ML12020A221
| ML12020A221 | |
| Person / Time | |
|---|---|
| Site: | Davis Besse  |
| Issue date: | 12/27/2011 |
| From: | Operations Branch III |
| To: | |
| References | |
| Download: ML12020A221 (47) | |
Text
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 1 of 15 FENOC Facsimile Final Facility:
Davis-Besse Scenario No.:
2 Op Test No.:
NRC 2011 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
90% power, MOL AFPT #1 tagged OOS Turnover:
The plant is at 90% power. MFPT #1 has an increasing vibration on the inboard bearing. The previous shift initiated a power reduction to take MFPT #1 out of service for repairs. Continue the power reduction at 1%/minute and remove MFPT
- 1 from service. AFWPT 1 is OOS for Governor work Protected Train 2 Event No.
Malf.
No.
Event Type*
Event Description 1
N-SRO Controlled power reduction R-ATC 2
C-BOP, SRO Increasing vibration on MFPT #1 requiring manual trip 3
C-ATC, SRO ICS AUTO Runback fails 4
I-ATC, SRO Selected Pressurizer temperature element fails low 5
TS-SRO 120VAC Inverter alarm actuates in the control room 6
C-ATC, BOP, TS-SRO OTSG Tube Leak 7
M-ALL MFPT #2 trips 8
M-ALL OTSG tube leak rises to rupture following the reactor trip 9
C-ATC, SRO PZR Spray Valve fails CLOSED during depressurization (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Scenario Event Summary 2011 NRC Scenario 2 NUREG-1021, Revision 9 Supplement 1 Page 2 of 15 FENOC Facsimile Final DAVIS-BESSE 2011 NRC SCENARIO 2 The crew will take the watch with power holding at approximately 90%. The previous shift initiated a power reduction to take MFPT #1 out of service for repairs using DB-OP-02504 Rapid Shutdown. Directions will be to continue the power reduction and remove MFPT #1 from service for repair of an oil leak.
Any time after the power reduction is initiated the Lead Evaluator can cue initiation of rising vibration levels on MFPT #1. The crew should respond to alarm 10-3-A in accordance with DB-OP-02010, FEEDWATER ALARM PANEL 10 ANNUNCIATORS. The Auxiliary Operator (AO) will report a vibration level exceeding the threshold for tripping the pump. The crew should trip MFPT #1, recognize that an AUTO runback did not initiate and then manually runback power to within the capacity of one MFWP.
After power has stabilized, the Lead Evaluator can cue the selected Pressurizer temperature element failing low.. Pressurizer level will indicate low. The RCS make-up valve, MU32, will open. Crew will take MU32 to hand to maintain Pressurizer level where it is at. The crew will determine the failure and select a different Pressurizer temperature element.
After the crew has selected a different Pressurizer temperature element, the Lead Evaluator can cue actuation of alarm 1-6-A, INV YV1-YV-3 TRBL. The crew should respond in accordance with DB-OP-02001, ELECTRICAL DISTRIBUTION ALARM PANEL 1 ANNUNCIATORS, and dispatch an AO to investigate. The AO will report that one of the inverters has shifted to the alternate source. The SRO should request maintenance assistance and/or enter the correct TS.
If necessary, the maintenance supervisor will report an electrical problem that indicates the normal supply cannot be restored until corrective actions are completed.
Any time after the SRO has entered the TS for the 120VAC problem, the Lead Evaluator can cue initiation of the OTSG tube leak. The crew should respond to alarm 9-4-A, Vac Sys Disch Rad Hi, in accordance with DB-OP-02009, PLANT SERVICES ALARM PANEL 9 ANNUNCIATORS, which will direct them to DB-OP-02531, STEAM GENERATOR TUBE LEAK, for actions. The simulator operator will maintain leak rate greater than the TS limit but less than DB-OP-02000 entry. After the crew has recognized the tube leak and/or the SRO is evaluating the tube leak TS, the Lead Evaluator can cue the MFPT #2 trip. This results in a reactor trip and entry into DB-OP-02000. After the crew has entered DB-OP-02000, the OTSG tube leak will ramp to a size below SFAS actuation. Among other actions, the crew will perform the following high level activities: establish HPI piggyback operation, depressurize the RCS using Pressurizer PORV when the Spray Valve fails closed.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
1 Page 3
of 15 Event
Description:
Controlled Power Reduction Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 3 of 15 FENOC Facsimile Final SRO Direct Load Reduction to ~450 MWe at 1%/minute IAW DB-OP-02504, Rapid Shutdown ATC Set ULD to ~55% power and ENTER ATC Set ULD for 1%/min and ENTER CREW Monitor plant parameters On Lead Evaluators discretion, insert Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
2 Page 4
of 15 Event
Description:
ICS AUTO Runback Fails Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 4 of 15 FENOC Facsimile Final Event 2: Increasing Vibrations on MFPT 1 requiring manual trip Indications Available:
10-3-A, MFP 1 or BFP 1 BEARING VIB HI Excessive vibration of MFP 1 Bearings Excessive vibration of MFPT 1 Bearings Excessive vibration of MFPT 1 Gear Reducer Bearings CREW Refer to Annunciator Response DB-OP-02010 BOP Send EO to locally monitor the MAIN FD PUMPS 1 AND 2 VIBRATION PANEL for Gear Reducer, Booster Pump, and Feed Pump vibration.
BOP Obtain vibration reading from ZJR 2538, MAIN TURBINE &
MFP TURBINES - BEARING VIBRATION & ECCENTRICITY, points 11 and 12 for MFPT 1.
SRO/BOP IF vibration amplitude increases and remains above the second setpoint (5.0 mils) AND Maintenance personnel are NOT immediately available to take vibration readings, THEN trip MFPT 1 using HS 797, TURBINE TRIP.
I/F Role Play
- 1. Report that Maintenance personnel are NOT available.
BOP TRIP MFPT #1
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
3 Page 5
of 15 Event
Description:
ICS AUTO Runback Fails Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 5 of 15 FENOC Facsimile Final Event 3: Auto ICS MFP Runback fails Indications Available:
8-4-A, MFPT 1 TRIP 4-3-E, PZR LEVEL HI 14-3-D, ICS MFP LOSS OR LOW DEAR RUNBACK 14-4-C, ICS RX PWR LIMITED BY FEEDWATER IF an ICS Runback occurs THEN REFER to DB-OP-06401, Integrated Control System Operating Procedure. Runback should occur but does NOT.
ATC Places SG/RX DEMAND H/A Station in HAND and initiates runback at 20% power per minute (See Event next page)
Crew may refer to OP-06401 for runback.
ATC/BOP IF the runback was caused by a feed pump trip, THEN perform the following:
ATC IF ICS was NOT in TRACK, THEN verify ICS is or has runback at 20%/minute to 55% power. OTHERWISE place HIC ICS13, SG/RX DEMAND station in HAND AND perform the runback at 20%/minute to 55% power. (ULD DEMAND as read on DAAS=514 Mwe)
ATC IF the pressurizer spray valve was operated, THEN verify RC2, PRESSURIZER SPRAY VALVE is in AUTO AND closed.
ATC/BOP Perform a NIP/HBP comparison for the current power level.
