ML21137A295

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Proposed Scenarios
ML21137A295
Person / Time
Site: Davis Besse Cleveland Electric icon.png
Issue date: 02/18/2021
From: Gregory Roach
NRC/RGN-III/DRS/OLB
To:
FirstEnergy Nuclear Operating Co
Roach G
Shared Package
ML20136A254 List:
References
Download: ML21137A295 (47)
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Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 1 Op Test No.: DB NRC 2021 Examiners: Operators: SRO ATC BOP Initial Conditions:

  • Approximately 2% power
  • MDFP in service
  • MFP 2 running with no load on it, ICS control in HAND Turnover:
  • Plant was shut down to repair a small RCS Leak
  • Reactor Power currently at approximately 2%
  • Plant startup per DB-OP-06901, complete through Step 3.24
  • Mode 1 checklist is complete Planned:
  • Continue a plant startup per DB-OP-06901, starting at Step 3.25
  • Place MFP 2 in service and shutdown the MDFP
  • Raise Reactor power to 4% in preparation for Mode change Critical tasks:
1. Trip All Reactor Coolant Pumps (CT-1)
2. Initiate LPI (CT-4)

Event Malf. Event Type* Event No. No. Description 1 N-BOP/SRO Transfer from Motor Driven Feed Pump to MFP 2 2 R-ATC/SRO Raise power to 4%

3 C-BOP/SRO CAC 2 high bearing temperature (TS)

I-ATC/SRO 4 PZR Level Temp Comp Inst Fails Low TS-SRO C-BOP/SRO 5 SW Pump Trip (TS), CT2955 fails to Auto Open TS-SRO 6 M-All Large Break LOCA/Reactor Trip/LSCM 7 C-ATC/SRO LPI pump 2 fail to start - cross connect LPI

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, Revision 11 Page 1 of 21

Scenario Event Summary DAVIS-BESSE 2021 NRC SCENARIO 1 The scenario begins with a plant startup in progress, Mode 2, Reactor Power stable at ~2%,

with Main Feed Pump (MFP) 2 ready to be placed in service. The crew will have an opportunity to review DB-OP-06901, Plant Startup Procedure, DB-OP-06225, MDFP Procedure, and the turnover sheet, prior to walking down the panels.

EVENT 1 & 2: Place MFP 2 in service and raise Reactor power to 4%

The BOP will place MFP 2 in service then shutdown the Motor Driven Feed Pump (MDFP). The ATC will then raise Reactor Power to 4%, all IAW DB-OP-06901, Plant Startup Procedure.

When power ascension has begun and on Lead Evaluators direction, proceed to Event 3.

EVENT 3: Containment Air Cooler (CAC) 2 High Bearing Temperature CAC 2 fan motor bearing high temperature alarm will come in on computer point T299. The SRO will refer to DB-OP-06016, Containment Air Cooling System and direct shutting down CAC 2 and enter TS 3.6.6 Condition C.

EVENT 4: PZR Level Temp Comp Inst Fails Low When event 4 is cued by the Lead Evaluator the Pressurizer Temperature Transmitter TE RC15-1 will fail low resulting in lowering pressurizer level indication (temperature compensated) and increased makeup flow as MU32, Makeup Flow Controller, responds to the failure. The crew will diagnose the failure and enter abnormal procedure DB-OP-02513, Pressurizer System Abnormal Operations, and place MU32 in hand to control pressurizer level. Alternate temperature input to pressurizer temperature (TE RC15-2) will be verified functional and selected, then MU32 can be returned to automatic control.

EVENT 5: Service Water Pump 2 Trip (TS) CT2955 fails to Auto Open At Lead Evaluators discretion cue Service Water Pump supplying secondary loads to trip. SW HDR PRESS computer point will come in, and the SRO will implement DB-OP-02511, Loss of Service Water Pumps/System. The BOP will OPEN CT2955 to align Circulating Water to cool secondary loads. The SRO will enter the applicable TS and direct the spare SW Pump to be placed in service. The next event will be cued prior to placing the spare SW Pump in service.

EVENT 6 & 7: Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start The Lead Evaluator will cue a Large Break LOCA resulting in a reactor trip. The crew will implement Emergency Procedure, DB-OP-02000, and verify immediate actions and check for Specific Rule applicability. With Minimum Sub Cooling Margin lost, Specific Rule 2 actions will be performed, and all RCPs tripped (CT-1 Trip All RCPs). After checking for the remaining Specific Rule applicability, Symptom Mitigation applicability will be checked and the Unit Supervisor will route to Section 5, Lack of Adequate Subcooling Margin. With LPI flowing into the core the Unit Supervisor will route to Section 10, Large LOCA Cooldown. The crew will identify that #2 LPI Pump failed to start and cannot be manually started. The crew will implement step 10.7 Response Not Obtained (RNO) and cross connect LPI Pump discharge using Section 1 of Attachment 22, Cross Connect LPI Pump Discharge (CT-4, Initiate LPI).

At Lead Evaluator discretion the scenario can be terminated.

NUREG-1021, Revision 11 Page 2 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 1&2 Page 1 of 4 Event

Description:

Place MFP 2 in service and Increase Reactor power to 4%

Time Position Applicants Actions or Behavior Indications Available:

  • NI Meters
  • Reactivity Trend up at SE Station
  • HUR on Back Screen for ROs to monitor
  • MFP 2 speed and discharge pressure
  • Average RCS Temperature TIRC7
  • T710 Core Delta Temp SRO Direct transfer of feedwater from the MDFP to MFP 2 Raise Main Feed Pump 2 Speed until discharge pressure is
  • BOP between 1000 and 1050 psig Driver Driver to adjust cooling if computer points come in.

SM Cue If MFP oil/bearing temperatures are discussed due to computer points in alarm, role play as Shift Manager (SM),

An operator is continuously monitoring and making adjustment to cooling as needed.

BOP Contact EO to close FW 6396, MDFP TO MFW ISO VALVE Booth Role play as EO, FW 6396 is closed.

Cue

  • Stop the MDFP using HIS 579
  • Adjust MFP 2 speed to maintain FW VLV DP 40-75 psid Contact EO to:

BOP o Verify Closed FW170, FW Mini Bypass to condenser o Close FW104, D/A Storage Tanks to Condenser o Verify Open FW33, D/A Storage Tanks to Condenser NUREG-1021, Revision 11 Page 3 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 1&2 Page 2 of 4 Event

Description:

Place MFP 2 in service and Increase Reactor power to 4%

Time Position Applicants Actions or Behavior Role play as EO, o FW170, FW Mini Bypass to condenser, has been Booth verified closed Cue o FW104, Deaerator Storage Tanks to Condenser, is closed o FW33, Deaerator Storage Tanks to Condenser, has been verified open Direct shutdown of the MDFP in the Main Feedwater Mode, BOP REFER TO DB-OP-06225, MDFP Operating Procedure.

If asked, Role play as the SM, o MDFP is NOT required to be kept warm o MDFP will be shutdown for an extended period SM/Booth o Settling basins are NOT aligned for secondary Cue system drain o MDFP will NOT be placed in the Auxiliary Feedwater Mode at this time If asked, Role play as the SM, SM Cue Adjust the GEMAC controller set point to 4.0 MPPH.

BOP Adjust the MFP 2 Recirc GEMAC controller set point to 4.0 MPPH NOTE: The following steps in ARTs should be performed when MFP 2 is in service.

