ML22059B045
| ML22059B045 | |
| Person / Time | |
|---|---|
| Site: | Millstone  |
| Issue date: | 01/21/2022 |
| From: | Forrestt W Dominion Energy Nuclear Connecticut |
| To: | Brian Fuller Operations Branch I |
| Shared Package | |
| ML21321A323 | List: |
| References | |
| EPID L-2022-OLL-0039 | |
| Download: ML22059B045 (34) | |
Text
Simulator Guide Page 5 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
Facility: Millstone 3. Scenario No.: 2K21 NRC-0 5 (Rev 0). Op -Test No.: 2K 21.
Examiners:. Operators:.
Initial Conditions: IC -99, 100% Power, Beginning of life, Equilibrium Xe
Turnover: B RHR Pump is tagged out of service.
Critical Tasks: 1. Manually close the B PORV Block Valve by the completion of E-0 Step 12.(CT -10).
1.
Event Malf. Event Event No. No Type* Description 1 MB8B-B08 US TS Breaker trips for 3DAS-P10, containment drain unidentified sump pump
2 RX09C US I,TS Controlling channel of pressurizer pressure fails high RO I causing the pressurizer spray valves to open.
3 FW01 US C Loss of condenser vacuum requiring use of AOP 3559 and RO R subsequent rapid downpower.
BOP C 4 TC01 US C Main Turbine trips on rising condenser vacuum with an RP10A BOP C automatic reactor trip failure. MB7 Reactor trip is RP10B successful.
RP09A 5 MS07A ALL M Loss of secondary heat removal transient causes both MS07B PORVs and S/G Safeties to open. The low set safeties on MS07C all four S/Gs fail to reseat. Four Faulted SGs (E-0, E -2, MS07D ECA-2.1).
6 RC18B US C B PORV fails to re-close and requires manual action to RO C close the associated block valve.
7 SG02A US C A SG Blowdown Isolation Valve sticks open requiring BOP C dispatch and manual closure of alternate valve.
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Simulator Guide Page 6 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
Transient and Event Checklist (used to complete NRC Form ES-301-5)
US (target)
RX 0 (0)
NOR 0 (1*)
I/C 5 (2)
MAJ 1 (1)
TS 2 (2)
- of CTs 2
- For an Exam Set, the ROs and Instant SROs are required one Normal evolution. However, reactivity and normal evolutions may be replaced w/ additional I/C manlfunctions on a one-for -one basis.
Simulator Scenario Quality Checklist (used to complete NRC Form ES-301-4)
Target Quantitative Attributes Actual (Per Scenario; See NUREG 1021 Appendix D)
- 1. Malfunctions after EOP entry (1-2) 2
- 2. Abnormal events (2-4) (typically before major event) 3
- 3. Major transients (1-2) 1
- 4. EOPs entered/requiring substantive actions (1-2) (exclude E-0) 1
- 5. EOP contingencies requiring substantive actions ( 1 pciset) 1 S. Pre -identi ral tasks 2 ) 2
Simulator Guide Page 7 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
Critical Tasks TASK DESCRIPTION TASK # K/A BASIS OF SELECTION
Manually close the B CT-10 EPE 009-EA1.15Source: Westinghouse PWROG-PORV Block Valve by 14043-NP ERG Rev. 3 Based the completion of E-0 (3.9 / 4.1) Critical Tasks Step 12.
Reduce AFW flow to -- AFW 061Failure to control AFW flow rate to 100 gpm per SG by the SGs leads to an unnecessary completion of step 2 of A3.02 and avoidable challenge to RCS ECA-2.1. (4.0 / 4.0) integrity.
Simulator Guide Page 1 of 34 SEG#_2K 21 NRC-05_ Rev ; __0
SITE: Millstone Power Station PROGRAM: Unit 3 ILT COURSE: N/A EXAM TITLE: NRC SIM EXAM 5 EXAM #: 2K21 NRC- 05 Total Time 90 Minutes
Prepared by: W.M. Forrestt Signature on file 12/ 8/2021 Printed Name Developer Signature Date
Reviewed by: J. Go Signature on file 12/9/2021 Printed Name Operations Supervisor Signature Date
Approved by: A. Leone Signature on file 12/13/2021 Printed Name Facility Review Signature Date
Simulator Guide Page 2 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
SUMMARY
OF CHANGES
DATE DESCRIPTION REV/CHANGE 12/2/21 Original issue for re-examination. 0 / 0
Simulator Guide Page 3 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
TABLE OF CONTENTS
SECTIONS LISTED IN ORDER
- 1. Cover Page
- 2. Table of Contents
- 3. Exam Overview and Forms
- 4. Exam Guide
Attachment:
- Shift Turnover Report
Simulator Guide Page 4 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
SECTION 3 EXAM OVERVIEW
Title:
Four Faulted SGs
- 1. The crew takes the shift with the plant at 100% power and at beginning of core life. The B Residual Heat Removal (RHR) Pump is tagged out service for an emergent motor oil leak.
Event 1: Breaker trips for 3DAS -P10, containment drain unidentified sump pump.
A Main Board annunciator for loss of control power to 480 Motor Control Centers alarms. The US implements the ARP actions and determines that 3DAS -P10 breaker has tripped. This pump is credited in TS for RCS leakage detection. The US enters the appropriate TS.