SRO REFER to DB-OP-06902, Power Operations, for guidance to operate plant equipment for the current power level.
On Lead Evaluators discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
4 Page 6
of 15 Event
Description:
Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 6 of 15 FENOC Facsimile Final Event 4: Selected Pzr temperature element (TE), RC15-1, fails low Indications Available:
2-4-C, MU FLOW HI TRN 2 4-2-E, PZR LVL LO CREW Go To DB-OP-02004, RC Alarm Panel 4 Annunciators CREW Refer to DB-OP-02513, Section 4.6.
ATC Place MU32, RCS Makeup valve, in HAND ATC Adjust MU32 to obtain desired Makeup flow or Pzr level ATC Compare Pzr Instrument, identify selected TE has failed ATC Select a good TE ATC Place MU32 in AUTO SRO May review TS 3.4.9, Pressurizer Level. Condition A for high level. Restore level with 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> On Lead Evaluators discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
5 Page 7 of 15 Event
Description:
120VAC Inverter Alarm Actuates in the Control Room Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 7 of 15 FENOC Facsimile Final Event 5: 120 VAC Inverter actions in the CTRM Indications Available:
Annunciator Alarm (1-6-A) INV YVI-YV3 TRBL CREW Refer to Annunciator Response DB-OP-02001 SRO Dispatch EO to inspect Essential Inverters YV1 or YV3 to determine which channel(s) caused the alarm.
I/F Role Play EO reports that the YRF1 input breaker CB1 is open Local Indications: Rectifier AC Power Failure red light is on, Rectifier fans stopped, Fan failure red light on, Inverter Supplying Load yellow light is on, voltage is normal, frequency is normal.
SRO REFER to DB-OP-06319, Instrument AC System Procedure, Emergency Operations Section.
SRO Refer to Technical Specification: 3.8.7, determines YV1 is operable On Lead Evaluators discretion, proceed to Event 6
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
6 Page 8 of 15 Event
Description:
OTSG Tube Leak Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 8 of 15 FENOC Facsimile Final Event 6: SG Tube Leak Indications Available:
9-4-A, VAC SYS DISCH RAD HI 12-1-B, MN STM LINE 2 RAD HI Makeup flow rising PZR level lowering CREW Refer to Annunciator Response DB-OP-02009 and/or 02012 BOP Confirms reading on RE 1003A/B (Vacuum RE), RE600 (Mn Stm Line RE) on CTRM RIM panel SRO GO to DB-OP-02531, Steam Generator Tube Leak, for guidance.
CREW Determine which SG is leaking (SG-2)
CREW Calculate a leak rate using Attachment 1, Steam Generator Tube Leak Rate Calculation. ( ~35 gpm)
SRO Notify Chemistry personnel to perform Attachment 2, Chemistry Personnel Responsibilities.
Notify Radiation Protection personnel to perform Attachment 3, Radiation Protection Personnel Responsibilities.
Perform Attachment 4, Control of Secondary Contamination and Offsite Releases.
CREW Determines SGTL is <50 gpm SRO Refer to TS 3.4.13, RCS Operational Leakage, Condition B
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
6 Page 9 of 15 Event
Description:
OTSG Tube Leak Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 9 of 15 FENOC Facsimile Final SRO Determine a shutdown rate to achieve at a minimum less than 50% within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and be in Mode 3 within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
SRO Refer To DB-OP-02504, Rapid Shutdown ATC At the LOAD CONTROL panel:
- 1. Set the RATE OF CHANGE to a rate specified by the SRO and press ENTER
- 2. Set the Target Load specified by the SRO and press ENTER SRO IF the leak rate calculation exceeds T.S. 3.4.13 limits restore within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SRO Notify the System Control Center (SCC) of the unit load reduction.
SRO As determined by the SRO, reduce unit load IAW DB-OP-02504 by any of the following methods:
On Lead Evaluators discretion, proceed to Event 7, 8, 9
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
7, 8, 9 Page 10 of 15 Event
Description:
Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 10 of 15 FENOC Facsimile Final Event 7, Trip of MFPT 2 (I/F actuated) 8, SGTL increase to a SG Tube Rupture 9, Pzr Spray Valve fails closed during depressurization Indications Available:
8-4-b, MFPT 2 Trip 8-1-A, CRD TRIP CONFIRM SRO Refer TO DB-OP-02000, EOP ATC Manually Trip the Reactor Reactor Trip Pushbutton has been depressed AND Power is decreasing on the Intermediate Range Nuclear Instrumentation ATC Manually trip the Turbine.
Turbine Trip Pushbutton has been depressed AND Turbine Stop Valves 1, 2, 3 AND 4 are closed SRO Implement any necessary Specific Rules BOP SG LEVEL SETPOINTS - May apply. MDFP must be started to feed SG 1 IAW Attachment 5 Enable BOTH MDFP Discharge Valves, HIS 6460 and 6459 Close Both MDFP Discharge Valves, LIC 6460 and 6459 Start MDFP Establish FW flow to SG 1 at less than 1000 gpm
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
7, 8, 9 Page 11 of 15 Event
Description:
Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 11 of 15 FENOC Facsimile Final SRO Implement any necessary Symptom Mitigation Sections Section 8.0 STEAM GENERATOR TUBE RUPTURE -
does apply. SRO will route to Section 8.0, Step 8.19 CRITICAL TASK*
ATC IF HPI piggyback operation is NOT in service, THEN line up and start HPI piggyback operation as follows per Att 8:
- Start the standby CCW Pump.
- Start BOTH HPI Pumps
- Open HPI Injection Valves, HP2A, 2B, 2C, and 2D
- Start BOTH LPI pumps are running
- Open DH64 and DH63
- Transfer MU Pump suctions to the BWST Set Pzr Level Controller to 100
- Verify Standby Makeup Pump is running ATC IF BOTH MU Pumps are running, THEN open MU 6421, CTMT ISOLATION FOR ALTERNATE INJECTION LINE.
ATC Control MU flow using MU 6419 and MU 32 per Specific Rule 3 BOP Verify SG levels are controlled at OR increasing the proper level using Specific Rule 4.
ATC Depressurize the RCS as follows:
Turn off all PZR heaters.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
7, 8, 9 Page 12 of 15 Event
Description:
Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 12 of 15 FENOC Facsimile Final ATC Use Pressurizer Spray to reduce RCS pressure to maintain minimum adequate subcooling margin.
ATC Verify RC 10, PZR SPRAY BLOCK Valve. open ATC Open RC 2, PZR SPRAY Valve (valve does NOT open).
SRO IF Pressurizer Spray is NOT available OR is NOT sufficient to reduce RCS pressure THEN REFER to Step 8.25 for guidance on Depressurizing the RCS without PZR Spray.
