ML17188A280

Exam Final Items - Delay Release 2 Yrs

ML17188A280
Person / Time
Site:	McGuire, Mcguire
Issue date:	07/07/2017
From:	NRC/RGN-II
To:
References
Download: ML17188A280 (430)

Text

Appendix D Scenario Outline Form ES-D-1 Final (Rev_032116)

Facility: McGuire Scenario No.: 2 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 90% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B. MCB Annunciator 1AD-8, A-4, CF PUMP DISCHARGE HI PRESS, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Event Malf. Event Type* Event No. No. Description 1 1 C-BOP VCT Level Channel 1 fails HIGH C-SRO 2 2 I-BOP 1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE I(TS)-SRO 3 3 C-RO 1SA48 fails OPEN/TDCA Pump starts inadvertently C(TS)-SRO 4 NA R-RO Rapid Downpower N-BOP N-SRO 5 4 C-RO Turbine Control Unit fails to MANUAL C-SRO 6 5 C-BOP High Vibration on 1B NCP C-SRO 7 6 M-RO Premature FWIS/Failure of Main Turbine to Trip/Failure of Main M-BOP Steam Line Isolation M-SRO 8 6 NA Overspeed Trip of TDCA Pump 9 6 NA 1A MDCA Pump trips upon Auto Start

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 Final (Rev_032116)

McGuire 2016 NRC Scenario #2 The plant is at 90% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B. MCB Annunciator 1AD-8, A-4, CF PUMP DISCHARGE HI PRESS, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Shortly after taking the watch, the VCT Level Channel 1 will fail HIGH. The operator will respond in accordance with MCB Annunciator 1AD-2, F8, DCS ALTERNATE ACTION, and go to OP/1/A/6102/003, DCS System Operation, Enclosure 4.1, Removing/Returning a VCT Level Channel From/To Service.

Next, 1EMF-38, Containment Particulate Radiation Monitor, will fail HIGH, although the VQ valves will fail to automatically CLOSE. The operator will respond in accordance with OP/1/A/6100/010 Q, Annunciator Response for 1RAD-1, A-1, 1EMF 38 CONTAINMENT PART HI RAD, and manually terminate the Containment Release. The operator may enter Case I of AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps. The crew will determine that the alarm is due to a failure, and NOT an actual high radioactivity condition. The operator will address Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation.

Following this, 1SA48 will fail OPEN causing the TDCA Pump to start. The crew will recognize that reactor power is rising, and that the pump should not be running, and take action to reduce Turbine load and isolate CA flow to the Steam Generators per the Crew Expectation Manual. The operator will be unable to locally isolate steam to the TDCA pump and leave the CA throttle valves closed. The operator will address Technical Specification LCO 3.7.5, Auxiliary Feedwater (AFW)

System, which will require a plant shutdown, and SLC 16.9.7, Standby Shutdown System. The operator may use AP/1/A/5500/1, Steam Leak, to diagnose the failure, and if so, use OP/1/A/6250/002, Auxiliary Feedwater System, in an attempt to stop the pump. Ultimately, the crew will enter AP/1/A/5500/4, Rapid Downpower.

During the downpower, a failure will occur in the Turbine Control Unit causing the unit to shift from Operator Auto to Manual control. The operator will address 1AD-1/F-4, TURBINE IN MANUAL, and control the Turbine manually during the downpower in accordance with OP/1/A/6300/001A, .1, Turbine Generator Load Change.

After this, a high vibration condition will develop on the 1B NCP. The operator will respond in accordance with OAC Alarm M1D3041, 1B NC PUMP VIBRATION (HALM), and enter AP/1/A/5500/08, Malfunction of NC Pump. Ultimately, the vibration condition will rise above the Hi-Hi threshold requiring tripping of the reactor and stopping the NCP. The operator will manually trip the reactor and enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection.

Following the plant trip, a Feedwater Isolation Signal (FWIS) will occur prematurely, the Main Turbine will fail to trip automatically or manually, and the Main Steam Line Isolation signal will fail to automatically actuate. The operator will be required to either manually close the Turbine Governor Valves or the MSIVs. It is likely that SI will actuate due to the delayed Turbine isolation.