Event 2: Controlling channel of pressurizer pressure fails high causing the pressurizer spray valves to open.
RCS*P457 fails high. The RO performs immediate actions per AOP 3581, Immediate Operator Actions. The US transitions to AOP 3571, Instrument Failure Response, to remove the failed channel, place an alternate channel in service, and address Tech Specs.
Event 3:Loss of Condenser Vacuum / Rapid Downpower A loss of condenser vacuum occurs (consistent with a condenser vacuum boot issue). The US implements AOP 3559, Loss of Condenser Vacuum. The leak worsens and the crew is forced to perform an emergency load reduction per AOP 3575, Rapid Downpower.
Event 4:Main Turbine trips with an automatic reactor trip failure.
Automatic Reactor trip is defeated and there is a failure of the MB4 Rx Trip Switch. The BOP Operators will trip the Reactor using the MB7 Rx Trip Switch.
Event 5:Loss of secondary heat removal transient causes both PORVs and S/G Safeties to open. Four Faulted SGs.
The turbine trip (without automatic Rx trip) causes both the PORVs & S/G Safeties to lift. The low set safeties on all four SGs will not re-close (100% failure is inserted on the RX Trip).This ultimately requires the crew to implement ECA-2.1, Uncontrolled Depressurization Of All Steam Generators.
While in ECA-2.1, the crew reduces auxiliary feed flow to 100 gpm per SG (Critical Task).
Event 6: The B PORV fails to re-close.
The US directs closure of the B PORV block valve using the guidance of E -0 (Critical Task).
Event 7:A SG Blowdown Isolation Valve sticks open.
US utilizes ECA-2.1 Attachment B guidance to close an alternate Blowdown isolation valve.
Simulator Guide Page 8 of 34
SEG#_2K 21 NRC-05_ Rev ; __0__
SECTION 4
EXAM GUIDE
All Control Room Conduct, Operations and Communications shall be in accordance with OP-AA -100, Conduct of Operations.
"Review the Simulator Operating Limits (design limits of plant) and the Simulator ModelingLimitations and Anomalous Response List prior to performing this exam scenario on the simulator. The evaluators should be aware if any of these limitations may be exceeded." (NSEM 6.06)
Simulator Guide Page 9 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
INPUT
SUMMARY
RESET SIMULATOR TO IC - 99 Ensure the following is loaded into IC -99 Event Delay Ramp Delete Severity ID Description Trigger Time Time Time Or Value
MALFUNCTIONS
MB8B-B08 MCC LOSS OF CNTRL POWER 1 ON
RX09C PZR PT457 FAIL 2 30 sec. 2500 psia
FW01 LOWERING CONDENSER VACUUM 3 20 sec. 1000 cfm
TC01 TURBINE TRIP 4 30 sec.
TU02F TURBINE HIGH VIB BRG #6 4 8 mils
TU02G TURBINE HIGH VIB BRG #7 4 7 mils
TU02H TURBINE HIGH VIB BRG #8 4 6 mils
RP10A AUTOMATIC REACTOR TRIP TRAIN A FAIL
RP10B AUTOMATIC REACTOR TRIP TRAIN B FAIL
MS07A MS SAFETY VALVE RV22A FAIL 30 100%
MS07B MS SAFETY VALVE RV22B FAIL 30 100%
MS07C MS SAFETY VALVE RV22C FAIL 30 100%
MS07D MS SAFETY VALVE RV22D FAIL 30 100%
RC18B PORV PCV455B FAILS IN OPEN Simulator Guide Page 10 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
INPUT
SUMMARY
RESET SIMULATOR TO IC - 99 Ensure the following is loaded into IC -99 Event Delay Ramp Delete Severity ID Description Trigger Time Time Time Or Value
RP09A REACTOR MANUAL TRIP SWITCH MB4 FAIL
SG02A SG BLOWDOWN ISOL (3BDG*CTV22A) FAILS IN POSITION
MB5D-C07 32-2M ROD CNTL AREA EL 45-6 1 ON
REMOTE FUNCTIONS
WDR04 3DAS P10 CONTROL SWITCH OFF
OVERRIDES
Simulator Guide Page 11 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION
COMPLETE Simulator Setup and Readiness Checklist. N/A SELECT appropriate IC: IC-99 (Password: hickory), 100% power, BOL.
LOAD and RUN applicable Schedule, N/A (part of IC-99)
LOAD event file N/A As necessary, VERIFY the following Initial Malfunctions / I/Os / Remote Functions, as specified on previous Input Summary page.
When the simulator is ready, PLACE to Run and VERIFY the simulator reflects the Initial Conditions for the scenario and is stable.
As necessary, REMOVE the following Equipment from service and tag accordingly:
3RHS*P1B B RHR Pp 1. Ensure in PTL 2. Place a YCT on Control Switch CONDUCT briefing with evaluators. PRE-SCENARIO:
BRIEF the crew i nitial plant conditions and provide a shift turnover.
(All) Walk down control boards and conduct shift briefing.
EVENT 1: Breaker trips for 3DAS-P10, containment drain unidentified sump pump US (TS)
General Note(s):
1.) MB8B 2-8 MCC LOSS OF CNTL PWR alarms. The US implements the ARP and determines that 3DAS -P10 breaker has tripped.