ATC Depressurize the RCS as follows:
Turn off all PZR Heaters Start the QT Circ Pump if available Close DR 2012A and DR 2012B, CTMT Normal Sump CTMT Isolation valves ATC Reduce RCS pressure to close to the minimum adequate SCM curve (Fig. 1) using one of the following methods:
PZR Vent Line Method Open RC 200, PZR VENT TO QT ISOLATION Open RC239A, PZR STEAM SPACE SAMPLE Manually Cycle RC239A and Pzr heaters to maintain RCS pressure close to minimum adequate SCM OR PORV method Open RC 11, PORV Block Valve Open RC 2A, PORV Manually cycle the PORV AND control PZR heaters to maintain RCS pressure close to the minimum adequate SCM
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 Scenario #
2 Event #
7, 8, 9 Page 13 of 15 Event
Description:
Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 13 of 15 FENOC Facsimile Final CAUTION:
With the SFAS Low RCS Pressure trips blocked, the operator is responsible for initiating SFAS if the leak rate rises such that PZR level OR RCS pressure can NOT be controlled.
CREW IF SFAS has NOT actuated on Low RCS Pressure, AND if the RCS pressure decrease is being manually controlled with adequate SCM THEN block the SFAS Low RCS Pressure trips when the BLOCK PERMITs come in.
ATC Allow HPI and MU to recover PZR level AND maintain PZR level from 80 to 120 inches by controlling HPI and MU.
SRO Check for entry into PTS criteria. REFER to Specific Rule 5.
CREW Establish a 50°F/hr cooldown rate (limit is <100°F/hr)
BOP IF SFRCS has tripped the AVVs, THEN block the trip and take control as follows:
Place BOTH AVV H/A Stations in HAND Reduce BOTH demands to zero.
Press the AVV BLOCK pushbuttons (HIS-ICS-11D or HIS-ICS-11C).
Press AUTO on HIS-ICS-11B or HIS-ICS-11A Control SG pressure using the H/A Station CRITICAL TASK CREW Depressurize the RCS down to AND maintain close to the minimum adequate subcooling margin limit during RCS cooldown.
Scenario may be terminated when RCS depressurization is in progress
NUREG-1021, Revision 9 Supplement 1 Page 14 of 15 FENOC Facsimile Final INSTRUCTOR FACILITY CUE SHEET\\
2011 SIMULATOR SCENARIO 2 NOTE: Role-play as Maintenance/Work Week Manager/Duty Team as necessary
- 1. Event 2
- a. Report that Maintenance personnel are NOT available.
- 2. Event 5
- a. EO reports that the YRF1 input breaker CB1 is open
- b. Local Indications: Rectifier AC Power Failure red light is on, Rectifier fans stopped, Fan failure red light on, Inverter Supplying Load yellow light is on.
NUREG-1021, Revision 9 Supplement 1 Page 15 of 15 FENOC Facsimile Final 2011 SIMULATOR SCENARIO 2 SETUP
~90% power AFPT 1 OOS for Governor work MFPT 1 has an oil leak Protected Train 2 SETUP ICS - L3M1A, MFP runback failure Tagout AFP 1: SFE8B, closes MS1106 RemoteSFE8A, opens MS106 breaker SFEAB, closes MS106A Remote SFEAA opens MS106A breaker Remote SFE1A, trips AFPT 1 trip throttle valve Event 1 Event 6 SG 2 Tube Leak Lower power to remove MFP 1 from service HH51 from 0.0 to 0.0095 in 300, (~35 gpm)
Event 2, Increasing MFPT 1 vibrations Event 7 Spurious trip of MFP 2 SFFB from 0.01 to 0.85 in 900 on Event 2 SFFA from 0.01 to 0.9 in 600 on Event 2 SFR6C Event 3 Event 8 SG2 Tube Rupture, Spray Valve FC L3M1A, MFP runback failure HH51 to 0.093 increases SG 2 Tube Leak (~300 gpm)
HV00C, RC2 Motor fails close Event 4, Pzr TE fails low H1C1H, TT15-1 RTD short Event 15, After MFPT 1 is tripped, change vibration SFFB from 0.85 to 0 in 900 Event 5 120v inverter failure SFFA from 0.9 to 0 om 900 Remote E601, open breaker to YRF1
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 1 of 17 FENOC Facsimile Final Facility:
DAVIS-BESSE Scenario No.:
3 Op Test No.:
NRC 2011 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
~60% power, 3 Reactor Coolant Pumps (RCP) running RCP 1-1 is not running Low Pressure Injection Pump 1 is out of service Turnover: The crew will assume the watch with the plant at ~60% power. Three RCPs are running. RCP 1-1 was stopped due to low oil level in the lower bearing reservoir. Senior Management is currently deciding when to begin a plant shutdown to repair RCP 1-1. Following turnover the Crew will take action to transfer Gland Steam from Main Steam to Auxiliary Steam in order allow I&C to calibrate the Main Steam Reducer controller. The DB-OP-06205, Gland Steam and Turbine Drains, Section 3.6 prerequistes are complete. Gland Steam pressure is higher than stated in the procedure due to Main Turbine leakoff and has been N/A by the SRO Event No.
Malf.
No.
Event Type*
Event Description 1
N - BOP, SRO Transfer Gland Steam from Main Steam to Auxiliary Steam 2
TS - SRO The crew will be notified that Auxiliary Feedwater Pump 1 has no Governor oil 3
C - BOP SRO Main Seal Oil Pump shaft shear 4
C - ATC, SRO Pressurizer level control valve (MU 32) fails to operate in auto 5
R - ATC N - SRO TS - SRO Control Rod drop 6
I - All Loss of NNI X DC, manual Rx trip required 7
M - All Loss of Offsite AC 8
C - ATC, SRO Emergency Diesel Generator 1 fails to auto start 9
C - BOP, SRO AFW Pump 2 governor valve closes (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 2 of 17 FENOC Facsimile Final DAVIS-BESSE 2011 NRC SIMULATOR SCENARIO 3 The crew will assume control with power at ~60% power and 3 Reactor Coolant Pumps in operation.
After turnover is complete the Lead Evaluator will direct the crew to transfer Gland Steam from Main Steam to Auxiliary Steam.
The Lead Evaluator will cue the Auxiliary Feedwater Pump 1 governor oil problem. The crew should review TS and declare AFW 1 inoperable.
The Lead Evaluator will cue the Seal Oil (SO) Pump shaft shear. The Emergency SO Pump (ESOP) will Auto start, but the Main SO Pump will continue to run. The crew will respond to ESOP Annunciator(s)16-1-H. An EO will be sent to investigate and report a Main SO Pump shaft shear. The BOP will turn off the Main SO Pump.
The Lead Evaluator will cue the dropped rod. The RCS temperature will lower and the Pressurizer level will drop due to the dropped control rod. If Pressurizer level drops to 200 inches alarm 4-2-E, PZR LVL LO will alarm. The MU 32 failure to operate in automatic will be inserted when the rod drops. The crew should identify that MU 32 is not responding. The crew should take MU 32 to HAND and control Pressurizer level by adjusting MU 32 position manually.
For the dropped rod, the crew should enter DB-OP-02516, CRD Malfunctions. The SRO should enter TS. The TS Limit with a dropped rod and 3 RCPs running is 45%
power (320 MWE). The crew should reduce power in accordance with DB-OP-02504, Rapid Shutdown.
The Lead Evaluator will cue the Loss of NNI X DC power during control rod recovery.
Annunciator 14-1-D, NNI-X 24 VDC BUS TRIP, on MSR/ICS Alarm Panel 14 Annunciators will alarm. The crew should enter DB-OP-2532, Loss of NNI/ICS Power.