Place the following test toggle switches for MFPT 2 in the OPERATE position in all four ARTS cabinets:

  • ARTS Channel 4 Verify MAIN FEED PUMP 1/5 status lights are OFF in all four ARTS Channels:

o ARTS Channel 1 in C5784A BOP o ARTS Channel 2 in C5784B o ARTS Channel 3 in C5784C o ARTS Channel 4 in C5784D NUREG-1021, Revision 11 Page 4 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 1&2 Page 3 of 4 Event

Description:

Place MFP 2 in service and Increase Reactor power to 4%

Time Position Applicants Actions or Behavior Check the following test toggle switches, for the MFPT NOT in service, are in the TRIP position in all four ARTS cabinets:

o ARTS Channel 1 BOP o ARTS Channel 2 o ARTS Channel 3 o ARTS Channel 4 Perform the following in all four ARTS Channels:

o Check the MAIN FEED PUMP 1/5 light is OFF

  • Place the MAIN FEED PUMP NORMAL/BYPASS switch in NORMAL.

o Check the TURB GEN 1/5 light is OFF.

o Check TG NORMAL/BYPASS switch is in NORMAL.

o Check the SFRCS 1/5 light is OFF.

  • BOP o Check SFRCS NORMAL/BYPASS switch is in NORMAL.

o Check the BYPASS NORMAL light is ON.

  • ARTS Channel 4 Direct Power increase to 4% while controlling heat up rate at less SRO than 35°F/Hr (0.58°F/min)

Direct Field Supervisor to begin preparations for Turbine warming.

SRO REFER TO DB-OP-06202, Turbine Operating Procedure.

When directed/requested, SM/Booth The Field Supervisor will begin preparations for Turbine Cue Warming.

  • Pull/withdraw rods using handle on Rod Control Panel o Monitor Heatup Rate on SPDS
  • ATC o Monitor Reactor power o Stabilize Reactor power at 4%

Contact Field Supervisor to Start Turbine warming. REFER TO SRO DB-OP-06202, Turbine Operating Procedure.

NUREG-1021, Revision 11 Page 5 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 1&2 Page 4 of 4 Event

Description:

Place MFP 2 in service and Increase Reactor power to 4%

Time Position Applicants Actions or Behavior When directed/requested, SM/Booth The Field Supervisor will begin Turbine Warming when Cue preparations are complete.

When directed/requested, SM/Booth The Field Supervisor will coordinate the transfer of Auxiliary Cue Steam 235 PSIG Header from the Auxiliary Boiler to Main Steam Reducing Station.

NOTE: It takes ~4 minutes for the computer point to come in after the event is inserted At Lead Evaluators direction, proceed to Event 3, CAC 3 as 1 high bearing temperature (TS)

NUREG-1021, Revision 11 Page 6 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 3 Page 1 of 2 Event

Description:

CAC 2 fan motor bearing high temperature (TS)

Time Position Applicants Actions or Behavior Indications Available:

T303 CTMT CLR FAN 3 MTR F/E BRG OT Recognize high bearing temperature on CAC 2 on computer point CREW T299, CTMT CLR FAN 2 MTR F/E BRG OT Monitor Containment Air Cooler 2 bearing temperatures. A bearing CREW temperature of 160 degrees Fahrenheit requires shutdown Refer to DB-OP-06016, Containment Air Cooling System Section SRO 4.1, Operation of CACs with Stator or Bearing Temperature Alarms Refer to DB-OP-06016, Containment Air Cooling System Section SRO 3.6, Shutdown of Containment Air Coolers to STOP CAC 2 NOTE: May also refer to Section 3.2 Direct EO to Slowly CLOSE SW59, CTMT AIR COOLER 2 INLET BOP ISO Booth Role-play as EO, Cue SW59 has been closed.

  • BOP Depress HIS5032, CTMT AIR CLR FAN 2 to stop CAC 2 Verify SW1357, CONTAINMENT AIR COOLER 2 OUTLET BOP TEMPERATURE CONTROL is OPEN using HIS1357, SW1357 CLOSE SW1367, SERVICE WATER INLET TO CAC 2, using

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 3 Page 2 of 2 Event

Description:

CAC 2 fan motor bearing high temperature (TS)

Time Position Applicants Actions or Behavior Declare CAC 2 inoperable and unavailable

  • Enter Condition: C. One required containment air cooling
  • SRO train inoperable o Required Action: C.1 Restore required containment air cooling train to OPERABLE status o Completion Time: 7 days SRO Direct placing Containment Air Cooler 3 as 2 in service Role play as requested, SM/Booth The Field Supervisor will coordinate placing Containment Air Cue Cooler 3 as 2 in service.

NOTE: Placing CAC 3 in service is not required for continuation of scenario After Tech Spec 3.6.6 Condition C has been entered and at Lead Evaluators direction, Proceed to Event 4, PZR Level Temp Comp Inst Fails Low NUREG-1021, Revision 11 Page 8 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 4 Page 1 of 1 Event

Description:

PZR Level Temp Comp Inst Fails Low Time Position Applicants Actions or Behavior Indications Available:

  • 2-4-C, MU FLOW HI TRN 2
  • Rising MU Flow
  • Drop in PZR Level Respond to annunciator 2-4-C, MU FLOW HI TRN 2, identify PZR ATC temperature indication is failed low Implement DB-OP-02513, Pressurizer System Abnormal SRO Operation, Section 4.6, Failure of Selected Pressurizer Level or Temperature Instruments.
  • ATC Place MU32, RCS Makeup valve, in HAND using LICRC14 Adjust MU32 to obtain desired Makeup flow or PZR level - Discuss
  • ATC with SRO and determine level band for manual control SRO Set Pressurizer level control band based on uncompensated level Compare PZR Temperature Instruments, identify selected TE has ATC failed (TTRC15-1)

Refer to DB-OP-06407, Non Nuclear Instrument Operating SRO Procedure, for transferring input SRO Contact I&C to investigate failure Select good input to HSRC15, place HIS RC 15 to the TT RC 15-2

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5 Page 1 of 3 Event

Description:

Service Water Pump 2 Trip (TS), CT2955 fails to Auto Open Time Position Applicants Actions or Behavior Indications Available:

  • SWP 2 green light on
  • BOP OPEN CT2955 to supply secondary loads Direct an Equipment Operator or Electrical Maintenance to SRO investigate targets on SW Pump 2 Role Play as an Equipment Operator, Booth There is an 50/51A target, Alarm-Time and Instantaneous Cue Overcurrent on Breaker AD107, Breaker for SW Pump 2 SRO/ATC Check Forebay Level (L435) is at least 566 feet.

Direct an Equipment Operator to align SW Pump 3 as SW Pump 2 SRO/BOP using Attachment 2, Aligning Service Water Pump 3 as 2.

Role Play as the Field Supervisor, Booth Align SW Pump 3 as SW Pump 2 using Attachment 2, Cue Aligning Service Water Pump 3 as 2.

NUREG-1021, Revision 11 Page 10 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 4 Page 2 of 3 Event

Description:

Service Water Pump 2 Trip (TS), CT2955 fails to Auto Open Time Position Applicants Actions or Behavior Control secondary loads on Circ Water using Attachment 10 o Verify SW1399, (HIS 1399) SW HDR 1 TO TPCW HX is closed.

o Verify SW1395, (HIS 1395) SW HDR 2 TO TPCW HX is closed.

o Verify CT 2955, (HIS 2955) TPCW HX SUPPLY FROM CIRC WTR is open.

Direct an Equipment Operator to complete Attachment 10 for Circ BOP Water Supplying Secondary loads o Verify CT56, CIRCULATING WATER SUPPLY TO TURBINE PLANT COOLING WATER HEAT EXCHANGERS STOP is open.

o Fully open the in-service TPCW HX Outlet Valves.

o SW54, TPCW HX 1 OUTLET ISOLATION o SW55, TPCW HX 2 OUTLET ISOLATION o SW56, TPCW HX 3 OUTLET ISOLATION Role play as Equipment Operator, Booth Complete Attachment 10 for Circ Water Supplying Secondary Cue loads Notify the Shift Manager to SRO

  • REFER TO NOP-OP-1015, Event Notifications.
  • REFER TO NOBP-OP-0011, Fleet Status Call.