This pump is credited in TS for RCS leakage detection. The US enters the appropriate TS.
2.) If the PEO is requested to reset and close the breaker for DAS -P10, the breaker will immediately trip again.
T= Directed by the Lead Examiner: BOP acknowledges MB8B 2 -8, MCC Loss of Trigger 1 (MB8B-B08) CNTL Pwr.
US enters ARP.
Simulator Guide Page 12 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION OP 3353.MB8B, MCC LOSS OF CNTL PWR (Rev. 13)
As PEO, acknowledge dispatch to BOP goes to MB5 Rear and determines 1. DETERMINE motor control center supplying MCC 32-2M. effected MCC is 32-2M. component with loss of control power by Two minutes later, REPORT The checking the following indications:
breaker for 3DAS-P10, C ontainment PEO is dispatched to AB - 45 ft.
- Annunciator panel MB 5D Drain Unidentified Sump Pump, is in the
- Plant computer tripped position. There is no bypass switch for the alarm.
- 2. Refer To the following and DETERMINE loads causing loss of control power alarm:
There is no alarm bypass switch for the 3. IF component causing alarm is known and, IF load. desired, PLACE affected relay switch to BYPASS to reset loss of control pow er relay alarm.
If dispatched to the LWS panel, report 4. IF no components have lost indicating lights there are no lights for DAS -P10. AND no other means of determining the faulty component exists, SEND Operator to perform the following in coordination with Control Room:
There is no alarm bypass switch for the 5. WHEN cause of loss of control power alarm is load. fixed, RESTORE affected relay switch to appropriate position:
US determines these Tech Specs are not 6. Refer To the following Technical applicable. However, the US should Specifications and DETERMINE Limiting recall that the RCS leakage detection TS Condition for Operation:
is effected (see following)
- T/S 3.8.1.1, A.C. Sources --- Operating
- T/S 3.8.1.2, A.C. Sources --- Shutdown
- T/S 3.8.3.1, Onsite Power Distribution ---
Operating
- T/S 3.8.3.2, Onsite Power Distribution ---
Shutdown
Simulator Guide Page 13 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION This condition should prompt the US to enter the Tech Spec for RCS leakage detection.
Give the US 5 minutes to enter the following TS.
- T/S 3.4.6.1b Action b
After 5 minutes (or completion of TS entry), move onto Event 2.
EVENT 2: Controlling channel of pressurizer pressure fails high causing the pressurizer spray valves to open.
US (TS, I) / RO (I)
General Note(s):
- 1. Controlling channel of pressurizer pressure fails high causing the pressurizer spray valves to open. RCS*P457 fails high. The RO performs immediate actions per AOP 3581. The US transitions to AOP 3571, Instrument Failure Response, to remove the failed channel, place an alternate channel in service, and address Tech Specs.
T= Directed by the Lead Examiner: RO begins immediate operator actions while US Trigger 2 (RX09C) maintains oversight
RO Performs Immediate Operator Actions:
- 1. Announces Taking my IA for PZR Spray Valve(s) Open
- 2. Announces actions taken as he / she is manually adjusting the Master Pressure Controller.
- 3. Announces IA are complete
US Focus Brief entry into AOP 3581
Simulator Guide Page 14 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION AOP 3581, Immediate Actions (Rev 7)
- 1. Using Appropriate Attachment, PERFORM Immediate Actions - Attachment E Pressurizer Spray Valve Open RO adjusts Master Pressure Controller to E. 1. Terminate Pressurizer Spray
~58% to close the spray valves and a. CHECK pressurizer spray valves -BOTH energize the PZR heaters. CLOSED (3RCS*PCV455B & 455C)
RNO: IF Pressurizer Pressure is less than 2270 psia, THEN PLACE Master Pressure Controller in MAN AND ADJUST to GREATER THAN OR EQUAL TO 50% output to maintain Pressurizer Pressure between 2225 psia and 2280 psia.
RCS pressure will be rising under the E.2 Check Pressurizer Spray TERMINATED ROs control. a. CHECK Pressurizer Pressure STABLE OR INCREASING E.3 CHECK Initiating Event INSTRUMENT FAILURE US briefs transition to AOP 3571. E.4 GO TO AOP 3571, Instrument Failure
Response
AOP 3571, Instrument Failure Response (Rev. 17)
US proceeds to Attachment B. 1. PROCEED TO the Appropriate Attachment, AND PERFORM Corrective Actions The Master Pressure Controller has B.1 CHECK PZR PRES (3RCS-PK455A) -
already been placed in manual. IN MAN US directs selecting C hannel 1 for PZR B.2 DEFEAT Failed Channel Input (RCS -
Press Control and recording. PS455F, 455G, & TS411E)
B.3 CHECK PZR Pressure - 2250 psia B.4 PLACE PZR PRES (3RCS-PK455A)
Controller In - AUTOMATIC Simulator Guide Page 15 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION If WW Coordinator is contacted for I&C US marks Channel 3 for bistables. B.5 Trip Associated Reactor Protection support, acknowledge request. However, System Bistable(s) bistables will not be tripped as part of this a. Using Table B.1, PLACE a check mark in the scenario. box above the channel required to be tripped
Allow Examinee ~5 minutes to US enters Tech Specs: b. REFER TO the following Tech Specs for evaluate Tech Specs BEFORE 1. TS 3.3.1 (Rx Trip INSTRU) FU7, FU9, required actions proceeding with the scenario. FU10. All are A ction 6A.