The crew should recognize a minor transient is in progress due to the mid-scale failure of Turbine Throttle Pressure by transferring the Turbine to MANUAL and transferring the SG/Rx Demand Station to HAND, and lowering the Turbine load.
The Lead Evaluator will cue the Loss of Offsite AC power. The crew will enter DB-OP-02000, RPS, SFAS, SFRCS Trip, or SG Tube Rupture, when the reactor trips.
Emergency Diesel Generator (EDG) 2 will fail to auto start. EDG 2 should be started manually.
The AFPT 2 governor valve will fail closed when AFW Pump 2 receives a start signal.
The crew should respond by entering DB-OP-02000, Section 6, Lack Of Heat Transfer.
The crew should energize non-essential electrical bus D2 from the Station Blackout Diesel Generator or one of the EDGs and align the Motor Driven Feedwater Pump to feed at least one of the Steam Generators.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 3 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 1 Page 3 of 17 Event
Description:
Following turnover the Crew will transfer Gland steam from the Main Steam system to the Auxiliary Steam System in accordance with DB-OP-06205 Section 3.6.
Time Position Applicants Actions or Behavior BOP Verify the 235 psig Aux Steam Header is in service BOP Open AS1934, Aux Steam Supply to 5# Condensate Tank 1-1 Control Valve, for 1 minute and then close AS 1934 BOP Throttle open GS 2385, Steam Seal Feed Bypass, to control Gland Steam pressure at 4.5 psig using HIS 2385 NOTE: GS2385 may be cracked open with OPEN indication BOP Close GS 2384, Seal Steam Supply Valve using HIS 2384 BOP Open GS 2380, Aux Steam Supply Steam Seal Valve, using HIS 2380 BOP Close GS 2385 using HIS 2385 BOP Verify Steam Seal Header pressure is between 2.5 to 4.5 psig At Lead Controllers discretion, proceed to Event 2
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 4 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.: 3 Event No.: 2 Page 4 of 17 Event
Description:
An Equipment Operator will report that AFPT 1 Governor oil sightglass is broken and the oil has leaked out. The SRO should declare AFPT 1 inoperable and entered the AFW Tech Spec Time Position Applicants Actions or Behavior I/F Role Play Call CTRM and report that AFPT 1 Governor oil sight glass is broken and the oil has leaked out.
SRO Determine AFW Pump 1 is inoperable SRO Refer to Tech Spec 3.7.5, Emergency Feedwater, Condition B SRO Notify Operations Management of the unplanned entry into Tech Specs CREW Turn on AFW Blue Light SRO May evaluate Risk - YELLOW At Lead Controllers discretion, proceed to Event 3 and 4
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 5 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.: 3 Event No.: 3 Page 5 of 17 Event
Description:
Main Seal Oil Pump shaft shears Time Position Applicants Actions or Behavior SRO Recognizes Indications 16-1-H ESOP ON 16-2-H Seal Oil P SRO Implements DB-OP-02016 CREW Dispatch an Operator to the Seal Oil Room to Investigate I/F Role Play EO reports that the Main Seal Oil Pump shaft is sheared (If Asked) ESOP parameters are nomal BOP Stop Main Seal Oil Pump At Lead Controllers discretion, proceed to Event 4 and 5
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 6 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 4 & 5 Page 6 of 17 Event
Description:
(4)Regulating Control Rod 5-8 drops, and (5) MU32 does not operate in auto Time Position Applicants Actions or Behavior CREW Recognize a dropped control rod Annunciator 5-1-E, CRD LCO Annunciator 5-2-E, CRD ASYMETRIC ROD Control Rod 5-8 Rod Bottom light ON SRO Implement DB-OP-02516, CRD Malfunctions ATC Reduce Reactor power Reduce ULD Power to ~32% power Set ULD Rate to 3%/MIN SRO Refer to DB-OP-02504, Rapid Shutdown SRO Notify the Load Dispatcher of plant shutdown SRO Contact Chemistry to monitor Condensate Polishers and sample the RCS ATC Maintain Makeup tank level BOP Remove a Main Feed Pump from service Place the ICS controller in HAND and lower speed to 3900 RPM Null the transfer volts using the MDT 20 output Place the MDT 20 control in MANUAL Lower the MDT 20 to the LOW SPEED STOP Trip the MFPT Verify the Discharge NRV is closed
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 7 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 4 & 5 Page 7 of 17 Event
Description:
(4)Regulating Control Rod 5-8 drops, and (5) MU32 does not operate in auto (cont.)
Time Position Applicants Actions or Behavior ATC Reduce Pressurizer set point to 180 inches if necessary Recognize MU 32 is not responding in Automatic control ATC Place MU 32 in HAND in accordance with DB-OP-02512, Makeup and Purification Malfunctions, and manually control Pressurizer level as directed SRO Refer to NG-DB-00230, Reactivity Management SRO Contact Reactor Engineering to determine SDM ATC Contact Work Week Manager/I&C to investigate SRO Refer to DB-OP-02516 Attachment 3 to determine Tech Spec applicability Tech Spec. 3.1.4 for the dropped rod BOP Stop both Heater Drain Pumps At Lead Controllers discretion, proceed to Event 6
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 8 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.: 3 Event No.: 6 Page 8 of 17 Event
Description:
A loss of NNI-X DC power causes a midscale failure of HAND/AUTO stations for MU 32 for Pressurizer level control and MU 19 for Seal Injection flow control.
Turbine Throttle Pressure fails midscale. Most indicators and controls powered by NNI-X DC will automatically transfer to NNI-Y DC powered indicators and control. Manual control of Pressurizer heaters, Pressurizer Spray and Pressurizer level will be required Time Position Applicants Actions or Behavior CREW Recognize a loss of NNI-X DC Power 14-1-D NNI-X 24 VDC BUS TRIP Loss of X-DC NNI Power Indicating Light on Control Room Panel C5722 SRO Implement DB-OP-02532, Loss of NNI/ICS Power ATC If a significant transient occurs, then (1) Trip the Reactor (2) Initiate and Isolate SFRCS using Manual Actuation Switches (3) Go To DB-OP-02000, EOP I/F If the Reactor is tripped, insert malfunctions 7, 8, 9 NOTE The following actions may or may not occur depending on Operator actions CREW If a minor transient occurs due to a midscale failure of Turbine Throttle Pressure occurs BOP Place the EHC Control Panel in MANUAL ATC Place the SG/Rx Demand Station in HAND BOP Lower Turbine load using the DECREASE pushbutton to restore Turbine Header pressure to 870 to 880 psig ATC Monitor Pressurizer level using uncompensated level indicators
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 9 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 6 Page 9 of 17 Event
Description:
Loss of NNI-X DC power (cont.)
