 1SI8811B Start 1B RH pump Open 1CS001B Restart 1B CS pump (manually actuate CS/Phase B)
Check at least one CNMT sump recirc flowpath established 1B RH pump - RUNNING 1SI8811B - OPEN Return to 1BwEP ES-1.3, step 3.d ATC
/BOP Check SI and Cent Chg Pumps in ECCS Injection Mode:
SI Pumps - Both RUNNING or Cent Chg pumps to cold legs injection isolation valves - 1SI8801A & B - OPEN ATC
/BOP
[CT]
ES-1.3 -
- A Align SI and Cent Chg Pumps for Cold Leg Recirculation:
Verify CENT CHG pump miniflow isolation valves:
1CV8111-CLOSED 1CV8114-CLOSED 1CV8110- CLOSED 1CV8116-CLOSED Close SI pump miniflow isol valves:
o 1SI8814 & 1SI8920, or o 1SI8813 Close RH HX discharge crosstie valves:
1RH8716A 1RH8716B Open SI and CENT CHG pumps suction header crosstie valves:
1SI8807A and/or B o 1SI8924 (already OPEN)
Check RH pump 1A - TRIPPED Check RH pump 1B - RUNNING Open RH HX to SI pumps isol valve 1SI8804B Evaluators Note: The scenario may be terminated at this point.
(Final)
WC-AA-111 Revision 4 Page 25 of 61 ATTACHMENT 10 SURVEILLANCE WO DISPOSITION SHEET (APPLICABLE TO MID-WEST SITES ONLY)
Page 1 of 1 Unit: _1__
Procedure:
PMID/RQ: ______
1BwOS FW-W1____
123456____ Work Order #: __ N/A PMID/RQ
Title:
PMID/RQ Due Date: ___
UNIT 1 TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE N/A________ PMID/RQ Late Date: N/A Signature/Authorization Approval Review: Name Date Shift Authorization to Start Work:
Time
_Joe Supervisor ______ Today Work Started 2 hrs ago Work Stopped:
Supv Review of Work Completion:
ANI Review of work package:
Surveillance Found Within Acceptance Criteria YES NO Surveillance Left Within Acceptance Criteria YES NO (Work Started date (above shall be Complete one of the following:
the credit date unless otherwise explained)
Verify Credit Surveillance Credit Date per another WO# ______________
Below:
If crediting per another WO, verify credit date is Work Started date of referenced WO.
Complete Sat - Credit Surveillance Complete w/ Portions Unsat - Credit Surveillance No Work Performed - Credit Surveillance Failed - Do Not Credit (Surv Due/Late Dates will NOT advance)
No Work Performed - Do Not Credit (Surv Due/Late Dates will NOT advance)
Comments _____________________________________________
ADDITIONAL REVIEW OF RESULTS (IF REQUIRED)
Title Signature Date
WC-AA-111 Revision 4 Page 25 of 61
1BwOS FW-W1 Revision 7 Reference Use 1
UNIT 1 1B & 1C TURBINE DRIVEN MAIN FEEDWATER PUMP STOP VALVE SURVEILLANCE A.
STATEMENT OF APPLICABILITY This procedure verifies operability of the High and Low Pressure Stop Valves by stroking the High Pressure valve full closed and the Low Pressure valve partially closed, when either or both Turbine Driven Main Feedwater Pumps are in operation.
B.
REFERENCES 1.
Station Drawing: M-35-6, Diagram of Main Steam.
2.
Vendor Manual - Westinghouse Feed Pump Turbine Manual.
C.
PREREQUISITES 1.
Receive permission from the Shift Manager or designee prior to performing this surveillance by having the Data Package Cover Sheet Signed and Dated.
2.
This surveillance can only be performed when the Feedwater Pump(s) are in operation.
D.
PRECAUTIONS 1.
Watch the Main Feedwater Pump RPM when performing this surveillance to verify the test does not result in tripping the pump.
2.
If conditions permit, a second feedwater pump should be in operation during this test.
E.
LIMITATIONS AND ACTIONS 1.
The HP stop valves cannot be tested when the Main Feedwater Pump is being driven by HP steam. An interlock prevents the valve from being closed.
2.
This procedure applies to both 1B & 1C Turbine Driven Main Feedwater Pumps and will normally be performed in its entirety. The Shift Manager may elect to perform only those steps, which are applicable for re-testing purposes.
1BwOS FW-W1 Revision 7 Reference Use 2
F.
MAIN BODY NOTE If any stop valve on an operating Feedwater Pump can not be tested, the Shift Manager or designee will record the untested valve and the reason for not testing it in the comments section of data sheet D-2. Record N/A in the appropriate places on data sheet D-2.
1.
RECORD time and date on Data Sheet D-2.
2.
DEPRESS the Left L.P. Stop Valve Test pushbutton located on the Turbine Driven Main Feedwater Pump control panel on 1PM04J for the associated pump to be tested.
3.
OBSERVE that the Left L.P. Stop Valve Open lamp goes OUT and CHECK YES in the appropriate place on Data Sheet D-2.
NOTE The Stop valve will stroke 25%. The test button will illuminate when the stop valve has traveled its 25% test stroke. The Stop valve will automatically stroke back open when it has reached its 25% test stroke.
4.
OBSERVE that the Left L.P. Stop Valve Test button ILLUMINATES when the valve has stroked 25% and CHECK YES in the appropriate place on Data Sheet D-2.
5.
OBSERVE that the Left L.P. Stop Valve Open button ILLUMINATES when the valve has stroked back OPEN and CHECK YES in the appropriate place on Data Sheet D-2.
6.
IF the Turbine Driven Main Feedwater Pump is being driven by high pressure steam, NOTE in Comment section of Data Sheet and PROCEED to step 13.
1BwOS FW-W1 Revision 7 Reference Use 3
NOTE The High Pressure Stop Valve will stroke Full Closed. When the High Pressure Stop valve is Full Closed, the valve will stroke back open.
F.
7.
DEPRESS the High Press Stop Valve Test pushbutton located on the Turbine Driven Main Feedwater Pump control panel on 1PM04J for the associated pump to be tested.
8.
OBSERVE that the High Press Stop Valve Open light goes OUT and CHECK YES in the appropriate place on Data Sheet D-2.
9.
OBSERVE that the High Press Stop Valve closed button ILLUMINATES when the Stop Valve is FULL CLOSED and CHECK YES in the appropriate place on Data Sheet D-2.
10.
OBSERVE that the High Press Stop Valve Test button ILLUMINATES when the Stop Valve is FULL CLOSED and CHECK YES in the appropriate place on Data Sheet D-2.
11.
OBSERVE that the High Press Stop Valve Closed button goes OUT when the Stop Valve starts to stroke back open.
12.
OBSERVE that the High Press Stop Valve Open button ILLUMINATES when the Stop Valve is FULL OPEN and CHECK YES in the appropriate place on Data Sheet D-2.
13.
IF more than one Turbine Driven Main Feedwater Pump is running, repeat steps F.2-12 for the other pump. IF not, RECORD N/A in the appropriate place on Data Sheet D-2.
1BwOS FW-W1 Revision 7 Reference Use 4
G.
ACCEPTANCE CRITERIA 1.
For each pump tested:
a.
The LP Stop Valve Test Button illuminates, indicating the valve has traveled 25% in the CLOSED direction.
b.
The HP Stop Valve Closed Button illuminates, indicating the valve has traveled to the full closed position (N/A if the pump is operating on HP steam).
OR 2.
A Condition Report and Action Request is written for any stop valve that does not stroke as expected.
(Final)
1BwOS FW-W1 Revision 7 Reference Use D-2 UNIT 1 MAIN FEEDWATER TURBINE DRIVEN PUMP STOP VALVE SURVEILLANCE DATA SHEET F.1.
TIME:
DATE:
ACTUAL REQUIRED 1B FEED PUMP (N/A if not running) 3.
Left L.P. Stop Valve Open Button OUT Yes No N/A YES 4.
Left L.P. Stop Valve Test Button ON Yes No N/A YES 5.
Left L.P. Stop Valve Open Button ON Yes No N/A YES 8.
High Press Stop Valve Open Button OUT Yes No N/A YES 9.
High Press Stop Valve Closed Button ON Yes No N/A YES 10.