SRO Refer to Tech Spec 3.7.8 for an inoperable Service Water Train Determine LCO 3.7.8, is not met due to SW Pump 2 inoperable

SRO o REQUIRED ACTION A1: Restore SWS loop to OPERABLE status.

o COMPLETION TIME: 72 Hours NUREG-1021, Revision 11 Page 11 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 4 Page 3 of 3 Event

Description:

Service Water Pump 2 Trip (TS), CT2955 fails to Auto Open Time Position Applicants Actions or Behavior Determine LCO 3.8.1, is not met due to EDG2 being inoperable

  • CONDITION B: One EDG inoperable o REQUIRED ACTION B.1: Perform SR 3.8.1.1 for OPERABLE offsite circuit(s) o COMPLETION TIME: 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> AND o REQUIRED ACTION B.2 (Not applicable in this scenario)
  • SRO AND o REQUIRED ACTION B.3.1 Determine OPERABLE EDG is not inoperable due to common cause failure o COMPLETION TIME: 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OR o REQUIRED ACTION B.3.2 Perform SR 3.8.1.2 for OPERABLE EDG.

o COMPLETION TIME: 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> AND o REQUIRED ACTION B.4 Restore EDG to OPERABLE status.

o COMPLETION TIME: 7 Days Role play as Shift Manager, SM Cue Another Operator will ensure completion and review of DB-SC-03023, Off-Site Sources.

BOP Energize SW and EDG Blue Operability lights On Lead Evaluators discretion, proceed to Event 5, Large Break LOCA NUREG-1021, Revision 11 Page 12 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 1 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior Indications Available:

  • Pressurizer Level decreasing
  • Makeup Tank level decreasing

<10 minutes after SCM is <20F Task (CT-1)

Time SCM Lost: ____________

NOTE: LPI pump must be cross tied per DB-OP-02000, Critical Attachment 22 <20 minutes after RCS Pressure 200 psig*

Task (CT-4)

Time RCS Pressure 200 psig: ____________

SRO Directs ATC to Trip the Reactor Perform DB-OP-02000 Immediate actions

  • Trip the Reactor o Verify Reactor Power is lowering on the Intermediate Range ATC
  • Trip the Turbine o VERIFY all Turbine Stop Valves OR Control Valves are closed Implement DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube SRO Rupture SRO/ATC Verify immediate actions Implement any necessary Specific Rules Actions CREW o Recognize SR 2 ACTIONS FOR LOSS OF SUBCOOLING MARGIN is required NUREG-1021, Revision 11 Page 13 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 2 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior Implement Specific Rule 2, Actions for Loss of Subcooling Margin

  • Critical Transfer Subcooled Margin Input to Incore Thermocouples Task BOP

Complete Specific Rule Actions SRO o SR 4 STEAM GENERATOR CONTROL o SR 6 POWER FOR C1 AND D1 BUSES OR EDG START Implement Specific Rule 6, due to EDG Start o Verify the affected train(s) EDG is running o Verify the affected train(s) essential bus (C1 - D1) is ATC energized o Verify a CCW pump is running for the EDG(s) that started o Verify a SW Pump is running for the EDG(s) that started o Monitor CCW Temp due to Loss of Train 2 Service Water Implement any necessary Symptom Mitigation Sections SRO o Route to Section 5.0 LACK OF ADEQUATE SUBCOOLING MARGIN SRO Verify all Reactor Coolant Pumps are tripped SRO Notify SM to review Emergency Classification ATC/BOP Verify MU, HPI AND LPI are in service per Attachment 8 ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Verify BOTH CCW Trains in service ATC/BOP o CCW Pump 1 running o CCW Pump 2 running NUREG-1021, Revision 11 Page 14 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 3 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Verify BOTH HPI Pumps are running:

ATC/BOP o HPI Pump 1 running o HPI Pump 2 running ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Verify HPI Injection Valves fully OPEN:

ATC/BOP o HP2C o HP2D o HP2A o HP2B ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Verify BOTH LPI Pumps are in service:

ATC/BOP o LPI Pump 1 running o LPI Pump 2 (failed to start - manual start will not be successful)

If Equipment Operator sent to check LPI Pump 2 breaker Booth report: 50/51 instantaneous over current relay actuated on cue breaker AD112 LPI flow will exist into core, piggyback valves to be left closed ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

ATC/BOP Check both piggyback valves are CLOSED o DH64 o DH63 NUREG-1021, Revision 11 Page 15 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 4 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Transfer MU Pumps suction to the BWST position and press OFF ATC/BOP for each switch:

  • MU 6405
  • MU 3971 ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

ATC/BOP

  • Set Pressurizer Level Control set point to 100 inches ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

ATC/BOP

  • Start standby Makeup Pump Lube Oil Pumps
  • Start standby Makeup Pump ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Lock MU Pump Suctions on the BWST ATC/BOP

  • MU6405
  • MU3971 ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

ATC

  • Isolate Letdown using MU2B ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

ATC o Check all Pressurizer Heaters are off ATTACHMENT 8, PLACE HPI/LPI/MU IN SERVICE Cont.

Place alternate injection line in service

  • Open MU6421, CTMT ISOLATION FOR ALTERNATE MU ATC INJECTION LINE
  • Open MU6419, ALTERNATE MU INJECTION LINE o Direct EO to Open MU6423B, MIN-FLOW BYPASS AROUND MU6419.

NUREG-1021, Revision 11 Page 16 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 5 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior Verify proper SFAS response (Check SAM Lights) o Identify LPI Pump 2 did not start BOP

  • Attempt to start LPI Pump 2 - May have attempted to start during performance of Attachment 8 If Equipment Operator sent to check LPI Pump 2 breaker Booth report: 50/51 instantaneous over current relay actuated on cue breaker AD112 Verify proper SFRCS actuation for the trip parameters present BOP using Table 1 Verify proper SG level control by AFW using Specific Rule 4 BOP (124 inches)

Direct BOP if SFRCS trips on low SG pressure due to MU/HPI SRO injection flow or raising SG levels to 124 inches then re-establish AFW to the isolated SG and restore level per Specific Rule 4 Block and re-establish AFW to the isolated SG and restore level per Specific Rule 4 BOP

  • OPEN MS107
  • OPEN MS106A
  • CLOSE AF3871 SRO Route to Section 10, Large LOCA Cooldown (LPI flow to RCS)

SRO Notify SM to review Emergency Classification NUREG-1021, Revision 11 Page 17 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 6 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior ATC/BOP Verify proper SFAS response using Table 2 Direct actions to close breakers for DH 7A, DH 7B, DH 9A, DH 9B SRO and HP 31. REFER TO Attachment 7, Section 1, Actions to close breakers for DH 7A, DH 7B, DH 9A, DH 9B and HP 31 Booth Role play as EO, REFER TO Attachment 7, Section 1 to close Cue breakers for DH 7A, DH 7B, DH 9A, DH 9B and HP 31.

Start Control Room EVS per Attachment 21:

BOP

  • Place HIS 5261, CREVS Train 1 in start.
  • Place HIS 5262, CREVS Train 2 in start Open the outside air Inlet damper(s):
  • HA 5262, FAN 2 OUTSIDE AIR INLET DAMPER NOTE: RCM 5327 and RCM 5328 are not modeled in simulator Direct EO to place the Air-Cooled Condensing Units in service BOP following Emergency Start. REFER to DB-OP-06505, CTRM Emergency Ventilation System Procedure.