Time Position Applicants Actions or Behavior ATC Maintain RCS pressure by manually controlling Pressurizer Heaters and Pressurizer Spray as necessary ATC Place the Makeup System alternate injection line in service Close MU 6422, Makeup Train 2 To RCS Isolation Open MU 6421, Makeup Train 1 To RCS Isolation Throttle open MU 6419, Makeup Train 1 Injection, to maintain desired Pressurizer level Direct an Equipment Operator to open MU 6423B, Makeup Train 1 Flow Controller Bypass ATC Monitor Makeup Tank level using NNI-Y powered indication Manually transfer Makeup Pump suction valves as required ATC/BOP Transfer all NNI selector switches to NNI-Y I/F Role Role play as I&C for investigating loss of NNI-X DC At Lead Controllers discretion, proceed to Event 7, 8, 9
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 10 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 7,8,9 Page 10 of 17 Event
Description:
A loss of offsite electrical power causes a Reactor trip and a loss of all RCPs. The loss of the RCPs causes a SFRCS actuation. AFPT 1 will start and overspeed trip due to the loss of governor oil. AFPT 2 fails to start requiring the use of the MDFP. D2 Bus will have to be reenergized to provide power to the MDFP. EDG 2 fails to automatically start but can be started manually from the Control Room Time Position Applicants Actions or Behavior CREW Recognize a loss of offsite power and Reactor trip ATC Perform DB-OP-02000 Immediate Actions
- Manually trip the reactor
- Verify power decreasing in the intermediate range
- Manually trip the turbine SRO Route to DB-OP-02000, Section 3 Verify immediate actions CREW Route to Section 4, Supplemental Action Implement Specific Rules ATC/BOP
- Use Attachment 6 of DB-OP-02000 to re-power D2 Bus
- From the Station Blackout DG Verify AD213 close Open ABDD2 Verify AD 110 is open Start the SBODG by pressing START at the SBODG Control Panel C5740 Check SBODG speed approximately 900 RPM Verify AD213 is closed Close AD 301 to energize Bus D2 Verify Bus D2 energized Verify AD2DF7 is closed Verify BDF7 is closed
- Critical Task
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 11 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 7,8,9 Page 11 of 17 Event
Description:
Continued Time Position Applicants Actions or Behavior ATC/BOP
- Use Attachment 6 of DB-OP-02000 to re-power D2 Bus
- From EDG 2 Verify AD301, SBODG BKR is open Verify AD205, XFMR BDF6 is open Verify AD206, CLNG WTR PMP 2 is open Verify AD201, STA AIR CMPSR 2 is open or lock out Verify AD202, CLNG TWR MU PMP 2 is open Verify AD204, HTR DRN PMP 2 is open Verify AD207, CNDS PMP 2 is open Verify AD210, MOTOR DRIVEN FEED PUMP is open Open ABDD2, HIS 6228, ABDD2 Place D1 SYNC SELECT to BKR to D2 Close AD110, HIS 6233, AD110 Verify D2 is energized Place D1 SYNC SELECT in the OFF Close AD2DF7 Verify BDF7 is closed
- From EDG 1 Verify AD301, SBODG BKR is open Verify ABDD2, BUS TIE XFMR BD is open Verify AD205, XFMR BDF6 is open Verify AD206, CLNG WTR PMP 2 is open Verify AD201, STA AIR CMPSR 2 is open or lock out Verify AD202, CLNG TWR MU PMP 2 is open Verify AD204, HTR DRN PMP 2 is open Verify AD207, CNDS PMP 2 is open Verify AD210, MOTOR DRIVEN FEED PUMP is open Verify AD110 is open, HIS 6233, AD110 Verify HBBD is open, HIS 6214, HBBD Verify AC110 is open, HIS 6223, AC110 Place the C1 SYNC SELECT Switch to BKR TO XBD Close ABDC1, HIS 6220, ABDC1 Place the C1 SYNC SELECT Switch to OFF Close ABDD2, HIS 6228, ABDD2 Verify D2 is energized Close AD2DF7 Verify BDF7 is closed
- Critical Task
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 12 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 7,8,9 Page 12 of 17 Event
Description:
Continued Time Position Applicants Actions or Behavior BOP
- Use Attachment 5 of DB-OP-02000 to start the MDFP
- Enable BOTH MDFP Discharge Valves HIS 6460 HIS 6459
- Close BOTH MDFP Discharge Valves LIC 6460 LIC 6459
- Start the MDFP
- Establish feedwater flow to a Steam Generators at less than 1000 gpm indicated flow on the MDFP Flow Indicator FI 5876 BOP Verify proper SG level control using Specific Rule 4, Steam Generator Control, Level should be controlled at 49 BOP Direct an Equipment Operator to locally shift MDFP recirculation to the CST ATC Implement Specific Rule 6 Verify MU Pump 2 breaker is open Manually start EDG 2 Verify D1 Bus is energized Verify CCW Pump 2 is running Verify Service Water Pump 2 is running CREW Recognize lowering Instrument Air pressure BOP Verify the EIAC starts
- Critical Task
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 13 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 7,8,9 Page 13 of 17 Event
Description:
Continued Time Position Applicants Actions or Behavior CREW Check for symptom direction ATC Check for all Group 1-7 Control Rods fully inserted ATC Perform Attachment 1, Primary Inventory Control Actions Start MUPs Transfer MU Pump suctions to the BWST Manually control MU 6419 to control Pressurizer level at 80 to 120 inches Brief the SRO on Primary Plant status BPO Perform Attachment 2, Steam Generator Inventory and Pressure Control Actions
- Verify Steam Generator Levels are being controlled at 49 inches with the MDFP
- Place the Atmospheric Vent Valves in manual using Attachment 3 Place the AVV Hand/Auto Stations in HAND Reduce the AVV demands to zero Press the AVV BLOCK pushbuttons Press AUTO on the AVV Hand Indicating Switches Control Steam Generator Pressure as required from the Hand/Auto stations to maintain RCS Tave constant or slightly lowering
- Establish one Condensate Pump operation I/F Role Play Role play as an Equipment Operator to investigate the loss of both AFW Pumps. Report AFPT 1 tripped on overspeed due to no Governor control and AFPT 2 governor valve is stuck closed
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 14 of 17 FENOC Facsimile Final Op-Test No.: 2011 NRC Scenario No.:
3 Event No.: 7,8,9 Page 14 of 17 Event
Description:
Continued Time Position Applicants Actions or Behavior ATC Check for NNI Power available
- With NNI X DC power lost, then perform the following:
Operate PZR Heaters and Spray manually to maintain RCS pressure If uncompensated PZR Level is less than 60 inches then turn off all PZR Heaters Alternate Injection Line may be used to maintain PZR Level per Specific Rule 3 BOP Check for ICS Power available BOP Check for Instrument Air available ATC Check SFAS has not actuated BOP Verify proper SFRCS actuation for the trip parameters present using Table 1 CREW Check for:
Adequate subcooling margin Proper primary to secondary heat transfer SG Tube Rupture Termination criteria MDFP supplying AFW to both SGs Pressurizer level at proper level using the Alternate Injection Line
NUREG-1021, Revision 9 Supplement 1 Page 15 of 17 FENOC Facsimile Final CUE SHEET 2011 NRC Scenario 3 NOTE: Role Play as Maintenance/Work Week Manager/Operations as needed.