Appendix D Scenario Outline Form ES-D-1 Final (Rev_032116)

At the same time, the TDCA Pump, if not already running, will start on low Steam Generator levels.

If the TDCA Pump was not running at the start of the event, it will trip on overspeed upon startup.

If the TDCA Pump was running at the start of the event, it will trip when the operator initiates flow to the Steam Generators. Furthermore, the 1A MDCA Pump will trip on overcurrent during pump startup, and any attempts to restart the pump will be unsuccessful. Consequently, a Red Path on Heat Sink will occur shortly after SI actuation, or upon the transition to EP/1/A/5000/ES-0.1, Reactor Trip Response. The operator will transition from EP/1/A/5000/E-0 to EP/1/A/5000/FR-H.1, Response to Loss of Secondary Heat Sink.

The operator will eventually restore feed flow using a CF Pump in accordance with Enclosure 8 (Re-establishing CF Flow) of FR-H.1, and the scenario will terminate.

Critical Tasks:

Trip the Reactor prior to stopping the NCP during a high vibration condition, and trip the NCP only after Reactor power level has dropped to less than 5%.

Safety Significance: The P-8 interlock allows one NCP to be stopped less than 48% power. If a NCP is stopped in Mode 1 or 2, Tech Spec 3.4.4 requires the unit to be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

In addition, T-ave for the idle loop may violate Tech Spec 3.4.2, minimum temperature for criticality. In this case, the unit must be sub-critical within 30 minutes. The transient placed on the unit when a NCP is secured at power can challenge both reactor protection and control systems.

Furthermore, an added burden is placed on the operator to stabilize the unit and shut down within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (possibly 30 minutes) to comply with Tech Specs. Even though the plant is designed and analyzed to operate in this configuration for a short time, station management has decided that the conservative approach to dealing with this transient is to trip the reactor anytime a NCP malfunction warrants stopping a pump in Mode 1 or 2. Guidance is given to wait until reactor power is less than 5% before stopping the NC pump. This will ensure the NC pump will provide adequate flow/core cooling until reactor power is sufficiently low enough to preclude a challenge to fuel integrity. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

Manually close the Main Turbine Governor Valves and establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24% (36%).

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, and failure to establish feedwater flow into at least one Steam Generator results in the crew having to rely upon the lower-priority action of having to initiate RCS Bleed and Feed to minimize the possibility of core uncovery. Failure to perform this task, when able to do so, constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers.

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class 16-1 TOPIC: NRC Simulator Exam Scenario N16-1-2

REFERENCES:

1. OP/1/A/6100/010 N, Annunciator Response for Panel 1AD-13 (Rev 78)

2. Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation (Amendment 235/217)

3. Technical Specification LCO 3.7.5, Auxiliary Feedwater (AFW) System (Amendment 221/203)

4. OP/1/A/6100/010 C, Annunciator Response for Panel 1AD-2 (Rev 5

5. OP/1/A/6102/003, DCS System Operation (Rev 10)

6. OP/1/A/6100/010 Q, Annunciator Response for Panel 1RAD-1 (Rev 66)

7. AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps (Rev 23)

8. Control Room Crew Expectations Manual (Rev 8/8/12)

9. AP/1/A/5500/1, Steam Leak (Rev 18)

10. OP/1/A/6250/002, Auxiliary Feedwater System (Rev 129)

11. SLC 16.9.7, Standby Shutdown System (Rev 145)

12. Technical Specification LCO 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits (Amendment 219/201)

13. AP/1/A/5500/04, Rapid Downpower (Rev 28)

14. OP/1/A/6100/010 B, Annunciator Response for Panel 1AD-1 (Rev 48)

15. OP/1/A/6300/001A, Turbine Generator Load Change (Rev 12)

16. AP/1/A/5500/08, Malfunction of NC Pump (Rev 14)

17. EP/1/A/5000/E-0, Reactor Trip or Safety Injection (Rev 34)

18. EP/1/A/5000/ES-0.1, Reactor Trip Response (Rev 42)

19. EP/1/A/5000/F-0, Critical Safety Function Status Trees (Rev 6)

20. EP/1/A/5000/FR-H.1, Response to Loss of Secondary Heat Sink (Rev 19)

Validation Time: 103 minutes Author: David Lazarony, Essential Training & Consulting, LLC Facility Review: ________________________