NUREG-1021, Revision 11 Page 18 of 21

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 1 Event # 5&6 Page 7 of 7 Event

Description:

Reactor Coolant System Large Break LOCA with LPI Pump 2 failure to start Time Position Applicants Actions or Behavior Cross-connect DH Pump discharges per Sect. 1 of Attachment 22:

o Verify DH Pump 2 is off

  • *Block AND close DH 2734, DH PUMP 2 LPI SUCT
  • *Restore Control Power for DH 1A and DH1B
  • *Close DH1A
  • *WHEN DH 2734 is closed, THEN open DH 831, DECAY HEAT COOLER DISCH XOVER 1 TO 2 ATC * *Throttle closed DH 1B AND throttle open DH 1A to obtain Critical the following:

Task*

(CT-4) *Maximize total DH Pump 1 flow NOT to exceed 4000 gpm

  • Do NOT throttle either LPI line to less than 1350 gpm o Balance flow between DH Injection Lines, FY1 DH2B AND FYI DH2A o Continue to monitor and adjust total DH Pump 2 flow as necessary.

NOTE: LPI pump discharge must be cross tied per DB-OP-Critical 02000, Att. 22 <20 minutes after RCS Pressure 200 psig Task (CT-4)

Time LPI pump cross tied: ____________

After cross-connect of DH Pump discharges is complete, the scenario can be terminated NUREG-1021, Revision 11 Page 19 of 21

Justification for Critical Tasks The term Critical Task, is defined in NUREG-1021, OPERATOR LICENSING EXAMINER STANDARDS FOR POWER REACTORS. The listed critical tasks were compiled based on a review of Areva Technical Document 47-1229003-06, EOP Technical Bases Document, and additional CTs were added based on established DB Operations expectations and standards for previously identified Critical Task.

CT-1: Trip all Reactor Coolant Pumps

1. Safety Significance:

-Analyses were performed which used both conservative and acceptable for best estimate Appendix K assumptions with the objective of meeting the requirements of 10CFR50.46.

-Using conservative Appendix K assumptions, it was shown that RCPs must be tripped within two minutes after losing adequate SCM to prevent the RCS from evolving to a high enough void fraction such that the core would be uncovered if the RCPs were tripped at a later time.

-Using realistic Appendix K assumptions, the maximum allowed time for tripping the RCPs was determined to be 10 minutes.

2. Cues:

SCM Meters and Annunciator 4-1-B, SUBCOOL MARGIN LO Procedural compliance

3. Measured by:

Time zero for CT-1 is when SCM <20°F on either SCM meter The required action to complete the critical task is to trip all RCPs The required end time for completion of Critical Task 1 is 10 minutes

4. Feedback:

RCP Status Indication CT-4: Initiate Low Pressure Injection

1. Safety Significance:

Providing flow through both LPI injection lines increases the likelihood that the LPI flow is providing Core cooling. Using two injection lines and balancing flow would insure at least 1000 gpm flow to the Core if one of the injection lines is faulted.

2. Cues:

RCS Pressure <200 psig and only one LPI Pump available Procedural compliance

3. Measured by:

Time zero for CT-4 is when RCS Pressure is <200psig The required action will require opening the LPI cross connect and throttling DH1A and DH1B to balance LPI flow without exceeding 4000 gpm total flow The required end time for completion of Critical Task 4 is 20 minutes

4. Feedback:

LPI Injection flow through both lines LPI Pump and Valve Status Indication NUREG-1021, Revision 11 Page 20 of 21

SIMULATOR SETUP INFORMATION

1. Simulator Setup
  • PZR Level at ~95 in
  • MUT Level at ~80 in
  • DB-OP-06901 complete through step 3.23
  • DB-OP-06225, Section 3.3 available for review
  • SP13B1 and SP13A1 in service, all other TBVs are disabled closed by isolating their Air Supply - hang placards
  • Adjust Header Pressure as required to ensure Tave is within band of CC 2.1
  • MFPT 2 on ICS control in HAND
  • Gland Steam on Aux Steam
  • Aux Boiler in service supplying Aux Steam
  • LPI Pump 2 fail to start
  • CACs 2 and 3 in service
  • 75% open on FW6396 (Placard Info Only)
  • Verify placards for FW170 (open), FW33 (2 turns), FW104 (open)
  • T710 Core Delta Temp on monitor over PAM Panel
  • Reactivity Trend up at SE Station
  • HUR on Back Screen for ROs to monitor
  • Remove V920, MDFP Vibration from computer alarm monitor
  • Secondary Plant Status Board FW HDR Press: 900-1200psig
  • Primary Status Board Maintain 2+/-.5% power using Core T
  • Ensure ARTs Keys are in key cabinet
2. Procedures
  • DB-OP-06901, Plant Startup Procedure (scenario aid signed up to Step 3.25)
  • DB-OP-06225, MDFP Operating Procedure
  • DB-OP-02513, Pressurizer System Abnormal Operation
  • DB-OP-06403, RPS and NNI Operating Procedure
  • DB-OP-06016, CAC System Procedure
  • DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture
3. Procedures for the Booth

Page 1 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST DATE: Today SHIFT: DAYS MODE: 2 POWER: 2%

SECURITY RISK: GREEN PLANT ONLINE RISK: GREEN PROTECTED TRAIN: 2 PLANT CONDITION: 1 SHUTDOWN DEFENSE-IN-DEPTH:

ACTIVE ALERTS: NONE GRID CONDITION: NORMAL N/A ADDITIONAL PROTECTED EQUIPMENT - None CONTINGENCY PLANS FOR OPERABILITY/AVAIL IN EFFECT - None OUTSTANDING PROMPT OPERABILITY DETERMINATIONS - None SHIFT ACTIVITIES

  • Plant was shut down for a minor RCS Leak repair.
  • Plant startup is in progress and currently at approximately 2% by Core Differential Temperature (T)

- Simulator T at 100% is 49°F

  • Plant startup per DB-OP-06901, complete through Step 3.24
  • MDFP in service, a spare EO is at FW6396
  • MDFP is NOT required to be kept warm after it is shutdown
  • MDFP will NOT be shutdown for an extended period of time
  • Settling basins are NOT aligned for secondary system drain
  • MFP 2 rotating at 3950 RPM, controlled by ICS in HAND, Steam Supply has been transferred to Main Steam

- An EO is standing by MFP 2 monitoring for proper operation and adjusting LO Temp cooling as needed.

  • Mode 1 checklist is complete
  • Gland Steam on Aux Steam
  • Aux Boiler in service supplying Aux Steam
  • SP13B1 and SP13A1 in service, all other TBVs are disabled closed by isolating their Air Supply Planned following Turnover:
  • Continue a plant startup per DB-OP-06901, starting at Step 3.25

- Transfer feedwater from the MDFP to MFP 2

- Raise Reactor power to 4% in preparation for mode change

  • A Spare RO will log HUR IAW DB-OP-06901 Step 3.17
  • Contact the Field Supervisor when ready to Begin Preparations for Turbine Warming
  • Contact the Field Supervisor when ready to Start Turbine Warming
  • Contact the Field Supervisor when ready to Transfer Aux Steam form the Boiler to Main Steam ALARM STATUS Expected alarms due to plant start-up ZONE 1 - ODMI TRIGGER POINTS ZONE 1 - WORKAROUNDS - None ZONE 1 - BURDENS - None ZONE 2 - ODMI TRIGGER POINTS ZONE 2 - WORKAROUNDS - None ZONE 2 - BURDENS - None ZONE 3 - ODMI TRIGGER POINTS ZONE 3 - WORKAROUNDS - None ZONE 3 - BURDENS - None