- TS 3.3.1, Reactor Trip System Instrumentation
- TS 3.3.2, Engineered Safety Features Action 20A. Actuation System Instrumentation
- TS 3.3.3.5, Remote Shutdown Instrumentation
- 3. TS 3.3.2.b (ESFAS INSTRU) FU11.
Action 20. c. REFER TO the following Technical
- TRM 3.3.2.1, Engineered Safety Features
- 5. TS 3.2.5.b (DNB - most limiting TS the Actuation System Instrumentation
2 hr Action Statement) (CONDITIONAL:
Applicable IF RCS pressure lowered below 2204 psia)
Yes a Rx trip will not occur when d. CHECK existing bistable status to ensure a bistables are tripped. Reactor trip will NOT occur when the failed channel is tripped Yes RCS*PI457 is not normal. e. CHECK affected channel indication - NOT NORMAL If WW Coordinator is contacted for I&C f. REQUEST I&C use Table B.1 and support, acknowledge request. However, ATTACHMENT S to perform the following:
bistables will not be tripped as part of this 1. PLACE selected Master Test switch in scenario. TEST At the direction of the Lead Examiner, 2. PLACE selected Bistable Switches in proceed to the next event. TEST
Simulator Guide Page 16 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION EVENT 3: Loss of Condenser Vacuum / Rapid Downpower US (C) / RO (R) / BOP (C)
General Note(s):
- 1. This event will cause loss of condenser vacuum of varying amounts (cause will not be disclosed to the crew.. but postulated as condenser vacuum boot issue). At first, the booth operator will hold vacuum under 5 in HgA to allow performing actions in AOP 3559.
After the Lead Examiner is satisfied, vacuum will degrade to force the crew to downpower the unit.
T = Lead Examiner Cue BOP notes rising condenser back pressure.
Trigger 3 (FW01 @ 1000 cfm) US enters AOP 3559.
After condenser backpressure reaches
~4.4 in Hga, Reduce FW01 (74 0 TO 720 cfm) to maintain condenser backpressure below 5 in HgA.
AOP 3559, Loss of Condenser Vacuum (Rev. 13)
If PEOs are dispatched to the Turbine Condenser backpressure is expected to 1. Check if the Reactor Should Be Tripped Building, a cause for the degraded still be below 5 in. HgA. US proceeds to a. CHECK Reactor Power GREATER THAN 3%
vacuum will NOT be given to the crew. step 3. b. CHECK Condenser backpressure LESS THAN 7.5 inches Hg Absolute
- c. CHECK Condenser backpressure LESS THAN 5 inches Hg Absolute
- d. PROCEED TO step 3 Simulator Guide Page 17 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION US will have to balance efforts to identify NOTE: When directed, AOP 3559 is
/ resolve cause of backpressure issue implemented in parallel with AOP 3575, Rapid with requirements to downpower the unit. Downpower. The actions of AOP 3559 are NOT to distract from plant control during AOP 3575.
If called as OMOC (for direction on a Step 3 is a Continuous Action Step that 3. Check If Turbine Load Should Be Reduced downpower), state Absent a turbine either drives a unit downpower if a. CHECK Condenser backpressure GREATER vibration issue, dont downpower until either.condenser backpressure exceeds THAN 5 inches Hg Absolute AND CHECK Main condenser back pressure reaches 5 in 5 in. HgA or Management discretion. Generator output GREATER THAN 389 Mwe HgA. RNO: PROCEED TO Note prior to step 4 AND IF US/SM DETERMINE a turbine Backpressure will be held below 5 in. load reduction is needed to stabilize HgA to allow the crew to implement AOP vacuum, THEN RETURN TO step 3.b.
Maintain condenser backpressure below 3559. Once the Lead Examiner is 5 in. HgA until directed by the Lead satisfied, condenser back pressure will b. PERFORM both of the following:
Examiner. When directed, increasebe increased greater than 5 in HgA. to GO TO AOP 3575, Rapid Downpower, and FW01 to 750 cfm (or more) and have the crew exercise AOP 3575, Rapid LOWER Turbine load AND PROCEED TO the maintain condenser backpressure Downpower. Note prior to Step 4 between 5 and 6.5 in.HgA. AND WHEN one of the following occurs:
- Main Generator output LESS THAN OR EQUAL TO 389 Mwe THEN PERFORM Step 3.c
NOTE: Steps 4 through 11 may be performed in any order.