Event 1 - Transfer Gland Steam from Main Steam to Aux Steam Role play as an Equipment Operator to open AS1934, Aux Steam Supply to 5# Condensate Tank 1-1 Control Valve, for 1 minute and then close AS 1934 Event 2 - Loss of oil in AFPT 1 governor Role play as an Equipment Operator to call the Control Room to report the oil sight glass on the AFPT 1 governor is broken and the oil has leaked out of the governor Event 3 - Main Seal Oil Pump shaft shear Role play as an Equipment Operator to report the Main Seal Oil Pump has a sheared shaft. (If asked) ESOP is working properly Event 5 - Dropped Control Rod Role play as Operations Management for Reactivity Management notifications Role play as I&C for investigating the dropped rod Role play as the System Dispatcher to acknowledge the power reduction Event 6 - Loss of NNI-X DC Role play as I&C for investigating loss of NNI-X DC Event 7, 8 and 9 - Loss of offsite power, Reactor trip, failure of EDG 2 to automatically start and loss of both AFW Pumps Role play as an Equipment Operator to investigate the loss of both AFW Pumps. Report AFPT 1 tripped on overspeed due to no Governor control and AFPT 2 governor valve is stuck closed
NUREG-1021, Revision 9 Supplement 1 Page 16 of 17 FENOC Facsimile Final Simulator Setup Instructions 2011 NRC Scenario 3
- 1. Verify the following:
- a. Previous data on Yokogawa recorders is cleared
- c. Applicable procedures are wiped cleaned
- d. Used Alarm Typer paper is removed
- e. Computer alarms are cleared/acknowledged
- 2. Initialize at 50 to 60% power
- 3. Equipment Status:
- b. Tag out LPI Pump 1
- c. Turn on the LPI blue status
- d. Hang Protected Train 2 signs
- 4. Set Up Batch File
- a. Initial Setup
- Rackout the breaker for LPI Pump 1 IRFBDP1A to Ractout IRF BDPIE to TRUE
- EDG 2 fails to automatically start IMF XXXX to DEFEAT
- Stop RCP 1-1
- b. Triggers
- AFPT 2 Gov Valve closes when AFPT 2 steam admission valve opens TRGSET 8 SXA5889B>0.2
NUREG-1021, Revision 9 Supplement 1 Page 17 of 17 FENOC Facsimile Final
- c. Events Event 1 - Transfer GS from Main Steam to Auxiliary Steam Event 2 - Loss of oil from AFPT 1 governor IMF SFEJA (2)
Event 3 - Main Seal Oil Pump shaft shear IMF USMSC Event 4 - Rod 5-8 drops, location M-5 IMF LI53B (3)
Event 5 - Blown fuse causes MU32 to fail to control in automatic IMF H170 to 4.00000 (4)
Event 6 - Loss of NNI X DC IMF NP19B Event 7 - Loss of offsite power IMF PLZZ (6)
Event 8 - EDG 2 fails to automatically start Part of the setup Event 9 - AFPT 2 Gov Valve closes when the AFP starts IMF SFERE after 300(8) TRUE
Appendix D Scenario Outline Form ES-D-1 NUREG-1021, Revision 9 Supplement 1 Page 1 of 15 FENOC Facsimile Final Facility:
Davis-Besse Scenario No.:
4 Op Test No.:
NRC 2011 Examiners:
Operators:
SRO ATC BOP Initial Conditions:
80% power, MOL AFPT #1 tagged OOS Turnover:
Hold at 80% power while the Reactor Engineer reviews the calorimetric calculation completed at the end of the last shift.
Event No.
Malf.
No.
Event Type*
Event Description 1
TS-SRO AO reports oil leak on Train 1 Containment Spray Pump.
2 C-All RCP 1st Stage Seal failure on RCP 1-1.
3 R-ATC Power reduction prior to associated with1 N-SRO, BOP stopping RCP 1-1.
TS-SRO 4
I-ATC, BOP, SRO RCS Hot Leg RTD slowly drifts HI.
5 M-ALL RCP 1-2 Breaker trips. Reactor Trip required.
AUTO and MANUAL Reactor trip fails.
6 M-ALL PZR Safety Valve fails OPEN, initiating SFAS.
HPIP 2 fails to automatically start.
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor 1 Changed to reflect that power reduction actions occur both before and after pump stop and include actions by the BOP operator.
Scenario Event Description 2011 NRC Scenario 4 NUREG-1021, Revision 9 Supplement 1 Page 2 of 15 FENOC Facsimile Final DAVIS-BESSE 2011 NRC SCENARIO 4 The crew will take the watch with power holding at 80% power while the Reactor Engineer reviews the calorimetric calculation completed at the end of the last shift.
On cue from the Lead Evaluator, an AO will call the control room to report an oil leak on Containment Spray (CS) Pump #1. The SRO should request assistance from maintenance and/or enter the applicable TS. If necessary, a maintenance supervisor will report that the pump must be tagged OOS in order to make the repairs.
After the SRO has declared the TS for the CS Pump, the Lead Evaluator will cue the RCP 1-1 seal failure. The crew should respond to alarm 6-3-A in accordance with DB-OP-02006, REACTOR COOLANT PUMP ALARM PANEL 6 ANNUNCIATORS, and then enter DB-OP-02515, REACTOR COOLANT PUMP AND MOTOR ABNORMAL OPERATION.
DB-OP-02515 will require the crew to reduce power to 72% in accordance with DB-OP-02504, RAPID SHUTDOWN, and stop the affected RCP. The SRO should enter the proper TS after the RCP is stopped.
On cue from the Lead Evaluator, the RCS Thot selected on HIS3A and for Tave or UNIT will begin to drift HI. The crew should respond to alarm 4-2-B or indications in accordance with DB-OP-02004, REACTOR COOLANT ALARM PANEL 4 ANNUNCIATORS. The affected controls should be shifted to an alternate channel and the channel should be removed from service. The channel does not have to be removed from service to proceed with the scenario.
The Lead Evaluator can cue RCP 1-2 breaker trip when evaluation on the Thot failure is complete. The crew should recognize that an AUTO reactor trip should have occurred and attempt to initiate a MANUAL reactor trip. This will fail and the ATC should initiate a reactor trip by momentarily de-energizing Busses E2 and F2. Coincident with the reactor trip a PZR Safety Valve will fail sufficiently open to cause an SFAS actuation. HPIP #1 will trip and HPIP #2 will fail to automatically start. The crew should enter DB-OP-02000 - RPS, SFAS, SFRCS TRIP, OR S/G TUBE RUPTURE, and, among other actions, perform the following high level activities:
verify the reactor is tripped, start HPIP #2, complete the actions for lack of adequate subcooling margin.
The Lead Evaluator can terminate the scenario when all high level activities have been completed and the evaluators agree the crew can be properly evaluated.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
1 Page 3
of 15 Event
Description:
AO Reports Oil Leak On Train 1 Containment Spray Pump Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 3 of 15 FENOC Facsimile Final I/F Role Play When directed by Lead Evaluator, Call the control room to report an oil leak on Containment Spray Pump 1.
Role play as Maintenance/Work Week Manager/Operations as necessary.
SRO Refers to Tech Spec LCO 3.6.6 ATC/BOP Manually energize CS pump 1 blue light.
SRO May Call Work Week Manager.
SRO May refer to Risk Matrix (Yellow).
At Lead Evaluators discretion, proceed to Event 2
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
2 & 3 Page 4
of 15 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 4 of 15 FENOC Facsimile Final Indications Available:
6-3-A 1 SEAL RET FLOW HI.