Page 2 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST CONTROL ROOM - ODMI TRIGGER POINTS CONTROL ROOM - WORKAROUNDS - None CONTROL ROOM - BURDENS - None CONTROL ROOM - DEFICIENCIES - None OUTAGE-RELATED repairs in the CTRM - None GENERAL STATUS Intake Chlorination (Primary Oxidant) - OOS Intake Actibrom (Oxidant enhancer) - OOS Circwater Chlorination (Primary Oxidant) - Pumps 1 & 3 Circwater Actibrom (Oxidant Enhancer) - I/S Circwater Trasar (Scale inhibitor) - I/S Pumps 1 & 3 Collection Box Sodium Bisulfite (Dechlorinator) - I/S RCS Zinc Injection (Crud Layer Enhancement) - I/S Polishers I/S: 1, 2, 3, 4 MUT press band: 30-40 psig MSD Skid #1: I/S MSR 1 Drains: Forward MSD Skid #2: I/S MSR 2 Drains: Forward

                              • Screen Wash Catch Basin aligned to the North Settling Basin 5/18/2016 ***************

EVOLUTIONS IN PROGRESS - None FOLLOW-UP ITEMS - None

Page 3 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST ACTIVE DB LICENSE REQUIREMENTS (TS, TRM, FHAR, ODCM, FLEX)

Issue Date & Next Action Due Equipment Owner/

Time Specification Action Required Responsible Affected Test Entered Individual Leader FUNCTIONAL EP RELATED EQUIPMENT REQUIRING COMPENSATORY ACTIONS

Appendix D Scenario Outline Form ES-D-1 Facility: Davis-Besse Scenario No.: 2 Op Test No.: DB1LOT21 Examiners: Operators: SRO ATC BOP Initial Conditions:

  • 93% Power
  • #1 EDG is OOS for maintenance Turnover:
  • Reactor Power is at 93% power in preparation to stop #1 Condensate Pump Planned:
  • Stop Condensate Pump 1 for planned PMs
  • Restore #1 EDG to service when maintenance is complete Critical tasks:
1. Restore RCP Seal Return (CT-B)
2. Electrical Power Alignment (CT-8)
3. Initiate High Pressure Injection (HPI) (CT-2)

Event Malf. Event Type* Event No. No. Description 1 N-BOP/SRO Stop Condensate Pump 1 2 I-ATC/BOP/SRO RCS Press NNI input fails low (TS) 3 C-BOP/SRO Circ Pump high stator temperature 4 C-ATC/SRO MU38, RCP Seal Return fails Closed (TS) 5 R-ATC/SRO Small RCS Leak (~275 gpm) into CTMT (TS) 6 M-ALL Loss of Offsite Power/Loss of SCM 7 C-ATC/BOP/SRO EDG 2 trips/HPI fails to Auto start

  • (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, Revision 11 Page 1 of 17

Scenario Event Summary DAVIS-BESSE 2020 NRC SCENARIO 2 The scenario begins with the plant at 93% power in preparation for stopping Condensate Pump 1 for planned PMs. EDG 1 is also OOS for planned maintenance.

EVENT 1 Stop Condensate Pump 1 for PMs After the crew performs a shift turnover briefing, the CSRO will perform a prejob brief and direct the BOP to stop Condensate Pump 1 IAW DB-OP-06221, Condensate System.

EVENT 2 RCS Press NNI input fails low (TS)

Event 2 will be initiated at Leads Evaluators direction. RCS pressure instrument selected for NNI fails low. The crew will implement DB-OP-02513, Pressurizer System Abnormal Operation, for Failure of Pressure Input to Heaters, Spray and PORV. Manual control of heaters will be required due to input pressure signal failing low. The pressure input to NNI will be swapped to the non-faulted signal IAW DB-OP-06403, RPS and NNI Operating Procedure. Heater controls will then be returned to automatic control. The Unit Supervisor will enter Technical Specification 3.3.1 Condition A for the pressure instrument failure. The TS required action will be completed since the channel will already be tripped due to the failure. The SRO should direct bypassing RPS CH 1 to obtain 2 out of 3 RPS Trip Logic. When Technical Specification 3.3.1 Condition A has been entered and at Leads Evaluators direction, proceed to Event 3.

EVENT 3: Circulating Water Pump 1 high stator temperature The crew will identify the problem using computer point data (T110, CWP 1 MTR Stator Temp Hi, and T113, CWP 1 TRBL) and/or response to annunciator 11-3-E, Circ Water Pump Temp Hi.

The crew will refer to alarm procedure DB-OP-02011, Heat Sink Alarm Panel Annunciators. The CSRO will implement abnormal procedure DB-OP-02517, Circ Water System Malfunction. The CSRO will direct the BOP to stop #1 Circ Water Pump. The crew will monitor Condenser Pressure and Reactor Power.

EVENT 4: MU38, RCP Seal Return fails Closed (TS)

At the Lead Evaluators direction, cue event 4, MU38 will fail closed. The crew will recognize a loss of Seal Return flow to all RCPs and implement DB-OP-02515, RCP and Motor Abnormal Operation. After determining an airline is broke, MU38 will be manually opened. (CT-B)

Technical Specifications associated with the failure will be evaluated. When MU38 is open and LCO 3.6.3 is entered, event 5 can be inserted.

EVENT 5: Small RCS Leak (~275 gpm) into CTMT (TS)

The Lead Evaluator will cue event 5, Small RCS Leak in CTMT. The CSRO will implement abnormal procedure DB-OP-02522, SMALL RCS LEAKS. When the crew has begun a down power, T.S 3.4.13 has been addressed, and as directed by the Lead Evaluator, cue event 6, Loss of Offsite Power and LSCM.

EVENT 6 & 7: Loss of Offsite Power/LSCM & EDG 2 Trips/HPI fails to Auto Start The crew will identify a Reactor Trip due to a Loss of Offsite Power and perform Immediate Actions for DB-OP-02000. The crew will identify a Loss of SCM and a loss of both EDGs during Specific Rules Check. EDG 2 tripped immediately after starting. Since EDG 1 is OOS this will cause a station blackout until the BOP starts the Station Blackout Diesel Generator (SBODG) and powers 4160 bus C1 or D1 per Attachment 28 of DB-OP-02000 and Specific Rule 6. (CT-8)

DB-OP-02000 Section 5, Loss of Subcooling Margin will be entered. HPI will fail to Auto start.

HPI will be placed in service after the SBODG is aligned to C1 or D1 bus. (CT-2). When HPI is started, the scenario can be terminated.

NUREG-1021, Revision 11 Page 2 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 1 Page 1 of 1 Event

Description:

Stop Condensate Pump 1 Time Position Applicants Actions or Behavior Indications:

  • HIS558, CONDENSATE PUMP 1 Indicating lights
  • Motor Amps
  • Deaerator Levels
  • Condensate Flow CREW Brief stopping Condensate Pump 1 SRO Direct BOP to stop Condensate Pump 1 Booth Role play as EO as requested Cue Stop Condensate Pump 1 using HIS558 CONDENSATE PUMP 1
  • SRO/BOP IAW DB-OP-06221, Section 3.8 Direct an EO to perform the following:

- Open CD13 CONDENSATE PUMP 1 DISCHARGE SUCTION BOP VENT

- Close CD576 CONDENSATE PUMP 1 OUTLET PRESSURE INDICATOR SOURCE Role play as an EO to perform required actions:

- CD13 CONDENSATE PUMP 1 DISCHARGE SUCTION VENT Booth is OPEN Cue - CD576 CONDENSATE PUMP 1 OUTLET PRESSURE INDICATOR SOURCE is CLOSED

- If asked, all indications are normal At Lead Evaluators direction cue Event 2, RCS Press NNI input fails low NUREG-1021, Revision 11 Page 3 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 2 Page 1 of 2 Event