Rev. 032116 Scenario Event Description NRC Scenario 2 Facility: McGuire Scenario No.: 2 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 90% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B. MCB Annunciator 1AD-8, A-4, CF PUMP DISCHARGE HI PRESS, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Event Malf. Event Type* Event No. No. Description 1 1 C-BOP VCT Level Channel 1 fails HIGH C-SRO 2 2 I-BOP 1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE I(TS)-SRO 3 3 C-RO 1SA48 fails OPEN/TDCA Pump starts inadvertently C(TS)-SRO 4 NA R-RO Rapid Downpower N-BOP N-SRO 5 4 C-RO Turbine Control Unit fails to MANUAL C-SRO 6 5 C-BOP High Vibration on 1B NCP C-SRO 7 6 M-RO Premature FWIS/Failure of Main Turbine to Trip/Failure of Main M-BOP Steam Line Isolation M-SRO 8 6 NA Overspeed Trip of TDCA Pump 9 6 NA 1A MDCA Pump trips upon Auto Start

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 2 McGuire 2016 NRC Scenario #2 The plant is at 90% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B. MCB Annunciator 1AD-8, A-4, CF PUMP DISCHARGE HI PRESS, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Shortly after taking the watch, the VCT Level Channel 1 will fail HIGH. The operator will respond in accordance with MCB Annunciator 1AD-2, F8, DCS ALTERNATE ACTION, and go to OP/1/A/6102/003, DCS System Operation, Enclosure 4.1, Removing/Returning a VCT Level Channel From/To Service.

Next, 1EMF-38, Containment Particulate Radiation Monitor, will fail HIGH, although the VQ valves will fail to automatically CLOSE. The operator will respond in accordance with OP/1/A/6100/010 Q, Annunciator Response for 1RAD-1, A-1, 1EMF 38 CONTAINMENT PART HI RAD, and manually terminate the Containment Release. The operator may enter Case I of AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps. The crew will determine that the alarm is due to a failure, and NOT an actual high radioactivity condition. The operator will address Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation.

Following this, 1SA48 will fail OPEN causing the TDCA Pump to start. The crew will recognize that reactor power is rising, and that the pump should not be running, and take action to reduce Turbine load and isolate CA flow to the Steam Generators per the Crew Expectation Manual.

The operator will address Technical Specification LCO 3.7.5, Auxiliary Feedwater (AFW)

System, which will require a plant shutdown, and SLC 16.9.7, Standby Shutdown System.

The operator may use AP/1/A/5500/1, Steam Leak, to diagnose the failure, and if so, use OP/1/A/6250/002, Auxiliary Feedwater System, in an attempt to stop the pump. Ultimately, the crew will enter AP/1/A/5500/4, Rapid Downpower.

During the downpower, a failure will occur in the Turbine Control Unit causing the unit to shift from Operator Auto to Manual control. The operator will address 1AD-1/F-4, TURBINE IN MANUAL, and control the Turbine manually during the downpower in accordance with OP/1/A/6300/001A, Enclosure 4.1, Turbine Generator Load Change.

After this, a high vibration condition will develop on the 1B NCP. The operator will respond in accordance with OAC Alarm M1D3041, 1B NC PUMP VIBRATION (HALM), and enter AP/1/A/5500/08, Malfunction of NC Pump. Ultimately, the vibration condition will rise above the Hi-Hi threshold requiring tripping of the reactor and stopping the NCP. The operator will manually trip the reactor and enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection.