High Press Stop Valve Test Button ON Yes No N/A YES 12.
High Press Stop Valve Open Button ON Yes No N/A YES 1C FEED PUMP (N/A if not running) 3.
Left L.P. Stop Valve Open Button OUT Yes No N/A YES 4.
Left L.P. Stop Valve Test Button ON Yes No N/A YES 5.
Left L.P. Stop Valve Open Button ON Yes No N/A YES 8.
High Press Stop Valve Open Button OUT Yes No N/A YES 9.
High Press Stop Valve Closed Button ON Yes No N/A YES 10.
High Press Stop Valve Test Button ON Yes No N/A YES 12.
High Press Stop Valve Open Button ON Yes No N/A YES Comments:
(Final)
NRC 13-sp Simulation Facility Braidwood Scenario No.:
NRC 13-sp Operating Test No.: 2013-1 Examiners:
Applicant:
SRO ATC BOP Initial Conditions:
IC-18 Turnover: Unit 1 is operating at 75% power, steady state, equilibrium xenon. 1B CW PP is OOS for motor inspection. Following completion of turnover, the crew is to perform 1BwOS EH-M1, UNIT 1 PUMP OPERABILITY SURVEILLANCE using the preferred method of depressing and holding the MCB pushbutton. The Equipment Operator has been briefed and is standing by at the Unit 1 EH skid. TSO has requested Unit 1 prepare to raise turbine load to full power at maximum allowable rate due to grid demand following the surveillance.
Event No.
Malf. No.
Event Type Event Description Preload IOR ZDI1CW01PB PTL MRF ED093B OPEN IMF FW44 IMF RP15D MRF RP84 OPEN trgset 1 ZLO52BRKA(2)== 1 IMF CV01B (1 0) trg 1 IMF FW19C 3.5 0 10 MRF RP56 OUT 1B CW PP OOS 1CW001B OOS 1B AF pump fails to start 1B SI pump fails to automatically start 1B CV pump trips when Rx trips Feed line break inside containment when Rx trips Phase A slave failure 1
None N-BOP, US Perform 1BwOS EH-M1.
2 None R-ATC, US Raise power at 0.4 Mw/Min 3
IMF NI08H (500 10)
I-ATC, US TS-US PR NI N-44 fails high 4
IOR ZDI0VC01CA TRIP C-BOP, US TS, US MCR Supply Fan OA Trip 5
IMF CV01A C-ATC, US TS, US 1A CV pump trip 6
IMF RX04E 0 120 I-BOP, US Feed Flow channel 1FT530A fails low 7
IMF ED07A C-ATC, BOP TS-US Loss of bus 141 8
IMF RP09A M
(ALL)
Inadvertent FWI Feed line break inside containment 9
Preload 1B CV pump trip when Rx trips Preload Loss of heat sink (1B AF pp)
- (N)ormal, (R)eactivity (I)nstrument, (C)omponent, (M)ajor Transient
NRC 13-sp Page 2 of 30 SCENARIO OVERVIEW Unit 1 is operating at 75% power, steady state, equilibrium xenon. 1B CW PP is OOS for motor inspection.
Following completion of turnover, the crew is to perform 1BwOS EH-M1, UNIT 1 PUMP OPERABILITY SURVEILLANCE using the preferred method of depressing and holding the MCB pushbutton. The Equipment Operator has been briefed and is standing by at the Unit 1 EH skid. TSO has requested Unit 1 prepare to raise turbine load to full power at maximum allowable rate due to grid demand following the surveillance.
After completing shift turnover and relief, the BOP will perform 1BwOS EH-M1, UNIT 1 PUMP OPERABILITY SURVEILLANCE.
After completing the surveillance, Power Team will request Unit raise turbine load to full power at maximum allowable rate due to grid demand. The crew will commence a power ascension at 0.4 mw/min.
After a measurable change in power, a failure of power range N-44 lower detector will occur. The crew should take actions per 1BwOA INST-1 including defeating the channel functions. Technical Specifications 3.3.1 applies.
After the Power Range failure is addressed, the MCR Supply Fan OA will trip. The crew will send an equipment operator to investigate the cause. Upon receiving the report that local indications are a motor overload, the crew will start the OB VC train as directed by BwAR 0-33-A8 MCR SUP FAN OA TRIP DP HIGH LOW and BwOP VC-1. Technical Specification 3.7.10 condition A is required. The SRO may also decide to enter LCO 3.7.11 Condition A.
After the MCR Supply Fan OA failure is addressed, 1A CV pump will trip. The crew will implement 1BwOA PRI-15, LOSS OF NORMAL CHARGING. The crew will start the 1B CV pump to restore normal charging.
Technical Specifications 3.5.2 condition A and TRM 3.1.d, condition A apply.
After the charging pump failure is addressed, Feed Flow channel 1FT-530A will fail low, resulting in indications of lowering feed flow and opening of 1FW530, 1C S/G Feed Reg Valve to attempt to match feed flow with steam flow. The BOP will diagnose the failure and take manual control of 1FW530 to restore 1C SG level. The US will enter 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL -
Attachment G.
After addressing the failed feed flow channel, a ground fault will occur on bus 141. 1BwOA ELEC-3 will be entered and the operators will start redundant equipment on bus 142 and investigate the status of bus 141.
Tech Spec 3.8.9 applies.
Following completion of 1BwOA ELEC-3 actions, an inadvertent FWI occurs. When the crew manually trips the reactor, a feed line break on the 1C SG inside containment will occur. SI will actuate. The crew will enter 1BwEP-0 to stabilize the plant. The 1B SI pump fails to auto start and must be manually started due to a failure of its actuation relay. The 1B AF pump will not start (engine will seize) resulting in a transition to 1BwFR-H.1 at step 15 of 1BwEP-0. The 1B CV pump trips when the reactor trips. Bleed and feed will be required due to the status of the CV pumps.
Completion criteria is establishing startup feedwater pump flow to the non-faulted SGs.
Critical Tasks
- 1. Manually close 1CV 8112 prior to the PRT rupturing in containment.
(ERG Critical Task number - E - 0) (K/A number 103000A2.03 3.5/3.8)
- 2. Initiate RCS bleed and feed before attempting to establish main feedwater flow or condensate flow to any SG (ERG Critical Task number - FR-H.1--F) (K/A number 000E05EA1.1 importance 4.1/4.0)
NRC 13-sp Page 3 of 30 SIMULATOR SETUP GUIDE:
Verify/perform TQ-BR-201-0113, BRAIDWOOD TRAINING DEPARTMENT SIMULATOR EXAMINATION SECURITY ACTIONS CHECKLIST.
Establish the conditions of IC-18, 75% power, steady state, equilibrium xenon.
Verify/place OA/OC VA plenums in service.
Place the OB VC train in STANDBY and place the OA VC train IN SERVICE.
Complete items on Simulator Ready for Training Checklist.
Verify/remove any Equipment Status Tags and Danger Tags not applicable to the scenario.
Place simulator in RUN (allow simulator to run during board walk down and turnover).
Place 1B CW pump C/S in PTL, after 1CW001B is full closed, then run CAE.
Run caep NRC 13-sp SETUP from disk and verify the following actuate:
IOR ZDI1CW01PB PTL MRF ED093B OPEN IMF FW44 IMF RP15D MRF RP84 OPEN trgset 1 ZLO52BRKA(2)== 1 IMF CV01B (1 0) trg 1 IMF FW19C 3.5 0 10 MRF RP56 OUT Provide students with turnover sheets and 1BwOS NR-1.
NRC 13-sp Page 4 of 30 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 1: Perform 1BwOS EH-M1.
When requested, as Equipment Operator report you are standing by at the Unit 1 EH skid. Report the following data as EH pumps are started and stopped:
EH system temperature is 110°F.
EH system pressure is 1970 psig with ONE EH pump running.
If requested, as Field Supervisor report you are providing direct supervision in the field for production risk.
Acknowledge as Shift Manager commencement and completion of procedure.
Events 2: Raise power at 0.4 MW/min.
As Power Team, contact the MCR by phone and request Unit 1 raise MW to full power at maximum allowable rate due to grid demand.
Acknowledge as chemistry/rad protection requests for RCS samples (if required).
Acknowledge as Power Team initiation of ramp.
Event 3: Power range N-44 fails high.