Description:

RCS Press NNI input fails low (TS)

Time Position Applicants Actions or Behavior Indications Available:

  • 4-4-C HOT LEG PRESS LO
  • 5-3-G RPS RC LO PRESS TRIP
  • 5-3-J RPS RC PRESS-TEMP TRIP
  • Pressurizer Heaters energize Crew Recognize Failure of Pressure Input to Heaters, Spray and PORV Implement DB-OP-02513 Pressurizer System Abnormal Operation SRO Section 4.1 Failure of Pressure Input to Heaters, Spray and PORV Manually control Pressurizer Heaters and Spray to maintain required ATC RCS Pressure (2105 to 2205)

Refer to TS 3.4.1, RCS Pressure, Temperature and Flow DNB Limits -

SRO entry into TS 3.4.1 is not required for this failure Refer to DB-OP-06403 Reactor Protective System (RPS) and Nuclear Instrumentation (NI) Operating Procedure SRO Directs the BOP to,

- Exchange RCS pressure input to NNI from RPS CH 1 to RPS CH 2

- Place RPS CH 1 in Manual Bypass Place the following Pressurizer Heaters in OFF

  • HIS RC2-2, Bank 2
  • HIS RC2-3, Bank 3
  • HIS RC2-4, Bank 4
  • ATC/SRO
  • HIS RC2A, Essen Bank 1
  • HIS RC2B, Essen Bank 2
  • Place PIC RC2 Bank 1 in MANUAL and maintain RCS pressure by adjusting the output NUREG-1021, Revision 11 Page 4 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 2 Page 2 of 2 Event

Description:

RCS Press NNI input fails low (TS)

Time Position Applicants Actions or Behavior Exchange RCS pressure input to NNI from RPS CH 1 to RPS CH 2

  • Remove the cap on the selection panel for the alternate RC PRESSURE NNI receptacle in RPS Channel 2
  • BOP/SRO
  • Disconnect the amphenol connector from the RC PRESSURE NNI subassembly and reconnect the amphenol connector to the alternate RC PRESSURE NNI Receptacle o Cap the open RC PRESSURE NNI receptacle Return PZR heaters to Auto Control
  • HIS RC2-2, Bank 2, in AUTO + BASE
  • HIS RC2-3, Bank 3, in AUTO
  • ATC/SRO
  • HIS RC2-4, Bank 4, in AUTO
  • HIS RC2A, Essen Bank 1, in AUTO
  • HIS RC2B, Essen Bank 2, in AUTO
  • PIC RC2 Bank 1 in AUTO Change panel placard indicating which RPS Channel is now supplying BOP the RCS Pressure input signal panel meter. RPS Channel 2 is now supplying.

Place RPS CH 1 in Manual Bypass

  • Obtain RPS Manual Bypass key and RPS Ch 1 door key
  • Rotate the MANUAL-BYPASS KEY SWITCH to actuate the
  • BOP/SRO manual bypass relay in RPS Channel 1

- Check MANUAL-BYPASS light is BRIGHT

- Check SUB-SYSTEM light is DIM Declare RPS CH 1 inoperable (RC Pressure Inputs)

  • LCO 3.3.1: Four channels of RPS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE
  • CONDITION: A. One channel inoperable o REQUIRED ACTION: A.1 Place channel in bypass or trip o COMPLETION TIME: 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> NOTE: It takes ~4 minutes for 11-3-E CIRC WATER PUMP TEMP HI to come in At Lead Evaluators direction, proceed to Event 3, Circ Pump high stator temperature NUREG-1021, Revision 11 Page 5 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 3 Page 1 of 2 Event

Description:

Circ Pump 1 high stator temperature Time Position Applicants Actions or Behavior Indications Available:

  • 11-3-E CIRC WATER PUMP TEMP HI
  • T113 CWP 1 TRBL Recognize symptoms of high stator temperature on Circulating Water Crew Pump 1 Refer to DB-OP-02011, Heat Sink Alarm Panel Annunciators

- Direct an Equipment Operator to investigate Circ Water Pump 1 BOP locally

- Trend computer point T110 - Recognize temperature rise is >1ºF per minute or Motor Stator temperature of 305°F SRO Implement DB-OP-02517, Circ Water System Malfunction Role play as an EO:

After 3 minutes report Circ Water Pump 1

- Cooling Water Lineups-Normal Booth - Pump and Motor Oil Levels-Normal Cue - Motor Vents for Obstructions are clear but I smell a slight electrical odor coming from the motor vent, theres no smoke.

- Pump or Motor Vibration Levels-Normal Direct stopping Circ Water Pump 1 using DB-OP-02517, Attachment 1, SRO Shutdown of a Loop 1 Circ Water Pump Depress close on both Circ Water Loop 1 Pump Discharge Valves

  • SRO/BOP
  • HIS856, Circ Water Pump 1 Discharge Valve
  • HIS861, Circ Water Pump 2 Discharge Valve When the Circ Water Pump Discharge Valves reach the throttled
  • SRO/BOP position, then
  • depress close on HIS856, Circ Water Pump 1 Discharge Valve NUREG-1021, Revision 11 Page 6 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 3 Page 2 of 2 Event

Description:

Circ Pump 1 high stator temperature Time Position Applicants Actions or Behavior When HIS856, Circ Water Pump 1 Discharge Valve Closed light comes

  • SRO/BOP on, Trip Circ Water Pump 1 using HIS876 ATC Monitor Reactor power NOTE: Cond Pressure will not exceed 5 in HgA IF AT ANY TIME Condenser Pressure exceeds 5.0 inches HgA, ATC THEN reduce Reactor Power to maintain Condenser Pressure less than or equal to 5.0 inches HgA.

SRO Notify Chemistry of the change in alignment Role play as Chemistry:

Booth Realign the Circ Water Chemical Addition System and Cue Chlorination System for Circ Pump 1 shut down SRO Notify SM to review notification and Fleet update requirements At Lead Evaluators direction proceed to Event 4, MU38, RCP Seal Return fails Closed NUREG-1021, Revision 11 Page 7 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 4 Page 1 of 2 Event

Description:

MU38, RCP Seal Return fails Closed Time Position Applicants Actions or Behavior Indications Available:

  • RCP Seal pressure computer alarms
  • MU 38 closed
  • RCP Seal Return Flow Computer Point F783 Critical Recognize a Loss of Seal Return Flow to all RCPs (MU38 Closed)

Task CREW (CT-B) Time MU 38 is closed _________

ATC Attempt to open MU 38 Implement DB-OP-02515, RCP and Motor Abnormal Operation SRO Section 4.5, Loss of RCP Seal Return Flow ATC/BOP Dispatch EO to investigate MU38 Role play as Maintenance Services after the EO is dispatched, Booth Hey, we were down here in #1 MPR building scaffolding and one Cue of the guys stepped on the airline to a valve and broke it. Theres air blowing out of the line. The label says MU38 Booth If asked, Role play as maintenance (~3 min) after investigating, Cue Its going to take about 45 minutes to fix.

Direct an EO to manually open MU38. REFER TO Attachment 4, SRO/ATC Manual Operation to Open MU38

  • SRO/ATC Depress the CLOSED pushbutton on MU38 NUREG-1021, Revision 11 Page 8 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 4 Page 2 of 2 Event

Description:

MU38, RCP Seal Return fails Closed Time Position Applicants Actions or Behavior Role play as EO,

~2 minutes after being notified that MU38 CLOSED pushbutton has been depressed, manually OPEN MU38.