6-5-A - Monitor System TRBL High controlled bleedoff flow of RCP 1-1 seal water.
Crew Respond to Annunciator Alarm (6-3-A) 1-1 SEAL RET FLOW HI.
ATC Observe High controlled bleedoff flow of RCP 1-1.
SRO Refer to DB-OP-02515, Reactor Coolant Pump and Motor Abnormal Operation.
CREW Determine IF any of the following RCP conditions exist:
Seal Return Temp 200°F Total seal leakage for the affected RCP 2.0 gpm.
Seal stage pressure drop greater than 1440 PSIG CREW Determines total seal leakage is > 2.0 gpm.
CREW IF a Reactor Shutdown to take the Unit off line is NOT desired, THEN, perform those steps necessary to reduce reactor power to the desired power level, AND REFER TO Attachment 1, ATC Reduce reactor power to 72 percent using DB-OP-02504, Rapid Shutdown At the Load Control Center Panel:
Set the rate of change and Enter Select the reactor power to the target load and Enter IF the APSRs are available, THEN attempt to maintain Axial Power Imbalance between 0 and negative 20 percent.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
2 & 3 Page 5
of 15 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 5 of 15 FENOC Facsimile Final BOP Place Tc Controller in Auto ATC/BOP Stop the affected RCP.
BOP Verify proper Feedwater flow ratios of 2.4 to 1.
ATC/BOP Verify Tave control transferred to the RC loop with two RCPs.
CREW Verify RCS flow is greater than the flow required by T.S. 3.4.1.
SRO Within four hours verify the Ø/Ø/Flow AND High Flux Trips setpoints have been reduced in accordance with TS 3.4.4.
SRO Notify the Steam Control Center (SCC). Load dispatcher of the unit load reduction.
SRO Request Chemistry to perform the following:
Monitor Condensate Polisher operation Sample the RCS for an isotopic analysis of Iodine.
SRO May review/implement TS 3.2.1 Rod Insertion Limit TS 3.4.9, Pzr Level BOP May reset SASS per DB-OP-02014, push SASS ACKNOWLEDGE and RESET buttons
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
2 & 3 Page 6
of 15 Event
Description:
RCP 1st Stage Seal Failure on RCP 1-1; Power Reduction Prior to Stopping RCP 1-1 Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 6 of 15 FENOC Facsimile Final ATC Boric Acid/water may be added to RCS to adjust rod position.
To Batch, at the Batch Controller per DB-OP-06001 NOTE: (number) is the keypad number
- 1. Press BATCH SET
- 2. Press number keys for size of batch
- 3. Press ENTER
- 4. Press DISPLAY (lower) to exist BATCH SET
- 5. Press BATCH (4) to display batch size
- 6. Press DISPLAY (lower)
- 7. Press TOTAL (7)
- 8. Press TOTAL RESET(6)
- 9. Press DISPLAY (upper)
- 10. Press RATE (*8)
- 11. Press RUN
- 12. Open MU40 using HISMU40
- 13. Start a Boric Acid Pump using HIS MU50A/B
- 14. Adjust MU flow, if necessary, with MU23 using HC MU23
- 15. Open WC 3526 using HIS 3526
- 16. When batch is complete, verify MU40 is closed
- 17. Close WC 3526 using HIS 3526 At Lead Evaluators discretion, proceed to Event 4
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
4 Page 7
of 15 Event
Description:
RCS Hot Leg RTD Slowly Drifts HI Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 7 of 15 FENOC Facsimile Final Booth Operator Instructions:
When directed, insert command for Event 4 Indications Available:
4-2-B, HOT LEG TEMP HIGH 14-4-D, ICS FW LIMITED BY RX POWER 14-4-E, ICS INPUT MISMATCH 14-6-D, ICS IN TRACK 4-2-E, PZR LVL LO Loop 2 Thot indication rising ATC Check the alarm by observing Loop 1 and Loop 2 Hot Leg Tis.
ATC Verify the ICS is reducing Rx power to lower Tave to 582°F ATC Compare Hot Leg Temperature Indicators TI RC3A1 and T1 RC3B1 on RC Panel C5718.
ATC IF the selected Hot Leg Temperature Transmitter failed, THEN verify SASS has transferred to unfaulted instrument.
Crew May Respond to Annunciator Alarm (4-2-E) PZR LVL LO IAW with DB-OP-02004, Reactor Coolant Alarm Panel 4 Annunciators ATC Observes Low Pressurizer level as indicated on LRS RC14 if low Pressurizer level occurs ATC IF Pressurizer Level is due to a Tave transient, THEN perform the following:
Reduce MU-32 Setpoint to ~ 180 WHEN Tave is restored to ~ 582°F, AND Pressurizer Level is stable, THEN restore MU-32 to 220 inches as directed by the CTRM SRO.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
4 Page 8
of 15 Event
Description:
RCS Hot Leg RTD Slowly Drifts HI Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 8 of 15 FENOC Facsimile Final CREW Determine which instrument pair has caused the alarm. (Thot)
SRO Refer to DB-OP-06404 NNI System and Operating procedure, and/or DB-OP-02526, Primary to Secondary Heat Transfer Upset ATC Place SG/Rx Demand station in HAND Place Rx Demand station in HAND ATC Place Rod Control Panel in Manual and adjust power.
BOP Place BOTH FEEDWATER DEMAND H/A Stations in HAND.
BOP Maintain Feedwater flow matched with Plant power using SP6A and SP7A AND LOOP 1 FEEDWATER DEMAND H\\A Station.
ATC/BOP Check for ICS module, component, or instrument failures.
At Lead Evaluators discretion, proceed to Event 5
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
5, 6, & 7 Page 9 of 15 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 9 of 15 FENOC Facsimile Final Booth Operator Instructions:
When directed, insert command for Event 5 Indications Available:
5-3-H, RPS POWER - PUMPS TRIPPED 5-1-G, H, I, J, RPS CH 1, 2, 3, 4 TRIPPED ZL4265A and ZL 4265A red lights lit - Safety Valve Open indication ATC Manually Trip the Reactor Reactor Trip Pushbutton has been depressed Power is decreasing on the Intermediate Range Nuclear Instrumentation (NO)
IF the reactor is NOT shutdown, THEN perform the following actions until the reactor is shutdown.
CRITICAL TASK ATC
- 1.
Momentarily deenergize 480-Volt Unit Substations E2 AND F2 simultaneously.
Maintain balanced primary to secondary heat transfer:
- 1.
IF MFW is less than Reactor power, THEN manually control MFW flow to match Reactor power.
ATC Manually trip the Turbine Turbine Trip Pushbutton has been depressed Turbine Stop Valves 1, 2, 3 AND 4 are closed OR Turbine Control Valves 1, 2, 3, AND 4 are closed
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
5, 6, & 7 Page 10 of 15 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 10 of 15 FENOC Facsimile Final SRO CHECK FOR SPECIFIC RULE OR SYMPTOM DIRECTION Implement any necessary Specific Rules.