Insert IMF NI08H 500 10 Acknowledge as SM entry into TS 3.3.1 conditions A, D & E.
Acknowledge as SM request for writing IR, performing risk assessment and making appropriate notifications.
As SM, if requested support for tripping bistables in AEER, report that AEER bistables are not to be tripped until work analyst and NSO support can be obtained (in approx. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />) and that the abnormal operating procedure should be continued. AEER bistable tripping NOT be conducted.
NRC 13-sp Page 5 of 30 Event 4: MCR Supply Fan OA Trip Insert IOR ZDI0VC01CA TRIP to trip the OA VC Supply Fan.
After the OA VC Supply Fan is off, DELETE the override DOR ZDI0VC01CA.
If dispatched as EO to investigate OA VC Supply Fan trip, report that the motor for the fan is charred with light smoke in the area (no fire).
If the crew directs you to locally start the standby VC train (supply and return fans), acknowledge and then 1 minute later call back and report that the local/remote transfer switch for Supply Fan 0VC01CB is stuck in the REMOTE position and recommend that the crew start the OB VC train from the MCR.
If directed as EO to locally shutdown the OA VC Chiller per BwOP VC-11, then use the following remote functions:
MRF HV03 LOCAL MCR Chiller OA Remote/Local SW to LOCAL MRF HV05 OFF MCR Chiller OA LOCAL ON/OFF SW to OFF Notify the crew that you are ready for them to place the OA VC Chiller Unit Control Switch to AFTER TRIP at 0PM02J.
MRF HV03 REMOTE MCR Chiller OA Remote/Local SW to REMOTE In support of starting the OB VC Chiller provide the following information (BwOP VC-10):
Steps F 1 and 2 complete (Chilled pump suction pressure 30 psig; WO Expansion Tank level 55%, oil level 77%).
You are ready for the crew to perform step F.3 (start of 0WO01PB Chilled Water pump at 0PM02J)
After the OB Chilled Water pump is running:
If directed to locally start the chiller:
o MRF HV06 OFF MCR Chiller OB LOCAL ON/OFF SW to OFF o MRF HV04 LOCAL MCR Chiller OB Remote/Local SW to LOCAL o Contact the MCR to perform steps F.10.c and d (place the OB MCR Chiller OB C/S to AFTER TRIP at 0PM02J, followed by AFTER CLOSE) o MRF HV06 ON MCR Chiller OB LOCAL ON/OFF SW to ON o MRF HV04 REMOTE to restore control of MCR Chiller OB to the MCR o Notify the MCR that you will complete the local steps If the crew remotely starts the OB MCR Chiller, provide reports that you will/have completed local actions as requested Acknowledge as Shift Manager the failure, request for maintenance support, and IR request.
NRC 13-sp Page 6 of 30 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 5: 1A CV pump trip Insert IMF CV01A for 1A CV pump.
If dispatched as Equipment Operator to 1A CV pump and/or pump breaker, wait three minutes and report 1A CV pump appears normal and/or report phase A overcurrent flag at breaker cubicle.
Acknowledge as Shift Manager the failure, LCOAR entry, on line risk assessment, EAL evaluation, request for maintenance support, and IR request.
Event 6: Feed flow channel 1FT-530 fails low Insert IMF RX04E 0 120 As SM, acknowledge the failure, requests for on line risk assessment, maintenance support, and IR initiation.
Event 7: Loss of bus 141 Insert IMF ED07A If dispatched as EO to bus 141 report acrid smell in Div. 11 ESF switchgear room but no fire. Ground overcurrent flag on breaker 1412.
Acknowledge as SM request for E-plan evaluation, Tech Spec 3.8.9 entry for unit 1, and 3.8.1 for both units request for on line risk assessment. (on line risk will be red)
Acknowledge Tech Spec 3.8.4 entry and exit.
Acknowledge request for U-2 admin NSO to perform 1/2BwOSR 3.8.1.1 If requested as FS/EO to cross-tie 125 VDC bus 111 to 125 VDC bus 211 wait five minutes and insert the following:
MRF ED111 CLOSE If dispatched as EO to depress 1A DG emergency stop push button insert the following:
MRF EG19 TRIP
NRC 13-sp Page 7 of 30 INSTRUCTOR/SIMULATOR RUN AID GUIDE Event 8: Inadvertent Feed Water Isolation Insert IMF RP09A Event 9: Feed line break in containment / Loss of Heat Sink/CV pump trip Acknowledge as SM procedure changes, E Plan evaluations, and STA request.
After STA requested, as STA report CSF status - Red path on heat sink (until feed flow established). Yellow on heat sink once feed flow established, Yellow on inventory when head voids due to bleed and feed.
If dispatched as EO, report 1B CV pump has phase C overcurrent flag.
If dispatched as EO, report 1B AF pump has large lube oil leak and engine damage.
Acknowledge as U2 NSO request to remove FW isolation fuses insert the following:
MRF FW150 REMOVED MRF FW151 REMOVED MRF RP78 REMOVED MRF RP79 REMOVED To locally close 1AF005C:
MRF FW173 0 20 (20 second ramp)
Acknowledge as EO start startup FW pump aux oil pump and insert the following:
MRF FW149 START Acknowledge request as EO to close containment isolation valves.
MRF CH11 0 to close 1WO006A MRF CH13 0 to close 1WO020A MRF CV17 0 to close 1CV8100 NOTE: remote function RP56 causes a slave relay failure preventing the following phase A valves from closing automatically:
1CV8112 (Key because the other CIV in this flowpath will not close due to loss of power) 1CV8160 (fails closed on loss of Instrument Air to Containment) 1PR01B 1FP010 1PS229A 1PS229B
Comments:
NRC13-sp Page 8 of 30 Scenario No:
NRC 13-sp Event No.
1 Event
==
Description:==
Perform 1BwOS EH-M1 Time Position Applicants Actions or Behavior CUE o From turnover, perform 1BwOS EH-M1, UNIT 1 PUMP OPERABILITY SURVEILLANCE.
US Direct BOP to perform 1BwOS EH-M1.
- Refer to 1BwOS EH-M1.
- Record initial data on Data Sheet D-2.
- Notify Equipment Operator at EH skid of pending 1B EH pump start
- At 1PM02J, depress EH PP LO PRESS AUTO START TEST (20/MPT) pushbutton.
o Equipment Operator locally verify 1B EH pump started.
- Perform the following at 1PM02J:
- Verify annunciator 1-18-B15, EH SYSTEM TROUBLE, remained clear.
- Place 1B EH pump C/S in AFTER CLOSE.
- Notify Equipment Operator at EH skid of pending 1A EH pump shutdown
- At 1PM02J, place 1A EH pump C/S in AFTER TRIP.
- Equipment Operator locally verify EH pressure 2000 +/- 50 psig.
- Notify Equipment Operator at EH skid of pending 1A EH pump start
- At 1PM02J, depress EH PP LO PRESS AUTO START TEST (20/MPT) pushbutton o Equipment Operator locally verify 1A EH pump started.
- Perform the following at 1PM02J:
- Verify annunciator 1-18-B15, EH SYSTEM TROUBLE, remained clear.
- Place 1A EH pump C/S in AFTER TRIP.
- Equipment Operator locally verify EH pressure 2000 +/- 50 psig.
- Record initial data on Data Sheet D-2.
- Inform US 1BwOS EH-M1 complete.
US
- Acknowledge report.
o Notify SM 1BwOS EH-M1 is complete.
EVALUATOR NOTE: After 1BwOS EH-M1 is complete and with lead examiner concurrence, enter next event.
Comments:
NRC13-sp Page 9 of 30 Scenario No:
NRC 13-sp Event No.
2 Event
==
Description:==
Raise power at 0.4 MW/min Time Position Applicants Actions or Behavior CUE o Call from Power Team to raise MW to full power at maximum allowable rate.
US Acknowledge request to raise MW to full power at maximum allowable rate.
Implement actions of 1BwGP 100-3.
o Perform pre-job brief per HU-AA-1211 PRE-JOB, HEIGHTENED LEVEL OF AWARENESS, INFREQUENT PLANT ACTIVITY, AND POST JOB BRIEFINGS for load ramp.
US Direct raising load to 100% at 0.4 MW/min.
o Initiate load swing instruction sheet, 1BwGP 100-4T2.