Booth Cue After MU38 is OPEN,

1. Notify the CTRM that MU38 is OPEN
2. Notify the Command SRO to assign a Dedicated Operator to be available to close MU38 in the event of an SFAS Level 3 actuation Critical Check MU38 position Task ATC/SRO Time MU 38 is open _________

(CT-B)

SRO Notify the Shift Manager to complete required notifications CREW Check RCP Seal conditions for proper operation

  • Determine LCO 3.6.3, Each containment isolation valve shall be OPERABLE, for MU38 is NOT met
  • Enter Condition A, One or more penetration flow paths with one containment isolation valve inoperable for reasons other than Condition D or E
  • SRO o REQUIRED ACTION: Isolate the affected penetration flow path by use of at least one closed and de-activated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured o COMPLETION TIME: 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> At Lead Evaluators direction, proceed to Event 5, Small RCS Leak in CTMT NUREG-1021, Revision 11 Page 9 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 5 Page 1 of 2 Event

Description:

Small RCS Leak in CTMT (~275 gpm)

Time Position Applicants Actions or Behavior Indications:

  • MU Tank level lowering
  • MU flow abnormally high
  • Rising Normal Sump level
  • Rising CTMT radiation levels AND pressure TEAM Recognize symptoms of RCS leak in CTMT SRO Route to DB-OP-02522, Small RCS Leaks Monitor Pressurizer level.
  • IF AT ANY TIME Pressurizer level is below set point by more than 20 inches Close MU2B
  • IF Pressurizer Level continues to lower, THEN start the standby MU pump ATC Determine the RCS Leakrate using the computer calculation for RCS Leakage (5 minute average preferred)

Determine LCO 3.4.13 is not met

  • CONDITION A: > 1 gpm unidentified LEAKAGE o REQUIRED ACTION: Reduce LEAKAGE to within limits o COMPLETION TIME: 4 HOURS o Notify the System Control Center (SCC) Load Dispatcher of the unit load reduction o Notify Chemistry to perform the following:

SRO o Monitor Condensate Polisher operation.

o Sample the RCS for an isotopic analysis of Iodine.

o Notify the SM refer to RA-EP-01500, Emergency Classification IF AT ANY TIME Makeup Tank level is approaching 55 inches THEN maintain MU Tank Level 55 to 86 inches by transferring MU Pump ATC Suctions MU3971 and MU6405 between the MU Tank and the BWST as necessary NUREG-1021, Revision 11 Page 10 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 5 Page 2 of 2 Event

Description:

Small RCS Leak in CTMT (~275 gpm)

Time Position Applicants Actions or Behavior ATC/BOP Perform Attachment 4, RCS Leak Location Determination Aid Commence a Plant Shutdown, REFER TO DB-OP-02504, Rapid SRO/ATC Shutdown Determine the power reduction method, target power level, and rate of SRO power reduction Direct the ATC Operator to perform Attachment 1, Power Reduction SRO Actions ICS Full Automatic Direct the Balance of Plant Operator to perform Attachment 6, Balance SRO of Plant Actions for Rapid Shutdown

  • Set the rate of change to the rate specified by the CSRO
  • Select the target RTP as determined by the CSRO
  • ATC/SRO

- Monitor Reactor Power to confirm power is being reduced at approximately the expected rate

- At approximately 90 percent power, notify an Equipment Operator to remove the Auxiliary Feed Pump Turbine Main o BOP o

Steam Minimum flow lines from service When condensate flow is less than 7.0 MPPH (FI578), THEN establish two Condensate pumps in operation NOT REQUIRED TO CLOSE DR2012A AND DR2012B TO CONTINUE SCENARIO o Close DR2012A o ATC o Close DR2012B Determine LCO 3.4.15 is NOT met due to DR2012A and DR2012B being closed

o REQUIRED ACTION: A.2 Restore containment sump monitor to OPERABLE status.

o COMPLETION TIME: 30 days When the RCS Leakage TS has been entered and the down power has commenced and at Lead Evaluators direction, proceed to Events 6 and 7, Loss of Offsite Power/LSCM & EDG 2 Trips/HPI fails to Auto start NUREG-1021, Revision 11 Page 11 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 6&7 Page 1 of 3 Event

Description:

Loss of Offsite Power/LSCM & EDG 2 Trips/HPI fails to Auto start Time Position Applicants Actions or Behavior Indications Available for a Loss of Offsite Power:

  • Loss of Control Room Lighting
  • A and B Bus Source Breakers Open CREW Recognize Reactor Trip due to a Loss of Offsite Power NOTE: C1 or D1 must be energized from the SBODG IAW DB-OP-Critical 02000 SR 6 <10 minutes from a LOOP Task (CT-8)

Time of LOOP_________

NOTE: HPI Flow must be initiated IAW DB-OP-02000 Attachment 8 Critical or SR 3 <15 minutes after SCM is <20°F Task (CT-2)

Time SCM Lost_________

Perform DB-OP-02000 Immediate Actions

  • Trip the reactor ATC - VERIFY Reactor Power is lowering on the Intermediate range
  • Trip the turbine

- VERIFY all Turbine Stop Valves OR Control Valves are closed SRO Implement DB-OP-02000 SRO/ATC Verify Immediate Actions Implement any necessary Specific Rules Actions

- ACTIONS FOR LOSS OF SUBCOOLING MARGIN TEAM

- STEAM GENERATOR CONTROL

- POWER FOR C1 AND D1 BUSES OR EDG START Implement Specific Rule 2

- Verify all RCPs are tripped (Already off due to loss of power)

ATC/BOP Transfer SCM Input to Incore Thermocouples o Ch 1 o Ch 2 NUREG-1021, Revision 11 Page 12 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 6&7 Page 2 of 3 Event

Description:

Loss of Offsite Power/LSCM & EDG 2 Trips/HPI fails to Auto start Time Position Applicants Actions or Behavior Implement Specific Rule 4

- Verify proper AFW actuation BOP - Refer to Attachment 3 for AVV control

- Verify D2 Bus is energized

- Verify an air compressor is running Implement Specific Rule 6

- Recognize C1 and D1 are de-energized

- Recognize EDG 1 is OOS and EDG 2 has a fault ATC

- Dispatch an Equipment Operator to EDG 2

- Route to Attachment 28, Restore Power to C1 or D1 Bus from the SBODG.

BOP may perform Attachment 6 as directed by Attachment 3 or Attachment 5 to energize D2.

Energize D2 Bus by performing Attachment 28, Restore Power to C1 or

  • Critical D1 from the SBODG Task ATC/BOP (CT-8) * *Verify ABDD2 is open

- Verify AD110 is open

  • *Start the SBODG

- Verify AD213 is closed

  • *Close AD 301 Energize C1

- Verify HBBD is open

  • *Close ABDD2
  • *Close ABDC1
  • Critical Task ATC/BOP OR (CT-8)

Energize D1

  • *Close AD110 Time C1 or D1 is energized__________

SRO Route to Section 5, Loss of Subcooling Margin NUREG-1021, Revision 11 Page 13 of 17

Appendix D Operator Action Form ES-D-2 Op Test No.: 2021 Scenario # 2 Event # 6&7 Page 3 of 3 Event

Description:

Loss of Offsite Power/LSCM & EDG 2 Trips/HPI fails to Auto start Time Position Applicants Actions or Behavior Implement Attachment 8, Place MU/HPI/LPI in Service as equipment is available

- Start/Verify running a CCW Pump

  • Critical
  • *Manually start an HPI Pump (auto start is failed)

Task BOP/ATC (CT-2) - Verify Open HP 2A and HP 2B OR HP 2C and HP 2D

- Refer to Attachment 11, HPI Flow Balancing (Not required)