Simulator Guide Page 18 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION Cause of loss of vacuum will not be Circ Water alignment / conditions are 4. Check Circulating Water System Operation found. found to be normal. a. CHECK Circulating Water Pumps AT LEAST ONE PER CONDENSER RUNNING
- b. CHECK Water Box Outlet Isolation valves for In-Service Water Boxes OPEN
- c. CHECK all Circulating Water pumps -
RUNNING
- d. CHECK the Traveling Screen differential pressure - LESS THAN 12 inches H2O 3ASS-AOV22 is Open. 5. Check Condenser Air Removal Alignment
- a. CHECK STEAM JET AIR EJECTOR AUXILIARY STEAM SUPPLY valve (3ASS-AOV22) - OPEN When requested as PEO, wait 4 5b. Using OP 3329, Condenser Air Removal, minutes and REPORT locally PERFORMthe following:
- 1) Both ejectors in service 1. CHECK BOTH sets of Steam Jet Air Ejectors -
- 2) Two first stage jets in service on each IN SERVICE ejector 2. CHECK TWO First Stage Jets IN SERVICE
- 3) Ejectors not backfiring ON EACH AIR EJECTOR
- 3. CHECK Air Ejectors NOT BACKFIRING
- 4. MAINTAIN Condenser backpressure in the prescribed band determined by the procedure in effect Simulator Guide Page 19 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION 5c. CHECK Gaseous Waste to Millstone Stack Isolation Dampers (3GWS*AOD78A and 3GWS*AOD78B) - OPEN When requested as PEO, wait 4 5d. At Gas Waste Panel minutes and REPORT: (3GWS-PNL01), CHECK Process Vent fans -
3GWS -FN1A is running. ONE RUNNING
- 3GWS-FN1B When requested as PEO, wait 3 5e. Locally, at Turbine Bldg minutes and REPORT: 38 southwest, CHECK Steam Jet Air Ejector Both 3ARC -AOV36A/B are open. Exhaust valves - OPEN
- 3ARC-AOV36A AND
- 6. CHECK Gland Seal Pressure BETWEEN 3 AND 5 PSIG
- 7. Check Auxiliary Steam Pressure In Required Band
- a. CHECK Auxiliary Steam Header Pressure (3ASS-PIC20)(MB6) 140 TO 155 PSIG
- 8. CHECK Condensate Surge Tank Level
- GREATER THAN 21,000 gal
- NOT DECREASING IN AN UNEXPECTED MANNER
- 9. CHECK Exhaust Hood Temperature (175°F)
Annunciators - NOT LIT Simulator Guide Page 20 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION When requested as PEO, wait 4 10. Check For Condenser In-Leakage minutes and REPORT: a. CHECK Condenser Vacuum Breakers (MB7)
Water is visible in each Vacuum (VAC BKRS 3ARC-MOV20A-B-C) - CLOSED Breaker. b. At Turbine Bldg 60 west, locally CHECK Vacuum Breaker Loop Seals - FILLED
- c. Locally CHECK for NO unusual noises indicative of air in-leakage
- d. CHECK Seal Water Supply Pressure Annunciator EXT STM NRV SEAL PRES LO (30 psig) (MB6A 3-6B) - NOT LIT
- e. CONTACT Engineering to assist in locally checking condenser penetrations for air in-leakage If requested as OMOC, REPORT: Crew recognizes Condenser backpressure Downpower the unit to 75% power at 3% exceeds 5 inHgA.
/ min. US implements Step 3 to initiate a down power.
AOP 3575, Rapid Downpower (Rev. 28)
US works with crew (& OMOC) to 1. Determine The Following:
determine downpower to 75% at 3% / REFER to ATTACHMENT H to min. using a canned Rx plan (RE-H -07). determine the following:
Attachment H yields a final desired MWE Final desired MWE: ___________
of 933 MW with a Load Set indicated Load Set Indicated MWe Setting:
Mwe setting of 1070 MWe. ____________
Final desired Rx Pwr: __________
- 2. CHECK Rod Control - IN AUTO Continue to Modify FW01 to maintain BOP aligns for Load Set. 3. Align EHC Panel backpressure between a. CHECK Load reduction using Load Set -
5-6.5 in HgA. DESIRED
- b. Using ATTACHMENT E, ALIGN EHC Panel for Load Set operation
Simulator Guide Page 21 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION OMOC recommended 3% per min. 4. Determine Power Reduction Rate (% / min)
- a. CHECK power reduction rate - 3%/min or 5%/min
RO initiates rapid boration. 5. Initiate Rapid Boration
- g. CHECK RCS Makeup System in - AUTO
- h. START ONE Boric Acid Transfer Pump
- BA PP A
- BA PP B
i.OPEN Emergency Boration Valve, (3CHS*MV8104)
j.CHECK direct Boric Acid flow (3CHS -
FI183A) - INDICATED
5k. RECORD time boration started
5l. ADJUST Charging Line Flow Control Valve, as necessary, to establish net charging flow matched or exceeding Boric Acid flow
5m. RNO: PROCEED TO step 7 AND WHEN boration has been performed for the calculated time, THEN using ATTACHMENT G, STOP boration Simulator Guide Page 22 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION Rapid boration is in progress. BOP 7. Initiate Load Reduction selects 3% minute and adjusts load set to a. CHECK Turbine OPERATING 1070 MWe. MODE - MANUAL
- b. CHECK load reduction-USING LOAD SET
- c. SELECT LOAD RATE LIMIT %/MIN (1%/MIN, 3%/MIN, or 5%/MIN)
- d. CHECK Lowering Turbine Load -
IMMEDIATELY REQUIRED
- e. REFER to ATTACHMENT H AND Using the LOAD SELECTOR pushbuttons, ADJUST LOAD SET to Load Set Indicated MWe setting recorded in step 1 Examiner Note: When Lead Examiner is 7f. ENERGIZE ALL PZR Heaters satisfied with downpower, cue Booth to move onto Event 4. 7g. ADJUST PZR Spray Valves to 50%
setpoint 3RCS-PK 455B 3RCS-PK 455C 7h. MAINTAIN plant parameters values as listed in ATTACHMENT C OR as directed by Operations Management
Acknowledge ISO-NE communication Yes. 7i. CHECK power reduction - ISO-NE and request MP3 maintain 100 MVARs REQUESTED out (+/- 20 MVARs)
RNO: NOTIFY ISO-NE of load reduction rate (MWe/min) and final MWe level.