CREW o Review applicable Precautions, and Limitations and Actions. (may have been done in PJB prior to starting demo) o May energize PZR heaters.
ATC o Verify rod position and boron concentration.
Initiate dilution, as required (BwOP CV-5).
o Determine required PW volume from REMA form.
Determine required PW flow rate.
Perform the following at 1PM05J:
o Add PW in dilute/alt dilute mode o Set 1FK-111 PW/Total Flow Cont POT to the desired PW flow rate.
o Set 1FY-0111 PW Control Predet Counter to desired PW volume.
o Place MAKE-UP CONT SWITCH to STOP position.
o Set MODE SELECT to DIL/ALT DIL position.
o Place MAKE-UP CONT Switch to START.
o Verify proper operation of valves and PW makeup pump (1CV111B open, 1CV111A throttled, 1CV110B open (ALT DIL only), PW pump running, PW flow on recorder).
o Open 1CV111B.
o Open 1CV110B.
Comments:
NRC13-sp Page 10 of 30 Scenario No:
NRC 13-sp Event No.
2 Event
==
Description:==
Raise power at 0.4 MW/min Time Position Applicants Actions or Behavior o Open 1CV111A.
o When desired amount of primary water added:
o Close 1CV111A.
o Verify/Close 1CV111B.
o Verify/Close 1CV110B.
BOP Raise turbine load at 1PM02J or OWS drop 210 by performing the following:
Select SETPOINT.
Enter desired MW into REF DEMAND window.
Select ENTER.
Enter 0.4 MW/min into the RATE window.
Select ENTER.
Select EXIT.
o Notify US and RO of pending ramp.
Select GO/HOLD.
Verify GO/HOLD button illuminates.
Verify HOLD illuminated RED.
Select GO.
Verify GO illuminates RED.
Verify main turbine load begins to rise.
ATC/
BOP Monitor reactor power and load ascension:
Monitor NIs, Tave, I, Pzr press/level at 1PM05J or PPC.
Monitor MW and DEHC system response at 1PM02J or OWS drop 210.
During dilution, monitor the following at 1PM05J or PPC:
VCT level.
RCS Tave rising.
o PW/Total flow predet counter responding correctly.
o Verify dilution auto stops at preset value.
o Return Reactor Makeup System to automatic.
o Perform periodic control rod steps to maintain Tave and Delta I within boundaries.
After measurable change in power and lead examiner approves, initiate the next event.
Comments:
NRC13-sp Page 11 of 30 Scenario No:
NRC 13-sp Event No.
3 Event
==
Description:==
Power range N-44 fails high.
Time Position Applicants Actions or Behavior CUE Annunciator PWR RNG FLUX RATE RX TRIP ALERT (1-10-C3)
Annunciator PWR RNG CHANNEL DEV (1-10-C4)
Annunciator PWR RNG LOWER DET FLUX DEV HIGH (1-10-B4)
Control rod inward motion ATC/
BOP Determine PR channel N-44 failing high Place control rods in manual o Reference BwARs as time permits CREW Identify entry conditions for 1BwOA INST-1, NUCLEAR INSTRUMENTATION MALFUNCTION US Implement 1BwOA INST-1, NUCLEAR INSTRUMENTATION MALFUNCTION, Attachment A "PR CHANNEL FAILURE" and direct operator action Notify SM of PR N-44 failure o Notify SM to evaluate for E-plan o Orders ramp placed on hold (per OP-AA-300 step 4.6.12)
ATC/
BOP Check rod control status Rod bank select switch in manual
- Check for rod stop Annunciator PWR RNG FLUX HIGH ROD STOP (1-10-B5) - LIT Place rod stop bypass switch to N-44 at 1PM07J ATC
- Verify/restore TAVE - TREF to within 1°F o Withdraw control rods o Adjust RCS boron concentration o Adjust turbine load BOP Check SG levels normal and stable BOP Bypass/defeat PR channel functions at 1PM07J N-44 upper current comparator N-44 lower current comparator N-44 power mismatch bypass o
N-44 rod stop bypass
Comments:
NRC13-sp Page 12 of 30 Scenario No:
NRC 13-sp Event No.
3 Event
==
Description:==
Power range N-44 fails high.
Time Position Applicants Actions or Behavior N-44 channel current comparator BOP Reset flux rate trip alarm for N44 ATC/
BOP Place computer points in test N0047 N0048 U1143 Place computer point in delete from scan N0052A Place N44 input to DEH in Test BOP Remove control power fuses on PR N-44 to trip bistables ATC Select operable channel (other than 1D) to loop T recorder Check if rod control can be placed in auto C-5 not lit TAVE - TREF within 1°F Place control rods in auto US Determines TS 3.3.1 conditions A, D, and E are applicable.
o Enter/exit TS 3.4.1 if pressurizer pressure dropped below 2209 psig during auto rod steps Contact SM to perform risk assessment, initiate IR, evaluate reactivity screening, make notifications and contact appropriate personnel to investigate/correct instrument failure.
NOTE: After the actions for N-44 are complete and with lead examiner concurrence, enter next event. Ensure rods are back in auto prior to inserting the next event.
Comments:
NRC13-sp Page 13 of 30 Scenario No:
NRC 13-sp Event No.
4 Event
==
Description:==
MCR Supply Fan OA Trip Time Position Applicants Actions or Behavior CUE Annunciator 0-33-A8 MCR SUP FAN OA TRIP P HIGH LOW "
Annunciator 0-33-A9MCR RTRN FAN OA TRIP P HIGH LOW BOP Recognize OA VC Supply Fan and Return Fan tripped.
Reference associated BwARs o Check SER Send EO to locally investigate Start Standby VC train per BwAR and US direction US Direct BOP to address annunciators o Check SER for cause Determines LCO 3.7.10 condition A applies o May enter LCO 3.7.11 Condition A Direct BOP to start standby train of VC (and associated VC Chiller) per BwOP VC-10 and BwOP VC-1 (secure the OA VC Chiller per BwOP VC-11)
NOTE: The procedure allows for locally starting the standby VC train. If directed as such, the EO will report back that the local/remote transfer switch is stuck in remote so the crew MUST start the standby train from the MCR.
NOTE: If/when BOP decides to address completing a shutdown of the tripped VC train see steps on the next page.
BOP Refer to BwOP VC-1 STARTUP OF CONTROL ROOM HVAC SYSTEM PRESS both Train A and B MCR isol Reset switches at 1PM06J Check status of 0RT-PR033/34 Ensures Makeup Filter Fan Isolation and Bypass Dampers Control Switch in NORMAL TB position on 0PM01J (already in position -- NOTE: due to recent HELB modification the BwOP may require placing the switch in AUTO)
START 0VC01CB MCR Supply Fan OB START 0VC02CB MCR Return Fan Verify 0VC282Y and 0VC16Y MCR Outside Air Dampers shift to OPEN Verify 0VC172Y MCR Supply Air Damper shifts to OPEN Verify 0VC01Y, MCR Return Ari Fan Inlet Damper shifts to OPEN Verifies MCR differential pressure is > 0.125 inches w.c.
Refers to BwOP VC-11 to shut down the OA VC Chiller
Comments:
NRC13-sp Page 14 of 30 Scenario No:
NRC 13-sp Event No.
4 Event
==
Description:==
MCR Supply Fan OA Trip Time Position Applicants Actions or Behavior Places Control Room Chiller OA Control switch to AFTER TRIP Refers to BwOP VC-10 to start the OB Chiller After directing EO to perform local checks, STARTs 0WO01PB MCR Chilled Water Pump at 0PM02J o IF the BOP starts the chiller from the MCR, the BOP will place the OB VC Chiller Control Switch to AFTER CLOSE at 0PM02J and direct the EO to perform the rest of the local verifications in the procedure.
o IF the BOP directs the EO to locally start the OB VC Chiller, then the EO will take local control of the Chiller, the BOP will cycle the OB VC Chiller switch to AFTER TRIP then to AFTER CLOSE. The EO will then LOCALLY initiate the Chiller start sequence and transfer control back to the MCR.
The OB Chiller will start approximately a minute after the start signal is initiated.
BOP o Refer to BwOP VC-2, SHUTDOWN OF CONTROL ROOM HVAC SYSTEM for Train A (tripped) VC.(NOTE: the procedure allows two different combinations of steps to perform this: F.1 through F.11 then F.14 and F.15 to remotely shutdown the train.