Following the plant trip, a Feedwater Isolation Signal (FWIS) will occur prematurely, the Main Turbine will fail to trip automatically or manually, and the Main Steam Line Isolation signal will fail to automatically actuate. The operator will be required to either manually close the Turbine Governor Valves or the MSIVs. It is likely that SI will actuate due to the delayed Turbine Scenario Event Description NRC Scenario 2 isolation. At the same time, the TDCA Pump, if not already running, will start on low Steam Generator levels. If the TDCA Pump was not running at the start of the event, it will trip on overspeed upon startup. If the TDCA Pump was running at the start of the event, it will trip when the operator initiates flow to the Steam Generators. Furthermore, the 1A MDCA Pump will trip on overcurrent during pump startup, and any attempts to restart the pump will be unsuccessful. Consequently, a Red Path on Heat Sink will occur shortly after SI actuation, or upon the transition to EP/1/A/5000/ES-0.1, Reactor Trip Response. The operator will transition from EP/1/A/5000/E-0 to EP/1/A/5000/FR-H.1, Response to Loss of Secondary Heat Sink.

The operator will eventually restore feed flow using a CF Pump in accordance with Enclosure 8 (Re-establishing CF Flow) of FR-H.1, and the scenario will terminate.

Critical Tasks:

Trip the Reactor prior to stopping the NCP during a high vibration condition, and trip the NCP only after Reactor power level has dropped to less than 5%.

Safety Significance: The P-8 interlock allows one NCP to be stopped less than 48% power. If a NCP is stopped in Mode 1 or 2, Tech Spec 3.4.4 requires the unit to be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. In addition, T-ave for the idle loop may violate Tech Spec 3.4.2, minimum temperature for criticality. In this case, the unit must be sub-critical within 30 minutes. The transient placed on the unit when a NCP is secured at power can challenge both reactor protection and control systems. Furthermore, an added burden is placed on the operator to stabilize the unit and shut down within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (possibly 30 minutes) to comply with Tech Specs. Even though the plant is designed and analyzed to operate in this configuration for a short time, station management has decided that the conservative approach to dealing with this transient is to trip the reactor anytime a NCP malfunction warrants stopping a pump in Mode 1 or 2. Guidance is given to wait until reactor power is less than 5% before stopping the NC pump. This will ensure the NC pump will provide adequate flow/core cooling until reactor power is sufficiently low enough to preclude a challenge to fuel integrity. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

Manually close the Main Turbine Governor Valves and establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24%

(36%).

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, and failure to establish feedwater flow into at least one Steam Generator results in the crew having to rely upon the lower-priority action of having to initiate RCS Bleed and Feed to minimize the possibility of core uncovery. Failure to perform this task, when able to do so, constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers.

Scenario Event Description NRC Scenario 2 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Sim. Setup Rod Step On Reset to Temp IC 236 T = 0 Malfunctions:

Initiate a Containment Release per Enclosure 4.2 of OP/1/A/6450/17.

insert XMT-WL_1WLLT5591 = 100 (1WLL-5591, VUCDT Tank Level is OOS) insert LOA-CA010 = RACKED OUT; insert LOA-CA010A = RACKED OUT; (1B MDCA Pump is OOS) insert OVR-1AD8_A04 = ON (MCB Annunciator 1AD8/A4)

Per Lesson Plan 2016 NRC Exam Scenario 2 insert MAL-DEH008A TRUE cd='h_x10_280_4 eq 1' (DEH Switch to Manual - triggered from 1NV-265B open light ON) insert MAL-ISE007A ACT_AUTO cd='H_X01_094_2 EQ 1' (Automatic FWI Train A occurs on Reactor Trip Breaker Open Indicating Light) insert MAL-ISE007B ACT_AUTO cd='H_X01_094_2 EQ 1' (Automatic FWI Train B occurs on Reactor Trip Breaker Open Indicating Light) insert MAL-ISE007A INACTIVE cd='H_X02_102_2 EQ 1' (Remove signal after insertion) insert MAL-ISE007B INACTIVE cd='H_X02_110_2 EQ 1' (Remove signal after insertion) insert MAL-CA009A TRUE cd='H_X10_077_4 EQ 1' delay=0 (MD CA Pump 1A trips on overcurrent after pump ON light actuates) insert MAL-CA005 TRIP cd='H_X01_094_2 EQ 1' delay=0 insert MAL-SM029 = 0, cd=H_X01_094_2 EQ1 (TDCA Overspeed Trip occurs and Breaker Open Indicating Light, 1SA-3 fails CLOSED on Reactor Trip) insertMAL-DEH003A = TRUE (Main Turbine fails to Auto Trip) insertMAL-DEH003B = TRUE (Main Turbine fails to Manually Trip) insertMAL-ISE006A = BLK_AUTO (MSI Fails in AUTO)