Simulator Guide Page 23 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION 7 j. CHECK using either of the following to reduce turbine load:
- Load Limit
- Standby Load Set
US determines rods are above RIL 8. Check Rod Position Above RIL
Examiner Note: When Lead Examiner is (US) satisfied with downpower, cue Booth to 9. Monitor Downpower move onto Event 4. a. CHECK the following-REMAINS UNCHANGED
- Final desired MWe load
- Final desired target power level
- Boron injection path
- b. PROCEED TO step 9 EVENT 4: Main Turbine trips with an automatic reactor trip failure.US (C) / BOP (C)
EVENT 5: Loss of secondary heat removal transient causes both PORVs and S/G Safeties to open. Four Faulted SGs. ALL (M)
EVENT 6: B PORV Fails to Re-Close US (C) / RO (C)
General Note(s):
1.) Trigger 4 will cause high turbine vibrations followed by a Main Turbine trip (30 seconds later ). Automatic Rx trip is defeated and there is a failure of the MB4 Rx Trip Switch. The MB7 Rx Trip Switch will work. (Event 4) 2.) The turbine trip (without an automatic Rx trip) causes both the PORVs & S/G Safeties to lift. The low set safeties on all four SGs will not re-close (100% failure will be inputted on the RX Trip). (Event 5) 3.) The B PORV will fail to re -close. This will require manual closure of the B PORV Block Valve. (Critical Task) (Event 6).
T = Lead Examiner Cue Event 4. Crew recognizes the Main Turbine has tripped Trigger 4 (TC01,TU02F, TU02G, TU02H) without an automatic Rx Trip.
BOP successfully trips the Rx from MB7.
US enters E-0.
Simulator Guide Page 24 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION E-0, REACTOR TRIP OR SAFETY INJECTION (Rev. 35)
BOP has tripped the RX from MB7. 1
- Check Reactor Trip
- CHECK Reactor Trip and Bypass Breakers - OPEN
- CHECK Rod Bottom lights - LIT
- CHECK Neutron Flux - DECREASING 2
- Check Turbine Trip
- a. CHECK all Turbine Stop Valves - CLOSED
Power source is normal - offsite. 3
- Check Power To AC Emergency Busses 3a.CHECK AC Emergency Busses 34C and 34D - BOTH ENERGIZED 3b. Open Phase Condition (OPC) NONE Exists 3c. PROCEED TO step 4.
BOOTH NOTE: Monitor for B PORV SI has auto actuated on low Pressurizer 4
- Check If SI Is Actuated opening. Provided there is a slight delay Pressure (B PORV fails to re-close once 4a. CHECK SAFETY INJECTION ACTUATION (5 sec.) with tripping the Rx (from when opened automatically - RC18B). annunciators, (MB4D 1-6 or MB2B 5-9) - LIT the turbine tripped), the B PORV will automatically open (& fail to close - 4b.By observation of ESF Group 2 Status RC18B). At step 4 pause, RO identifies RCP Trip Panel lights, CHECK both trains of SI -
In the unlikely case that the B PORV Criteria is met and US directs stopping ACTUATED doesnt open, manually INSERT: RCPs.
1.) Remote: RCLO0063 to ON 2.) Malfn RC07B to 80.0
- When B PORV Block Valve is closed later, remove RC07B.
Simulator Guide Page 25 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION CTMT is NOT adverse. 5. DETERMINE IF ADVERSE CTMT CONDITIONS EXIST
- Ctmt temperature - GREATER THAN 180°F OR
- Ctmt radiation - GREATER THAN 10^5 R/ hr RNO: DO NOT USE ADVERSE CTMT parameters RO performs Attachment B. 6. Using ATTACHMENT B, Actuation Signal Verification, CHECK Equipment Alignment
All three AFW pumps are running 7. Check AFW Pumps Running normally. 7a. CHECK MD Pumps - RUNNING
RNO: START pump(s).