Otherwise steps F.1 through F.4 then F.12 through F.15).
(F.1) Directs EO to shutdown Electrical OA per BwOP VC-9.
(F.2) Directs EO to place C/S to OFF at 0VC13J for CR Heating Coil OA.
(F.3) Depresses Train A and B MCR Isol Reset switches on 1PM06J.
(F.4) Check status of 0RT-PR031/32 (Train A) and 0RT-PR033/34 (Train B)
(F.5) Place C/S for 0VC03CA in AFTER STOP at 0PM02J.
(F.6) Verify intake dampers 0VC025Y/09y and 0VC312Y/313Y indicate CLOSED (F.7) STOP MCR Return Fan 0A at 0PM02J by placing the C/S in AFTER STOP.
(F.8) STOP MCR Supply Fan (tripped) 0A at 0PM02J by placing the C/S in AFTER STOP.
(F.9) Verify 0VC017Y, MCR Return Fan Inlet Damper indicates CLOSED.
(F,10) Verify MCR Outside Air Dampers 0VC32Y/282Y and 0VC281Y/16Y indicate CLOSED.
(F.11) Verify 0VC033Y MCR Supply Damper indicates CLOSED.
(F.12) Directs EO to shutdown M/U Filter Fan 0VC03CA locally.
(F.13) Directs EO to shutdown MCR HVAC Supply and Return fans locally.
(F.14) Coordinates with EO to shutdown VC chilled water per BwOP VC-11.
(F.15) N/A (applies if BOTH VC trains are to remain shutdown)
Comments:
NRC13-sp Page 15 of 30 Scenario No:
NRC 13-sp Event No.
4 Event
==
Description:==
MCR Supply Fan OA Trip Time Position Applicants Actions or Behavior NOTE: After the actions for the OA VC Supply Fan trip are complete, and with lead examiner concurrence, enter next event.
Comments:
NRC13-sp Page 16 of 30 Scenario No:
NRC 13-sp Event No.
5 Event
==
Description:==
1A CV pump trip.
Time Position Applicants Actions or Behavior CUE
- Annunciator 1-9-A3 CHG PUMP TRIP
- Annunciator 1-9-D3 CHG LINE FLOW HIGH/LOW
- Annunciator 1-7-B2 RCP SEAL WATER INJ FLOW LOW
- Annunciator 1-9-A1 REGEN HX LTDWN TEMP HIGH
- PZR level lowering.
- Trip/yellow disagreement light on 1A CV pump C/S.
ATC Identify 1A CV pump has tripped at 1PM05J.
Report failure to US.
o May isolate letdown per BwAR by closing 1CV8149A/B/C and 1CV459/460 CREW
- Reference BwARs as time permits.
o Identify entry conditions for 1BwOA PRI-15, LOSS OF NORMAL CHARGING.
- Dispatch operator to investigate cause of 1A CV pump trip.
o Place unit ramp on hold.
NOTE: The crew may elect to start the stand-by CV pump using Immediate Actions of BwAR 1-9-A3 OR by entering 1BwOA PRI-15. The required actions for each method are described below.
ATC IF crew chooses to use BwAR 1-9-A3 to start 1A CV pump, required actions begin here.
o Determine NO indications of gas binding of tripped pump.
o NO fluctuation of pump amps prior to trip.
o NO fluctuation of pump discharge flow prior to trip.
o NO fluctuation of charging flow prior to trip.
- Verify suction source 1CV112B and 1CV112C OPEN
- Verify recirc path 1CV8110 and 1CV8116 OPEN
- Place 1B CV pump C/S to start.
US IF crew chooses to enter 1BwOA PRI-15 to start 1B CV pump, required actions begin here.
Notify Shift Manager of plant status and procedure entry.
Request evaluation of Emergency Plan conditions.
o Implement 1BwOA PRI-15, LOSS OF NORMAL CHARGING, and direct operator
Comments:
NRC13-sp Page 17 of 30 Scenario No:
NRC 13-sp Event No.
5 Event
==
Description:==
1A CV pump trip.
Time Position Applicants Actions or Behavior actions of 1BwOA PRI-15 to establish the following conditions:
o Direct BOP/ATC to stop load ramp/dilution.
o Enter Tech Spec 3.4.1 if PZR pressure < 2209 psig.
ATC Perform the following at 1PM05J:
Check CV pump status:
Identify NEITHER CV pump is running Place 1A CV pump C/S in PULL OUT.
Isolate normal letdown:
Place 1CV8149A, B, & C, letdown orifice isolation valves, C/Ss to CLOSE.
Place 1CV459 & 1CV460, letdown isolation valves, C/Ss to CLOSE.
Check VCT status:
Check 1CV112B & 1CV112C, VCT suction valves, OPEN.
Maintain VCT level greater than 20%.
Check VCT level > 20% on 1LI-112 or 1LR-185.
Operate RMCS in automatic or manual to maintain VCT level > 20%.
Check annunciator 1-9-C2, VCT TEMP HIGH - NOT lit.
ATC/
BOP Perform the following at 1PM05J:
o Acknowledge RM-11 alarm caused by isolating flow to 1PR06J, Gross Failed Fuel Monitor.
Check for gas binding of previously running CV pump by verifying the following trends NOT fluctuating prior to pump trip (may use PPC trends):
RCP #1 seal leak off flows.
CV pump flow.
CV pump discharge pressure.
CV pump amps.
Restore normal charging flow:
Check 1CV8110 & 1CV8116, 1B CV pump miniflow isolation valves - OPEN.
Check RCS pressure approximately 2235 psig.
Place 1B CV pump C/S to start.
Check CV System Alignment:
Verify 1CV8147, charging to RC 1A loop isolation valve - OPEN.
Verify 1CV8324A, charging to regen HX 1A isolation valve - OPEN.
Comments:
NRC13-sp Page 18 of 30 Scenario No:
NRC 13-sp Event No.
5 Event
==
Description:==
1A CV pump trip.
Time Position Applicants Actions or Behavior Verify 1CV8105 AND 1CV8106, charging line CNMT isolation valves - OPEN.
Check charging flow established (Charging flow may be at minimum for RCP seal injection due to letdown isolation).
Determine normal letdown is isolated.
o Monitor RMCS during automatic VCT makeup:
Proper flow indicated on PW/Total Flow (1FT-0111) and Boric Acid Flow (1FT-0110).
CREW
- Identify entry conditions for 1BwOA ESP-2, REESTABLISHING CV LETDOWN DURING ABNORMAL CONDITIONS.
US o Notify Shift Manager of plant status and procedure entry.
Implement 1BwOA ESP-2, REESTABLISHING CV LETDOWN DURING ABNORMAL CONDITIONS, and direct operator actions of 1BwOA ESP-2 to establish the following conditions:
BOP Perform the following at 1PM05J (1BwOA ESP-2):
Check letdown Isolated:
Verify 1CV8149A, B, & C, letdown orifice isolation valves - CLOSED.
Verify 1CV459 & 1CV460, letdown isolation valves - CLOSED.
Check letdown flow path:
Verify 1CV8401A, letdown to letdown HX 1A isolation valve, - OPEN.
Verify 1CV8324A, charging to regen HX 1A isolation valve - OPEN.
Verify 1CV8389A, letdown to regen HX 1A isolation valve - OPEN.
Verify 1CV8152 & 1CV8160, letdown line CNMT isolation valves - OPEN.
Verify BTRS mode select switch OFF light - LIT.
Align letdown controllers:
Place 1PK-131, letdown line pressure controller, in MANUAL and raise demand to 40%.
Place 1CC130A, letdown HX outlet temperature controller, in MANUAL and raise demand to 60%.
Verify charging flow established:
Verify 1CV8105 AND 1CV8106, charging line CNMT isolation valves - OPEN Adjust 1CV182, charging header backpressure control valve, to establish 8-13 gpm
Comments:
NRC13-sp Page 19 of 30 Scenario No:
NRC 13-sp Event No.
5 Event
==
Description:==
1A CV pump trip.
Time Position Applicants Actions or Behavior RCP seal injection flow.
Place 1FK-121, in manual and operate 1FK-121 in manual to establish 100 gpm charging flow on 1FI-121A.