Scenario Event Description NRC Scenario 2 Bench Mark ACTIVITY DESCRIPTION insertMAL-ISE006B = BLK_AUTO (MSI Fails in AUTO)

RUN Place Tagout/O-Stick on:

1B MDCA Pump (Tagout)

Reset all SLIMs 1WLL-5591 (O-stick)

MCB Annunciator 1AD-13, C-7 (O-stick)

MCB Annunciator 1AD-8, A-4 (O-stick)

Update Status Board, NOTE: RMWST DO = <1000 ppb.

Setup OAC Freeze.

Update Fresh Tech.

Spec. Log.

Fill out the AO's Available section of Shift Turnover Info.

Prior to Crew RUN Briefing Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Direct the crew to Review the Control Boards taking note of present conditions, alarms.

4. Provide the crew with an In-progress copy of Enclosure 4.2 of OP/1/A/6450/17.

T-0 Begin Familiarization Period At direction of Execute Lesson Plan examiner for Simulator Scenario N16-1-2.

Scenario Event Description NRC Scenario 2 Bench Mark ACTIVITY DESCRIPTION At direction of Event 1 VCT Level Channel 1 fails HIGH examiner insertXMT-NV_1NVLT5760 = 100 At direction of Event 2 1EMF-38 (LO) fails HIGH/VQ valves fail to Auto examiner CLOSE insert EMF-38L = 10 (5 4

seconds delayed) insert MAL-ISE008A/B

= BLK Insert 1AD9_F08=ON (6 seconds delayed)

At direction of Event 3 1SA48 fails OPEN/TDCA Pump starts examiner inadvertently insert REM-SA0048ABC = 1.0 NOTE: Locally Close 1SA-1 if directed: insert REM-SA0001 = 0 Upon Crew Event 4 Rapid Downpower Entry into AP4 At direction of Event 5 Turbine Control Unit fails to MANUAL examiner insert DEH008A (Turbine Control Fails to MANUAL) Set in initial conditions.

Triggered from 1NV-265B open light ON.

At direction of Event 6 High Vibration on 1B NCP examiner insertMAL-NCP003B=4.6 (HI Vibration Alarm) insertMAL-NCP003B=5.1 cd =

X05_001e11_1 = 1 (Hi Vibration Alarm Ramp

= 360 seconds) (HI-HI Vibration Alarm)

Scenario Event Description NRC Scenario 2 Bench Mark ACTIVITY DESCRIPTION At direction of Event 7 Premature FWIS/Failure of Main Turbine to examiner Trip/Failure of Main Steam Line Isolation insert ISE007A/B (FWIS actuates) Set in initial These malfunctions will occur on Reactor Trip.

conditions. Triggered from Rx trip.

NOTE: Start 2A RN Pump and throttle flow:

insert DEH003A/B insertLOA-RN088 = ON (Main Turbine fails to insert LOA-RN084 = 8000.0024 trip) Set in initial conditions.

Post-Rx Trip Event 8 Overspeed Trip of TDCA Pump insert CA005 and SM- This malfunction will occur on Reactor Trip.

029 Set in initial conditions.

Post-Rx Trip Event 9 1A MDCA Pump trips upon Auto Start insert CA009 This malfunction will occur on Reactor Trip.

Set in initial conditions.

Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 1 Page 9 of 74 Event

Description:

VCT Level Channel 1 fails HIGH Shortly after taking the watch, the VCT Level Channel 1 will fail HIGH. The operator will respond in accordance with MCB Annunciator 1AD-2, F8, DCS ALTERNATE ACTION, and go to OP/1/A/6102/003, DCS System Operation, Enclosure 4.1, Removing/Returning a VCT Level Channel From/To Service.

Booth Operator Instructions: insert XMT-NV_1NVLT5760 = 100 Indications Available:

• MCB Annunciator 1AD-7 D3, VCT ABNORMAL (Momentary)

• MCB Annunciator 1AD-2 E8, DCS TROUBLE

• MCB Annunciator 1AD-2 F8, DCS Alternate Action

• VCT Level (1NVP-5760) indicates 100%

• VCT Level (1NVP-5763) indicates that the level is lowering.

• VCT Level SLIMs shifts into MANUAL Time Pos. Expected Actions/Behavior Comments NOTE: The BOP may address ARP for 1AD-7, D3.

NOTE: The CRS may direct the BOP to place 1NV-137 to VCT position.

MCB ANNUNCIATOR 1AD-2, F8 DCS ALTERNATE ACTION CRS (Step 1) Halt any power change in progress.

BOP (Step 2) Check DCS Workstation alarms.

DCS WORKSTATION ALARMS M1D1168, VCT LEVEL ALTERNATE ACTION BOP (Step 1) Manually control VCT level at desired value.

CRS (Step 2) Write work request and investigate repair.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 1 Page 10 of 74 Event

Description:

VCT Level Channel 1 fails HIGH Time Pos. Expected Actions/Behavior Comments CRS (Step 3) GO TO OP/1/A/6102/003 (DCS System Operation).

NOTE: The CRS will transition to OP/1/A/6102/003.

OP/1/A/6102/003, DCS SYSTEM OPERATION ENCLOSURE 4.1, REMOVING/RETURNING A VCT LEVEL CHANNEL FROM/TO SERVICE BOP (Step 3.1) Performing the following section, as applicable:

• Section 3.2, Respond To An Alternate Action.

BOP (Step 3.2) Respond To An Alternate Action

• On DCS Boric Acid Blender graphic, perform the following:

• Select 2XS for VCT Level 1.

• Determine which level transmitter is NOT faulted.

NVAA 5760 (Transmitter A)

NVAA 5761 (Transmitter B) NOTE: NVAA 5761 (Transmitter B) is NOT faulted.

• Select the non-faulted level NOTE: The BOP will select transmitter for VCT level input Transmitter B.

(Transmitter A or Transmitter B).

• Select DEV MRE INHIBIT to block the deviation input.

• Check MRE BLOCKED lit (blinking red).

BOP

• On DCS Boric Acid Blender Graphic, perform the following:

• Select 2XS for VCT Level 2.

• Determine which level transmitter is NOT faulted.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 1 Page 11 of 74 Event

Description:

VCT Level Channel 1 fails HIGH Time Pos. Expected Actions/Behavior Comments NVAA 5761 (Transmitter A) NOTE: NVAA 5761 (Transmitter A) is NOT faulted.

NVAA 5760 (Transmitter B)

• Select the non-faulted level NOTE: The BOP will transmitter for VCT level input recognize that Transmitter A is (Transmitter A or Transmitter B). selected.

• Select DEV MRE INHIBIT to block the deviation input.

• Check MRE BLOCKED lit (blinking red).

NOTE: An Auto Makeup may occur once the crew removes the faulty instrument from service.

BOP

• On DCS Boric Acid Blender graphic, perform the following:

• Select NV-137A (VCT Level)

• Ensure NV-137A is in auto CRS

• WHEN VCT Level Channel has been NOTE: The CRS may call repaired, go to Section 3.4. WCC/IAE to address the malfunction.