Time HPI Flow is initiated __________

Attachment 8 continued

- Start an LPI Pump

  • Open DH 64 OR DH 63 Transfer a MU Pump suction to the BWST o MU6405 BOP/ATC o MU3971
  • Set Pressurizer Level Controller to 100 inches
  • Close MU 19
  • Close MU 32
  • Start a Makeup Pump
  • Control Pressurizer level using MU 32 or Alt Injection Line Verify proper SFAS actuation for the trip parameters present. Use SAM ATC/SRO lights (on DIM) OR REFER TO Table 2

- Direct the dedicated operator to Close MU38 Booth Role play as an EO ~ 1 minute after directed to close MU38 Cue MU38 is closed Verify proper SFRCS actuation for the trip parameters present. REFER BOP TO Table 1 Verify proper SG level control by AFW using Specific Rule 4, Steam BOP Generator Control When DB-OP-02000, Attachment 8, Place HPI/LPI/MU in Service is complete the Scenario may be terminated at Lead Evaluators discretion NUREG-1021, Revision 11 Page 14 of 17

Justification for Critical Tasks The term Critical Task, is defined in NUREG-1021, OPERATOR LICENSING EXAMINER STANDARDS FOR POWER REACTORS. The listed critical tasks were compiled based on a review of Areva Technical Document 47-1229003-06, EOP Technical Bases Document, and additional CTs were added based on established DB Operations expectations and standards for previously identified Critical Task.

CT-B: Protect RCP Seals

1. Safety Significance:

MU38 failing closed will result in a loss of seal return flowpath. Extended operation without a RCP Seal Return flowpath may result in seal failure and unisolable RCS leakage.

2. Cues:
  • Loss of seal return flow as indicated by MU38 closed and RCPs running
  • DB-OP-02515, REACTOR COOLANT PUMP AND MOTOR ABNORMAL OPERATION and DB-OP-02000 Attachment 10
3. Measured by:
  • Time zero for CT-B is when MU38 goes closed
  • The required action to complete CT-B is to restore Seal Return
  • The required end time for completion of CT-B is 30 minutes
4. Feedback:
  • MU38 is manually opened from the field
  • Seal Return Flow is restored CT-8: Electrical Power Alignment
1. Safety Significance:

Loss of Emergency Diesel Generator (EDG) 2 with a loss of off-site power and EDG 1 out of service results in a station blackout.

2. Cues:
  • Loss of Control Room Lighting
  • A and B Bus Source Breakers Open
  • C1 and D1 are de-energized by observing associated voltage meters
  • DB-OP-02000 Specific Rule 6
3. Measured by:
  • Time zero for CT-8 is the LOOP
  • Required action to complete CT-8 is to energize C1 or D1 with the SBODG
  • The required end time for completion of CT-8 is 10 minutes
  • ELAP Time Sensitive Operator Action = 10 minutes
4. Feedback:
  • C1 or D1 energized NUREG-1021, Revision 11 Page 15 of 17

CT-2: Initiate High Pressure Injection

1. Safety Significance:

The Reactor Coolant System Leak that develops following the loss of off-site power will result in a loss of subcooling margin.

2. Cues:
  • DB-OP-02000 Specific Rule 3 or Attachment 8
3. Measured by:
  • Time zero for CT-2 is when SCM <20°F on either SCM meter
  • Required action to complete CT-2 is to place available HPI flow in service per DB-OP-02000, SR 3 or Attachment 8
  • The required end time for completion of CT-2 <15 minutes after Loss of SCM
  • 15 minutes based on established DB Operations expectations and standards
4. Feedback:

Available HPI Pump indicating lights, amp meter, and HPI flow NUREG-1021, Revision 11 Page 16 of 17

SIMULATOR SETUP INFORMATION

1. Simulator Setup
  • Protected Train 2
  • Makeup Pump 1 in service
  • HPI 1 and 2 fail to auto start
  • Verify operator aid for the intake structure is correct
  • Verify correct NNI RPS CH placard for RCS Pressure is CH 1
  • Place Caution Tag sticker on EDG 1
2. Procedures
  • DB-OP-06221, Condensate System
  • DB-OP-02513, Pressurizer System Abnormal Operation
  • DB-OP-06403, Reactor Protective System (RPS) and Nuclear Instrumentation (NI) Operating Procedure
  • DB-OP-02011, Heat Sink Alarm Panel
  • DB-OP-02515, RCP and Motor Abnormal Operation
  • DB-OP-02522, Small RCS Leaks
  • DB-OP-02504, Rapid Shutdown
  • DB-OP-02000, RPS, SFAS, SFRCS Trip or SG Tube Rupture
3. Procedures for the Simulator Driver None required NUREG-1021, Revision 11 Page 17 of 17

Page 1 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST DATE: Today SHIFT: NIGHTS MODE: 1 POWER: 93%

SECURITY RISK: GREEN PLANT ONLINE RISK: GREEN PROTECTED TRAIN: 2 PLANT CONDITION: 1 SHUTDOWN DEFENSE-IN-DEPTH:

ACTIVE ALERTS: NONE GRID CONDITION: NORMAL N/A ADDITIONAL PROTECTED EQUIPMENT - AD301, D2, and SBODG CONTINGENCY PLANS FOR OPERABILITY/AVAIL IN EFFECT - None OUTSTANDING PROMPT OPERABILITY DETERMINATIONS - None SHIFT ACTIVITIES COMPLETED Reactor Power at 93% to support stopping Condensate Pump 1 for Maintenance PLANNED After Turnover, Stop Condensate Pump 1 Restore EDG 1 when maintenance is complete ALARM STATUS -None ZONE 1 - ODMI TRIGGER POINTS -None ZONE 1 - WORKAROUNDS - None ZONE 1 - BURDENS - None ZONE 2 - ODMI TRIGGER POINTS -None ZONE 2 - WORKAROUNDS - None ZONE 2 - BURDENS - None ZONE 3 - ODMI TRIGGER POINTS -None ZONE 3 - WORKAROUNDS - None ZONE 3 - BURDENS - None CONTROL ROOM - ODMI TRIGGER POINTS-None CONTROL ROOM - WORKAROUNDS-None CONTROL ROOM - BURDENS - None CONTROL ROOM - DEFICIENCIES -None OUTAGE-RELATED repairs in the CTRM

Page 2 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST GENERAL STATUS Intake Chlorination (Primary Oxidant) - OOS Intake Actibrom (Oxidant enhancer) - OOS Circwater Chlorination (Primary Oxidant) - Pumps 1 & 3 Circwater Actibrom (Oxidant Enhancer) - I/S Circwater Trasar (Scale inhibitor) - I/S Pumps 1 & 3 Collection Box Sodium Bisulfite (Dechlorinator) - I/S RCS Zinc Injection (Crud Layer Enhancement) - I/S Polishers I/S: 1, 2, 3, 4 MUT press band: 30-40 psig MSD Skid #1: I/S MSR 1 Drains: Forward MSD Skid #2: I/S MSR 2 Drains: Forward

                              • Screen Wash Catch Basin aligned to the North Settling Basin 5/18/2016 ***************

EVOLUTIONS IN PROGRESS - None FOLLOW-UP ITEMS-None

Page 3 of 3 SHIFT MGR/UNIT/FIELD SUPERVISOR/SHIFT ENGINEER TURNOVER CHECKLIST ACTIVE DB LICENSE REQUIREMENTS (TS, TRM, FHAR, ODCM, FLEX)

Date & Next Action Due Equipment Issue Owner/

Time Specification Action Required Responsible Affected Test Leader Entered Individual B1: 5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> from now B.1 Perform SR 3.8.1.1 for OPERABLE offsite circuit(s).

Yesterday EDG 1 3.8.1 Condition B B4: 6 days at 0700 Mech Maint 0700 B.4 Restore EDG to OPERABLE status.

FUNCTIONAL EP RELATED EQUIPMENT REQUIRING COMPENSATORY ACTIONS

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