Establish letdown flow:
Place 1CV459 & 1CV460, letdown isolation valves, C/Ss to OPEN.
Place 1CV8149A, B, & C, letdown orifice isolation valves, C/Ss to OPEN as necessary to establish 120 gpm letdown flow.
Lower demand on 1PK-131, letdown line pressure controller, to raise letdown pressure to approximately 360 psig on 1PI-131.
Operate 1FK-121 in manual to restore PZR level to normal operating band and maintain 8-13 gpm RCP seal injection flow.
Lower demand on 1CC130A, to control letdown temperature between 90° to 115°F on 1TI-130.
Place 1PK-131, letdown line pressure controller, in AUTO.
Place 1CC130A, letdown HX outlet temperature controller, in AUTO.
At the RM-11, verify 1PR06J cursor is GREEN.
US Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
Determine TS 3.5.2, condition A is applicable.
LCO 3.5.5 condition A is applicable.
Determine TRM 3.1.d, condition A is applicable.
EVALUATOR NOTE: After the actions for charging pump trip are complete and with lead examiner concurrence, enter next event.
Comments:
NRC13-sp Page 20 of 30 Scenario No:
NRC 13-sp Event No.
6 Event
==
Description:==
Feed flow channel 1FT-530 fails low Time Position Applicants Actions or Behavior CUE Annunciator SG 1C FLOW MISMATCH FW FLOW LOW (1-15-C4)
Annunciator SG 1C LEVEL DEVIATION HIGH/LOW (1-15-C9) 1C SG NR levels rising FW flow rising on 1FI-531 BOP
- Identify/report failure of 1FT-530
- Take manual control to restore SG level
- Place 1FK-530 in manual and lower demand prior to receiving P14 turbine trip/FW isolation.
- Refer to BwARs CREW Identify entry conditions for 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Enter/Implement 1BwOA INST-2, OPERATION WITH A FAILED INSTRUMENT CHANNEL, Attachment G FEEDWATER FLOW CHANNEL FAILURE and direct operator actions of 1BwOA INST-2 to establish the following conditions.
o Direct BOP/RO to stop load ramp/dilution BOP Restore 1C SG level to 60%
Control 1FW530 in manual Select operable FW flow channel Place FW flow select switch to F-531 position (may be done per BwAR response)
Establish automatic level control Place 1FK-530 in auto when SG level restored to normal Check Reactor power <100%
10 min. calorimetric NIs Check HD system operation 1HD046A & B position normal
Comments:
NRC13-sp Page 21 of 30 Scenario No:
NRC 13-sp Event No.
6 Event
==
Description:==
Feed flow channel 1FT-530 fails low Time Position Applicants Actions or Behavior US
- Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure, and make other notifications.
The next event is to be inserted following the above actions by the US and Lead Examiner concurrence
Comments:
NRC13-sp Page 22 of 30 Scenario No:
NRC 13-sp Event No.
7 Event
==
Description:==
Loss of bus 141 Time Position Applicants Actions or Behavior CUE Annunciator (1-21-A7) "BUS 141 FD BRKR 1412 TRIP" Annunciator (1-21-C7) "BUS 141 OVERLOAD OR VOLT LOW" Annunciator (1-21-C8) "DG 1A TROUBLE/FAIL TO START" Bus 141 bus alive light not lit CREW Determine Bus 141 De-energized.
Reference BwARs Identify entry conditions for 1BwOA ELEC-3 "LOSS OF 4KV ESF BUS" US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Implement 1BwOA ELEC-3 "LOSS OF 4KV ESF BUS" to establish the following conditions:
Determines TS 3.8.9 condition A is applicable.
Contact SM to perform risk assessment, initiate IR, and contact maintenance to investigate/correct instrument failure.
ATC/
BOP US Ensure the following B train equipment started/running o 1B CV pump o 1B CC pump 1B SX pump o 1B/D RCFCs o 0B VC train Isolate bus 141 by placing the following breakers in PTL:
o ACB 1413 FIRST, then:
o ACB 1411, 1412, 1414 Bus 141 lockout alarm (1-21-A7) LIT 111 Batt Chrg trouble alarm (1-21-E8) LIT Dispatch operator to crosstie ESF DC Bus 111 with ESF DC Bus 211 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Refer to Tech Specs (US)
Perform 1BwOSR 3.8.1.1 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Unit 2 contacted to perform 2BwOSR 3.8.1.1 w/i 1 hr Review Tech Specs 3.8.1, 3.8.9
Comments:
NRC13-sp Page 23 of 30 Scenario No:
NRC 13-sp Event No.
7 Event
==
Description:==
Loss of bus 141 Time Position Applicants Actions or Behavior o Review Tech Spec 3.8.4 (US may point out that Unit 2 should enter LCO 3.8.4 condition B)
Operator dispatched to emergency trip 1A D/G Dispatch operators to locally investigate bus 141 NOTE: At this point, if the crew has started train B loads, with bus 141 faulted and the US having reviewed Tech Specs, it is suggested that the scenario continue with the next event with concurrence of the lead examiner.
Comments:
NRC13-sp Page 24 of 30 Scenario No:
NRC 13-sp Event No.
8 Event
==
Description:==
Inadvertent FWI & Feed line break inside containment Time Position Applicants Actions or Behavior CUE Annunciator (1-15-E7) "FWIV NOT FULL OPEN" FWI monitor lights - ALL lit CREW Recognize FWI and conditions requiring a manual reactor trip.
US Direct a manual Rx trip Implement 1BwEP-0 "REACTOR TRIP OR SI" Direct operator actions of 1BwEP-0 to establish the following conditions:
ATC Perform immediate operator actions of 1BwEP-0 at 1PM05J:
Verify reactor trip.
Rod bottom lights - ALL LIT.
Reactor trip & Bypass breakers - OPEN.
Neutron flux - DROPPING.
BOP Perform immediate operator actions of 1BwEP-0 at 1PM02J or OWS drop 210:
Verify Turbine Trip.
All Turbine throttle valves - CLOSED.
All Turbine governor valves - CLOSED.
BOP Perform immediate operator actions of 1BwEP-0 at 1PM01J:
Verify power to 4KV busses.
Bus 141 deenergized Bus 142 energized CREW (If manual SI not previously performed) Recognize and respond to conditions requiring a Safety Injection in accordance with 1BwEP-0 REACTOR TRIP OR SAFETY INJECTION, Step 4:
Check SI status o SI First OUT annunciator - NONE LIT o SI ACTUATED Permissive Light - NOT LIT o SI Equipment - AUTOMATICALLY ACTUATED o Either SI pumps - RUNNING o Either CV pump to cold leg isolation valve OPEN - 1SI8801A/B Manually actuate SI from 1PM05J and 1PM06J 1C SG pressure cannot be maintained > 640 psig.
Manually actuate SI from 1PM05J and 1PM06J.
1BwFR-H.1 actions start on page 27
Comments:
NRC13-sp Page 25 of 30 Scenario No:
NRC 13-sp Event No.
9 & 10 Event
==
Description:==
Feed line break inside containment & Loss of heat sink/1B CV pump trip Time Position Applicants Actions or Behavior EVALUATOR NOTE: US and RO will continue in 1BwEP-0 while BOP is performing Attachment B:
EVALUATOR NOTE: Per the OAS page, RCP trip criteria is applicable throughout the performance of 1BwEP-0. The crew may trip RCPs whenever the criteria of RCS pressure <1425 psig AND High head SI flow >100 gpm are recognized.
BOP Verify FW isolated at 1PM04J:
FW pumps - TRIPPED.
Isolation monitor lights - LIT.
FW pumps discharge valves - CLOSED (or going closed) 1FW002A-C.
Verify DGs running at 1PM01J:
DGs - BOTH RUNNING. (1A DG may be emergency tripped) 1SX169A/B OPEN.
Dispatch operator locally to check operation Verify Generator Trip at 1PM01J:
OCB 1-8 and 7-8 open.
PMG output breaker open.
Verify Control Room ventilation aligned for emergency operations at 0PM02J:
VC Rad Monitors - LESS THAN HIGH ALARM SETPOINT. (train A rad monitors de-energized) o Dispatch EO to secure VL, VW and VV supply fans.
Operating VC train equipment - RUNNING.