Specific Rule 2, ACTIONS FOR LOSS OF SUBCOOLING MARGIN Applies Specific Rule 3, MU\\HPI\\LPI FLOW INITIATION, THROTTLING, AND TERMINATION Applies Specific Rule 4, Steam Generator Level Control Applies SRO Implement any necessary Symptom Mitigation Sections LACK OF ADEQUATE SUBCOOLING MARGIN (Section 5.0) applies SRO Directs tripping remaining RCPs IAW specific Rule 2 when subcooling is lost.
CRITICAL TASK ATC Trips all remaining RCPs ATC Transfer SCM inputs to Incore Thermocouples CRITICAL TASK*
ATC MU\\HPI Initiation per Specific Rule 3 and Attachment 8 Start the standby CCW Pump.
- Start BOTH HPI Pumps.
HPI Pump 1 (Tripped)
HPI Pump 2
- Open HPI Injection Valves.
HP 2A HP 2B HP 2C (may/may not be opened)
HP 2D (may/may not be opened)
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
5, 6, & 7 Page 11 of 15 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 11 of 15 FENOC Facsimile Final Verify Both LPI Trains are in service Open Piggyback Valves (DH64 and DH63)
Lock MU Pump Suctions in the BWST position.
MU 3971 MU6405 Start the second MU Pump If Pressurizer level is <40 inches Isolate Letdown using MU2B Verify all Pressurizer heaters are off Open MU 6421 Open MU6419 ATC IF only one HPI train is available, THEN REFER TO 1, HPI Flow Balancing.
Stop Makeup flow through HPI Train 2 by closing MU 6422, MU CTMT ISOLATION.
Verify HPI Train 2 Injection Valves are fully open.
HP2A, HIGH PRESSURE INJECTION LINE 2-1 ISOLATION HP2B, HIGH PRESSURE INJECTION LINE 2-2 ISOLATION Determine which injection line has the lower flow and REFER TO Figure 3, HPI Balancing.
FYI HP3A FYI HP3B IF only the lower flow is NOT in the acceptable region, THEN throttle the higher flow line until:
The lower flow line is in the acceptable region OR The high flow line reaches the lower limit of the acceptable region IF MU 6422 was closed in during HPI flow balancing, THEN open MU 6422, MU CTMT ISOLATION.
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
5, 6, & 7 Page 12 of 15 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 12 of 15 FENOC Facsimile Final BOP Using Attachment 5 to start the the MDFP Enable BOTH MDFP Discharge Valves HIS 6460 HIS 6459 Close BOTH MDFP Discharge Valves LIC 6460 LIC 6459 Start MDFP Establish feedwater flow to a Steam Generator at less than 1000 gpm indicated flow on MDFP flow indicator FI5876 ATC Monitor RCS Pressure.
SRO Routes to DB-OP-02000, section for LACK OF ADEQUATE SUBCOOLING MARGIN ATC Trip all RCPs. (Already performed.)
Verify MU, HPI, and LPI are in service per Attachment 8 (Already performed)
CREW Verify proper SFAS response using SAM lights (on DIM) or Table 2 BOP Verify proper SFRCS actuation for the trip parameters present using Table 1.
BOP Verify proper SG level control by AFW using Specific Rule 4 SG level at 49 inches without an SFAS SG level at 124 inches with an SFAS
Appendix D Operator Action Form ES-D-2 Op Test No.:
2011 NRC Scenario #
4 Event #
5, 6, & 7 Page 13 of 15 Event
Description:
RCP 1-2 Breaker Trips; Reactor Trip Required; AUTO and MANUAL Reactor Trip Fails; PZR Safety Valve Fails OPEN, Initiating SFAS; HPIP 1 Trips; HPIP 2 Fails to Automatically Start Time Position Applicants Actions or Behavior NUREG-1021, Revision 9 Supplement 1 Page 13 of 15 FENOC Facsimile Final ATC Isolate Possible RCS Leaks using Attachment 19 NOTE: this is an unisolable leak at the top of the Pzr ATC Verify CFT Isolation Valves are open.
CF1A CF1B SRO If adequate subcooling margin exists, THEN GO TO Step 5.18.
CREW Throttle MU and HPI as necessary to maintain adequate subcooling margin. REFER TO Specific Rule 5, PTS Requirements.
Scenario may be terminated when crew reaches Step 5.18.
Scenario may be terminated if crew has control of RCS cooldown and depressurization and SCM does not exist.
NUREG-1021, Revision 9 Supplement 1 Page 14 of 15 FENOC Facsimile Final SIMULATOR INSTRUCTIONS 2011 NRC Scenario 4
- 1. Verify the following
- a. Previous data o Yokogawa recorders is cleared
- b. Applicable procedures are wiped clean
- c. Used Alarm Typer paper is removed
- d. Computer alarms are cleared/acknowledged
- 2. Initialize at 80% power
- 3. Equipment Status
- a. Hand License Requirement Sheet on the Status Board
- b. Tag out AFPT 1 speed changer
- c. Turn on the AFW blue light
- d. Hang Protected Train 2 sign
- 4. Set Up Batch Files
- a. Initial Setup (1) Remove AFPT 1 from service (a) Trip the Trip Throttle Valve:
IRF SFE1A to CLOSE (b) Close MS106A IMF SFEAB (c) Open MS106A breaker, BE1271 IRF SFEAA to OPEN, delete in 10 (d) Close MS106 IMF SFE8B (e) Open MS106 breaker IRF SFE8A to OPEN, delete in 10 (2) Fail the Reactor to automatically Trip:
(a) RPS trip override IMF L4 (b) ARTS trip override IMF L8 (c) DSS Ch 1 Opto-Isol failure IMF L5D1 (d) DSS Ch 2 Opto-Isol failure IMF L5D2 (3) Fails HPI 2 to AUTO START IMF BFP2E
- b. Events (1) CSP 1 breaker, BE111RACK OUT IRF BDP3A to TRUE (2) RCP 1-1 first stage seal failure IMF HN09 in 300 (3) Power Reduction (4) RCS Loop 2 Th RTD slowly drifts high IMFL1T6H from 0.81 in 120 (5) RCP 1-2 breaker fails open IMF H102J (6) RO must trip E2 and F2 (7) Pzr Safety fails open IMF HV40C (8) HPIP 1 trips IMF BFP1C
NUREG-1021, Revision 9 Supplement 1 Page 15 of 15 FENOC Facsimile Final SIMULATOR INSTRUCTIONS 2011 NRC Scenario 4
- 5. Instructor Station Cues NOTE: Role Play as Maintenance/Work Week Managers/Operations as applicable
- a. Event 1 - CTMT Spray Pump 1 Oil Leak (1) Role Play as a Plant Operator to report the oil sight glass for the outboard bearing on CSP 1 is broken and oil from the bearing has leaked onto the floor.
(2) Role Play to remove close power fuses of racked out breaker for CSP 1
- b.
Event 2 - RCP 1-1 Seal Failure and power reduction to stop RCP -1 (1) Role Play as the System Dispatcher, if contacted (2) Role Play as Equipment Operator, if contacted
- c.
Event 3 - Selected Thot RTD transmitter (TT RC3A1) fails high
- d.
Event 4 - RCP 1-2 breaker trip
- e.
Event 5 - ATWS
- f.
Event 6 - Pressurizer Safety fails open
- g.