7b. CHECK Turbine-Driven Pump - RUNNING IF NECESSARY
- 8. CHECK AFW Valve Alignment - PROPER EMERGENCY ALIGNMENT
- 9. Check Adequate Heat Sink 9a. CHECK NR level in at least one SG -
GREATER THAN 8% (42% ADVERSE CTMT)
RNO: PROCEED TO step 9.d
9d. CHECK Total AFW Flow - GREATER THAN 530 gpm
Simulator Guide Page 26 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION BOP throttles AFW to between 530 - 600 10. Check RCS Temperature gpm. a. Using GA-26, DUMP steam to control No-Load RCS Temperature - AT 557°F
- b. CHECK RCS Temperature - AT NO-LOAD VALUE:
- d. MAINTAIN total feed flow BETWEEN 530 to 600 gpm until NR Level is GREATER THAN 8% (42% ADVERSE CTMT) in at least one SG
- 11. Check Power To SBO Diesel Auxiliaries
- a. CHECK any SBO Bus Tie Breaker -
CLOSED TO AN ENERGIZED BUS
- Bus 34A: 34A1-2
- Bus 34B: 34B1-2
- B: A505 (U Event 6: B PORV is failed open. US 12. Check PZR Valves directs closure of B PORV Block Valve. 12a. CHECK PORVs - CLOSED (Critical Task)
RNO: IF PZR Pressure LESS THAN 2350 psia, THEN CLOSE PORVs.
IF any PORV CANNOT be closed, THEN CLOSE its Block Valve.
Simulator Guide Page 27 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION 12b. CHECK normal PZR Spray Valves -
CLOSED 12c. CHECK PORV Block Valves - AT LEAST ONE ENERGIZED VALVE OPEN RNO: IF NOT closed to isolate an open PORV(s) in step 12.a RNO, THEN OPEN one Block Valve.
12d. CHECK PORV Block Valves - ALL ENERGIZED VALVES OPEN 12e. CHECK PZR Safety Valves - CLOSED
If RCPs werent tripped previously 13. Check If RCPs Should Be Stopped (Foldout Page criteria), RCPs will be a. CHECK RCPs - ANY RUNNING likely stopped here (based on expectant b. CHECK RCS Pressure - LESS RCS pressure). THAN 1500 psia (1800 psia ADVERSE CTMT)
- d. STOP all RCPs
All four S/G safeties failed to re-close. 14. Check If SG Secondary Boundaries US transitions to E-2 based on 4 faulted Are Intact S/Gs. 14a. CHECK pressure in all SGs:
- NO SG PRESSURE LOWERING IN AN UNCONTROLLED MANNER
- NO SG COMPLETELY DEPRESSURIZED
RNO: INITIATE monitoring of CSF Status Trees AND GO TO E-2, Faulted Steam Generator Isolation.
Simulator Guide Page 28 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION E-2, Faulted Steam Generator Isolation (Rev. 15)
MSIV and Bypass valves are closed. 1. CHECK Main Steam Isolation And Bypass Valves - CLOSED 4 faulted SGs. US transitions to ECA-2. Check At Least One SG Secondary Boundary 2.1. Intact
RNO: IF all SG pressures lowering in an uncontrolled manner, THEN GO TO ECA-2.1, Uncontrolled Depressurization of All Steam Generators.
ECA-2.1, Uncontrolled Depressurization Of All Steam Generators (Rev. 21)
CAUTION: If the capability (e.g, open throttled valves or start TD AFW pump stopped in step 1.b) to feed SGs at GREATER THAN 530 gpm is NOT available and Heat Sink status is RED, then the Heat Sink Status color of RED is valid.
CAUTION: If the TD AFW pump is the only available source of feed flow to ANY SG, a steam supply to the TD AFW pump must be maintained from at least one SG.
- 1. Check Secondary Pressure Boundary
CLOSED Simulator Guide Page 29 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION Event 7: A SG Blowdown Isolation 1b. CHECK SG isolation:
Valve failed to isolate (embedded failure
- SG Feed Regulating Valves -CLOSED
- SGO2A). US utilizes RNO (&
- SG Feed Regulating BypassValves -
Attachment B) dispatching a PEO to CLOSED manually close 3BDG-V939.
- FW Isolation Trip Valves -CLOSED
- SG Atmospheric Relief and Bypass Valves - CLOSED
- SG Blowdown Isolation Valves -CLOSED
- SG Blowdown Sample Isolation Valves -
CLOSED
- SG Chemical Feed Isolation Valves -
CLOSED
- Using table, CHECK main steam line drains upstream of MSIVs and TD AFW pump - CLOSED RNO: CLOSE Valves or Isolation Valves.
IF a flow path CANNOT be isolated, THEN using ATTACHMENT B, locally CLOSE valves, one SG at a time.
1c. CHECK MDAFW Pumps:
- 3MSS*MOV17A
- 3MSS*MOV17B
- SS*MOV17D CAUTION: A minimum feed flow of 100 gpm must be maintained to each SG with a NR level LESS THAN 8% (42% ADVERSE CTMT).
Simulator Guide Page 30 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION Critical Task Crew reduces feed flow to 2. Control Feed Flow To Minimize RCS 100 gpm to each SG. Cooldown
- a. CHECK cooldown rate in RCS Cold Legs -
LESS THAN 80°F/hr
RNO: REDUCE feed flow to 100 gpm to each SG AND PROCEED TO step 2.c.
2c. CHECK RCS Hot Leg WR temperatures -
STABLE OR LOWERING RCPs have already been stopped. 3. Check Stopping RCPs
No change is needed in PORV or block 4. Check PZR PORVs And BLOCK Valves valve configuration.