0B Supply fan 0B Return fan 0B M/U fan 0B Chilled water pump 0B Chiller Operating VC train dampers - ALIGNED.
M/U fan outlet damper - 0VC08Y NOT FULLY CLOSED.
0B VC train M/U filter light - LIT.
0VC09Y - OPEN 0VC313Y - CLOSED
Comments:
NRC13-sp Page 26 of 30 Scenario No:
NRC 13-sp Event No.
9 & 10 Event
==
Description:==
Feed line break inside containment & Loss of heat sink/1B CV pump trip Time Position Applicants Actions or Behavior Operating VC train Charcoal Absorber aligned for train B.
0VC44Y - CLOSED 0VC05Y - OPEN 0VC06Y - OPEN Control Room pressure greater than +0.125 inches water on 0PDI-VC038.
Verify Auxiliary Building ventilation aligned at 0PM02J:
Two inaccessible filter plenums aligned.
Plenum A:
0VA03CB - RUNNING
- 0VA023Y - OPEN
- 0VA436Y - CLOSED
- Plenum C:
0VA03CF RUNNING
- 0VA072Y - OPEN 0VA438Y - CLOSED Verify FHB ventilation aligned at 0PM02J:
- 0VA04CB - RUNNING
- 0VA055Y - OPEN
- 0VA062Y - OPEN 0VA435Y - CLOSED
- Secure all running HD pumps
- Initiate Periodic Checking of Spent Fuel Cooling
CV pumps - NONE RUNNING (1B tripped):
1B RH pump - RUNNING.
SI pump - NONE RUNNING START 1B SI PP RCFCs running in accident mode (1B train ONLY running)
RCFC accident mode status light lit CNMT Phase A valves closed (train A valves not all closed and several train B valves not closed due to slave failure)
Manually actuate Phase A
Comments:
NRC13-sp Page 27 of 30 Scenario No:
NRC 13-sp Event No.
9 & 10 Event
==
Description:==
Feed line break inside containment & Loss of heat sink/1B CV pump trip Time Position Applicants Actions or Behavior
[CT]
E-0--0 Manually close 1CV8112 Dispatch EO to close de-energized valves outside containment Verify Cnmt Vent isolation:
Group 6 Cnmt Vent Isol monitor lights - ALL LIT.
Verify AF system:
AF pumps - Neither RUNNING.
Attempt manual start of 1B AF pump o Dispatch EO to check 1B AF pump AF isolation valves - 1AF13A-H OPEN.
AF flow control valves - 1AF005A-H OPEN.
Verify CC pumps - 1B RUNNING.
Verify SX pumps - 1B RUNNING ATC/
BOP Check if Main Steamline Isolation required 1C S/G pressure < 640 psig CNMT pressure > 8.2 psig MSIV & MSIV bypass valves - CLOSED CREW o Determine and Announce containment is adverse when containment pressure rises above 5 psig.
BOP/
ATC Check CS not required CNMT pressure remained < 20 psig BOP/
AF flow < 500 gpm SG levels < 31%
o May CLOSE 1AF005C & 1AF013G to isolate CST gravity flow to 1C SG FW line break.
CREW Identify entry conditions for 1BwFR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK
Comments:
NRC13-sp Page 28 of 30 Scenario No:
NRC 13-sp Event No.
10 Event
==
Description:==
Feed line break inside containment/loss of heat sink Time Position Applicants Actions or Behavior US Notify SM of plant status and procedure entry Request evaluation of Emergency Plan conditions Request STA evaluation of status trees Enter/Implement 1BwFR-H.1 and direct operator actions of 1BwFR-H.1 to establish the following conditions ATC Check if secondary heat sink is required RCS pressure > intact SG pressure RCS temperature > 350°F ATC Check CV pump status CV pumps - NONE RUNNING STOP all RCPs GO TO step 14 (bleed and feed)
ATC Establish RCS feed path Actuate SI BOP Verify RCS feed path 1B SI pump - RUNNING Group 2 cold leg injection monitor lights required for operating ECCS pumps - LIT ATC
[CT]
FR-H.1-
-F Establish RCS bleed path PORV isolation valves - 1RY8000A deenergized & open, 1RY8000B energized &
open Open BOTH PZR PORVs (1RY455A & 1RY456)
ATC Verify adequate RCS bleed path PZR PORVs - BOTH OPEN PORV isolation valves - BOTH OPEN ATC /
BOP Verify ESF equipment actuations
Comments:
NRC13-sp Page 29 of 30 Scenario No:
NRC 13-sp Event No.
10 Event
==
Description:==
Feed line break inside containment/loss of heat sink Time Position Applicants Actions or Behavior CREW Maintain RCS heat removal Maintain ECCS flow Maintain PZR PORVs - BOTH OPEN BOP Reset SI Reset Cnmt isolations Reset Phase A Restore IA to Cnmt BOP Check if CS should be stopped CS pumps - NONE RUNNING ATC Verify cold leg recirc capability 1B RH pump - RUNNING 1SI8811B - ENERGIZED BOP/
ATC Try to establish AF to at least one SG Check blowdown isolation and sample valves closed
- 1SD005 A-D & 1SD002A-H Review attachment B Check annunciator AF PUMPS SUCT VLVS ARMED (1-3-E7) - NOT LIT Check 1AF004A & B - OPEN Check AF pumps - NONE RUNNING o Dispatch operator to 1B AF pump AF isolation valves - OPEN 1AF13A-H AF flow control valves - THROTTLED/OPEN 1AF005A-H Check AF flow - NOT ESTABLISHED ATC /
BOP Prepare FW system for restoration CD/CB pumps - at least ONE RUNNING Place FW valves in manual at 0% demand 1FW510 - 540
Comments:
NRC13-sp Page 30 of 30 Scenario No:
NRC 13-sp Event No.
10 Event
==
Description:==
Feed line break inside containment/loss of heat sink Time Position Applicants Actions or Behavior 1FW510A - 540A 1FW034A - D ATC /
BOP Defeat FW isolation Dispatch operators to remove FW isolation fuses FW isolation fuses removed
- 1PA27J
- 1PA28J ATC /
BOP Establish main FW flow to at least one SG Open 1FW035A/B/D Check FW pumps available CD/CB pumps - at least TWO RUNNING Check startup FW pump prepared for operation
- Dispatch operator to startup FW pump
- Bus 159 - ENERGIZED
- Locally start aux oil pump
- Open startup FW pump disch valve - 1FW059
- Open startup FW pump recirc valve - 1FW076 (place C/S in modulate)
- Verify close main FW pump recirc valves - 1FW012A, B, & C Start startup FW pump US Review Attachment B prior to initiating FW flow ATC /
BOP Establish main FW flow to at least one SG Throttle 1FW034A/B/D to desired flow rate Maintain hotwell level > 7 inches Check SG WR levels rising Note: The scenario may be terminated at this point (final)
WC-AA-111 Revision 4 Page 25 of 61 ATTACHMENT 10 SURVEILLANCE WO DISPOSITION SHEET (APPLICABLE TO MID-WEST SITES ONLY)
Page 1 of 1 Unit: _1__
Procedure:
PMID/RQ: ______
1BwOS EH-M1_
123456____ Work Order #: __ N/A PMID/RQ
Title:
PMID/RQ Due Date: ___
UNIT ONE PUMP OPERABILITY SURVEILLANCE N/A________ PMID/RQ Late Date: N/A Signature/Authorization Approval Review: Name Date Shift Authorization to Start Work:
Time
_Joe Supervisor ______ Today Work Started 1 HR ago Work Stopped:
Supv Review of Work Completion:
ANI Review of work package:
Surveillance Found Within Acceptance Criteria YES NO Surveillance Left Within Acceptance Criteria YES NO (Work Started date (above shall be Complete one of the following:
the credit date unless otherwise explained)
Verify Credit Surveillance Credit Date per another WO# ______________
Below:
If crediting per another WO, verify credit date is Work Started date of referenced WO.
Complete Sat - Credit Surveillance Complete w/ Portions Unsat - Credit Surveillance No Work Performed - Credit Surveillance Failed - Do Not Credit (Surv Due/Late Dates will NOT advance)
No Work Performed - Do Not Credit (Surv Due/Late Dates will NOT advance)
Comments _____________________________________________
ADDITIONAL REVIEW OF RESULTS (IF REQUIRED)
Title Signature Date
WC-AA-111 Revision 4 Page 25 of 61
PROCEDURE 1BwOS EH-M1 BRAIDWOOD STATION UNIT NO.
1 REVISION NO.
9 PROCEDURE TITLE:
UNIT ONE PUMP OPERABILITY SURVEILLANCE Rev Summary IR# / EC# (if applicable) 8 Add computer point number for temperature reading (doesnt impact ops)
PCRA 1243112-02 9
Add step: Verify discharge pressure of standby pump approximately 2000 psig on 1PI-EH021/022 prior to shutdown of running pump (F.12)
PCRA 13134522-02
1BwOS EH-M1 Revision 9 Continuous Use 1
UNIT ONE PUMP OPERABILITY SURVEILLANCE A.
STATEMENT OF APPLICABILITY This procedure establishes the steps necessary for performing the Electro-Hydraulic (EH) Stdby Pump Operability Test during reactor Startup (MODE 2) and as scheduled thereafter during power (MODE 1) operations or as necessary in any MODE.
B.
REFERENCES 1.
Station Procedures:
a.
BwOP EH-1, Start-up of the EH Fluid System b.
BwOP EH-6, Transfer of the EH Pumps 2.
Station Drawings:
a.
20E-1-4026B b.
20E-1-4030EH01, 2 c.
M-152, Diagram Turb/Gen EH Fluid, Sheet 2B C.
PREREQUISITES 1.
This surveillance is required prior to rolling the Main Turbine during reactor startup and monthly thereafter if at power (MODE 1).
2.
Receive permission from the Shift Manager or designated licensed assistant prior to performing this surveillance by having the Data Package Cover Sheet signed and dated.
3.
The EH system is operating at normal temp. (90F) and normal pressure (2000 50 psig).
4.
Dispatch operator to local EH skid to monitor the pump and system pressure after auto PP starts (1PI-EH021: 1EH01PA, 1PI-EH022: 1EH01PB, 1PI-EH023:
System Pressure).
1BwOS EH-M1 Revision 9 Continuous Use 2
D.
PRECAUTIONS 1.
Turbine trip can result by reducing the pressure in the EH system.
2.
Fyrquel EHC is extremely caustic and must be handled as follows:
If spattered in eyes, on hands, or other exposed skin, flush area for 15 to 30 minutes with a gentle stream of cool, clean water. For inhalation of vapors, move to fresh air. NOTIFY Shift Manager and immediately seek medical attention if eye, skin, respiratory irritation, or breathing becomes difficult.
If spilled on clothing, rinse thoroughly with water and remove clothing.
NOTIFY Shift Manager or designee if the skin was affected.
If spilled on any surface, clean in accordance with approved Station Chemical Spill Procedures.
E.
LIMITATIONS AND ACTIONS In the event the pump auto starts at a pressure less than 1600 psig during the performance of this surveillance, notify the Shift Manager to initiate corrective actions.
1BwOS EH-M1 Revision 9 Continuous Use 3
F.
MAIN BODY 1.
ENTER the running and stdby pump on the Data Sheet.
2.
RECORD system temperature on the Data Sheet and VERIFY greater than or equal to 90F per 1TI-EH8001 or T0300.
¢ 3.
RECORD system pressure on the Data Sheet and VERIFY it is approximately 2000 50 psig per 1PI-EH023.
4.
On the Data Sheet MARK the appropriate plant evolution that requires this surveillance. If this surveillance is NOT being performed in MODE 1, VERIFY BwOP EH-1 is complete.
NOTE This surveillance is only required in MODES 1 and 2.
5.
ENTER the method to be used for this test. Two methods can be used to test the stdby pump auto start. The preferred method is from the Main Control Board. The backup method is locally at the EH skid using 1EH5090 Drain Isolation Vlv for 1PS-EH004 (63/MP). For the backup method substitute for the TEST pushbutton by MANUALLY OPENING and CLOSING 1EH5090 at the skid for stdby pump start.
6.
NOTIFY the operator at the EH skid of the pending stdby pump start. He should verify the stdby pump start.
CAUTION If the EH Sys Trouble Annunciator (1-18-B15) alarms during Step F.7., Release the test pushbutton.
7.
Auto start the Standby EH Pp by performing one of the following:
DEPRESS the EH Pp LO PRESS AUTO START TEST (20/MPT) pushbutton.
MANUALLY OPEN and CLOSE 1EH5090 as necessary to obtain an AUTO start of the stdby pump.
¢ 8.
VERIFY locally the stdby pump auto starts. INDICATE auto start by YES or NO on Data Sheet.
¢ 9.
VERIFY the EH SYS TROUBLE annunciator (1-18-B15) SER point 1143 (EH Sys Low Press 1350 psig) remained clear. INDICATE alarm remained clear by YES or NO on Data Sheet.
10.
PLACE the stdby EH Pp (as noted in Step F.1.) CONTROL switch in AFTER CLOSE.
1BwOS EH-M1 Revision 9 Continuous Use 4
F.
11.
NOTIFY the operator at the EH skid of the pending shutdown of running pump.
12.
VERIFY Discharge Pressure of Standby Pump approximately 2000 psig on 1PI-EH021/22.
13.
PLACE the Running EH Pp (as noted in Step F.1.) CONTROL switch to AFTER TRIP. This is now the stdby pump.
14.
OBTAIN confirmation locally that the EH pump is maintaining system pressure at approximately 2000 50 psig (ADJUST if necessary per BwOP EH-6).
15.
NOTIFY the operator at the EH skid of the pending stdby pump start. He should verify the stdby pump start.
CAUTION If the EH Sys Trouble Annunciator (1-18-B15) alarms during Step F.16., Release the test pushbutton.
16.
Auto start the Standby EH Pp by performing one of the following:
DEPRESS the EH Pp LO PRESS AUTO START TEST (20/MPT) pushbutton.
MANUALLY OPEN and CLOSE 1EH5090 as necessary to obtain an AUTO start of the stdby pump.
¢ 17.
VERIFY locally the stdby pump auto starts. INDICATE auto start by YES or NO on Data Sheet.
¢ 18.
VERIFY the EH SYS TROUBLE annunciator (1-18-B15) SER point 1143 (EH Sys Low Press 1350 psig) remained clear. INDICATE alarm remained clear by YES or NO on Data Sheet.
19.
PLACE the stdby pump to AFTER-TRIP.
¢ 20.
OBTAIN confirmation locally that the EH pump is maintaining system pressure at approximately 2000 50 psig (ADJUST if necessary per BwOP EH-6).
RECORD acceptable pressure on Data Sheet.
21.
On the Data Sheet ENTER the running and the stdby pumps, NOTING they should be opposite the ones listed in Step F.1.
1BwOS EH-M1 Revision 9 Continuous Use 5
G.
ACCEPTANCE CRITERIA The standby pump auto starts with the absence of EH Sys Trouble Alarm (Annunciator 1-18-B15) point 1143, EH Sys Low Press, and delivers system pressure of approximately 2000 50 psig (EH pump pressure compensator operation).
(Final)
1BwOS EH-M1 Revision 9 Continuous Use D-2 EH PUMP OPERABILITY SURVEILLANCE DATA SHEET 1.
Running Pp ____________________
Standby Pp 2.
EH Temp 3.
EH Press
¢___________________ approx. 2000 +/- 50 psig 4.
Plant Conditions a.
During at POWER (MODE 1) operations.
b.
Reactor Startup (MODE 2) prior to rolling the Main Turbine, VERIFY BwOP EH-1, is complete.
c.
EH System Testing in any MODE, VERIFY BwOP EH-1 is complete.
5.
TEST METHOD a.
20/MPT (1EH5029) Solenoid Valve b.
Local (1EH5090) Manual Valve 20.
EH Press
¢___________________ approx. 2000 +/- 50 psig 21.
- Running Pp ____________________
Standby Pump ___________________
Running and Standby Pumps in Step 21 should be opposite Running and Standby Pumps in Step 1.
(Final)
EH PUMP 1A Autostart from STBY condition
¢ YES NO EH Sys Trouble Alarm (SER point 1143) Remained Clear.
¢ YES NO EH PUMP 1B Autostart from STBY condition
¢ YES NO EH Sys Trouble Alarm (SER point 1143) Remained Clear.
¢ YES NO