When called as Chemistry, acknowledge RO aligns SG sampling. 5. Check Secondary Radiation chemistry sample request. a. Using GA-30, ALIGN RPCCW for RCS and SG sampling 5b. CHECK trend history and alarm status of radiation monitors Main Steam Line - NORMAL Condenser Air Ejector -NORMAL SG Blowdown - NORMAL 5c. CHECK SG chemistry activity sample results - AVAILABLE RNO: PROCEED TO step 6 AND IF SG sample results indicate Abnormal Radiation, THEN GO TO E-3, Steam Generator Tube Rupture.
Simulator Guide Page 31 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION Conditions are met to stop RHR. The 6. Check Stopping RHR Pumps crew resets SI and stops A RHR Pp (B a. CHECK RHR pumps - ANY RUNNING IN SI is RTO). RCS pressure is rising towards MODE PORV setpoint. b. CHECK RCS pressure GREATER THAN 300 psia (500 psia ADVERSE CTMT)
- d. IF actuated, THEN RESET the following:SI /
- e. STOP RHR pumps and PLACE in AUTO
- f. CHECK RCS pressure - STABLE OR RISING CTMT Spray pumps are NOT running. 7. Check Stopping Containment Spray
- 8. CHECK RWST Level - GREATER THAN 520,000 gal As PEO, acknowledge request to 9. Check Isolating Accumulators implement GA-7. No further action a. CHECK at least two RCS Hot Leg WR needed (session will end before PEO temperatures - LESS THAN 440°F actions are completed).
- b. Using GA-7, ISOLATE SI accumulators Conditions will be met to reduce ECCS 10. Check If ECCS Flow Should Be Reduced flow.
Only CIA requires RESET. 11. Reset Actuated ESF Actuation Signals
- a. RESET SI
- b. RESET the following:
- CIA
- B As PEO, acknowledge request to 12. Restore MCC 32-3T implement GA-1.No further action a. CHECK Emergency Bus 34C ENERGIZED needed (session will end before PEO b. Using GA-1, ENERGIZE MCC 32-3T actions are completed).
Simulator Guide Page 32 of 34 SEG#_2K 21 NRC-05_ Rev : __0 _
SCENARIO TIME LINE BOOTH INSTRUCTOR EXPECTED RESPONSE PROCEDURE INSTRUCTION
- 13. Establish Instrument Air To Ctmt
- a. CHECK Instrument Air Compressors - AT LEAST ONE RUNNING
- b. OPEN Instrument Air CTMT Isolation Valves Upon direction of Lead Examiner, Crew stops one Charging Pump. 14. STOP All But One Charging Pump AND PLACE Simulator in FREEZE PLACE In AUTO
Simulator Guide Page 33 of 34
SEG#_2K 21 NRC-05 Rev : __0__
SHIFT TURNOVER REPORT DATE-TIME PREPARED BY SHIFT Today 0515 Unit Supervisor /NIGHT Shift 18:00 - 06:00 PLANT STATUS:
Mode: 1 Rx Power: 100 %
Megawatts: Thermal: 3641 MWTH PZR Pressure: 2250 psia Electric: 1278 MWe RCS T-AVE: 587 deg F RCS Leakage: Identified: 0.015 gpm Core Burnup: 150 MWD/MTU Unidentified: 0.036 gpm Protected Train/Facility: A (Orange)
Date/Time: Today 0015 Intake: Green Active Tracking Records and Action Statements Equipment/Reason LCO Action Date Time in LCO Action Requirement Time Left B RHR is tagged out TS 3.5.2.d a today 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> Restore 71 hrs
OD Compensatory Actions / Temp Logs Open Date Class Reason Reason Watch Position
PLANT SYSTEMS APC System Notes RHS 3RHS*P1B, B RHR Pump, is tagged out of service for an emergent motor oil leak.
CROSS UNIT SYSTEM STATUS
SURVEILLANCES / EVOLUTIONS IN PROGRESS Steady State Operation I&C has just completed RAKSET 1 Testing - SAT REACTIVITY BRIEFING (SEE REACTIVITY THUMBRULES / SPREAD SHEET FOR ADDITIONAL INFO)
Current Rod Height 216 Xenon Trend Stable Current Boron 1504 Boron Pot Setting / Blend Ratio 4.27 / 17.1 gpm Plant Risk LERF 1.06 ACT: 1 year CDF 4.15 ACT: 46.9 days
Simulator Guide Page 34 of 34
SEG#_2K 21 NRC-05 Rev : __0__
REFERENCE MATERIAL Session No.: NRC-05 Reference No. Revision # Copies
ARPs MB1C 4-3 Rev. 16 1 MB4A 3-4, 4-3, 4-4 Rev. 8 1 MB4C 6-5 Rev. 22 1
MB5A 4-4 Rev. 12 1 MB6A 4-4, 4-5, 4-6 Rev. 18 1 MB6B 4-2 Rev. 6 1 MB8B 2-8 Rev. 13 1 OTHER - RO Station E-0, ATT. B Rev. 35 N/A
OTHER-BOP Station GA-1 Rev. 5 N/A GA-26 Rev. 3 N/A
US Desk Procedures AOP 3559 Rev. 13 N/A
AOP 3571 Rev. 17 N/A AOP 3575 Rev. 28 N/A AOP 3581 Rev. 7 N/A E-0 Rev. 35 N/A
E-2 Rev. 15 N/A ECA-2.1 Rev. 21 N/A