If so, Booth Instructor acknowledge as WCC.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 12 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Next, 1EMF-38, Containment Particulate Radiation Monitor, will fail HIGH, although the VQ valves will fail to automatically CLOSE. The operator will respond in accordance with OP/1/A/6100/010 Q, Annunciator Response for 1RAD-1, A-1, 1EMF 38 CONTAINMENT PART HI RAD, and manually terminate the Containment Release. The operator may enter Case I of AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps. The crew will determine that the alarm is due to a failure, and NOT an actual high radioactivity condition. The operator will address Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation.

Booth Operator Instructions: Insert EMF-38L = 104 (5 seconds delayed)

Insert MAL-ISE008A/B = BLK Insert 1AD9_F08=ON (6 seconds delayed)

Indications Available:

• 1EMF-38 in TRIP 2

• MCB Annunciator 1RAD1-A1, 1EMF 38 CONTAINMENT PART HI RAD, is LIT

• MCB Annunciator 1RAD1-E2, 1EMF CONTAINMENT PARTS

• MCB Annunciator 1AD9-F8, CONT VENT ISOL

• 1VQ-1A Red light is LIT, Green light is OFF

• 1VQ-2B Red light is LIT, Green light is OFF Time Pos. Expected Actions/Behavior Comments OP/1/A/6100/010 Q, ANNUNCIATOR RESPONSE FOR 1RAD-1 A-1, 1EMF 38 CONTAINMENT PART HI RAD RO (IA Step 1) IF VP in operation, NOTE: VP is NOT in operation.

BOP (IA Step 2) Ensure VQ valves are closed to NOTE: The VQ Valves should prevent possible release. have closed, but a failure has prevented this. The BOP will need to manually close the VQ Valves.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 13 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments CRS (SA Step 1) Notify RP to perform trending for NOTE: The CRS may call RP source term identification and leak location. to address the Rad Monitor failure.

If so, Booth Instructor acknowledge as RP. After five minutes report back that there is no abnormal radiation and that it is believed that 1EMF-38 has failed high.

CRS (SA Step 2) IF VP in operation, NOTE: VP is NOT in operation.

CRS (SA Step 3) WHEN informed by RP that NOTE: EMF-38L will remain Containment purge OR air release is failed throughout the permissible, perform the following: remainder of the scenario.

• Ensure "1EMF 38 CONTAINMENT PART HI RAD" alarm is clear.

• Reset Containment Ventilation isolation.

• Startup VP per OP/1/A/6450/015 (Containment Purge System) OR VQ per OP/1/A/6450/017 (Containment Air Release and Addition System), if desired.

CRS (SA Step 4) IF Trip 2 alarm is valid, NOTE: It will ultimately be determined that the Trip 2 alarm is invalid.

CRS (SA Step 5) IF 1EMF-38 is declared NOTE: Ultimately, 1EMF-38L inoperable, perform PT/1/A/4200/040 will be declared inoperable, (Reactor Coolant Leakage Detection) as and this action will be required.

required.

NOTE: The CRS may enter AP-10 believing that an NCS leak exists.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 14 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/10, NC SYSTEM LEAKAGE WITHIN THE CAPACITY OF BOTH NV PUMPS, CASE I NOTE: After the RP has reported that it is suspected that 1EMF-38(L) has failed high, the operator may suspend use of AP-10.

BOP (Step 1) Check leak - KNOWN TO BE IN NOTE: There is no NCS leak.

THE AUX BUILDING.

BOP (Step 2) Check Pzr level - STABLE OR NOTE: Pzr level will be stable.

GOING UP.

CRS/ (Step 3) IF AT ANY TIME while in this NOTE: This is a Continuous BOP procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN perform Step 2. both board operators aware.

RO/ (Step 4) Check Pzr pressure - STABLE OR BOP IF TRENDING TO 2235 PSIG.

RO/ (Step 5) Check main steam line intact as BOP follows:

• Reactor power - AT TURBINE POWER

• NC Loop T-Avg - STABLE.

CRS (Step 6) Announce occurrence on page. NOTE: CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

RO/ (Step 7) Estimate leak rate using any of the NOTE: There is no NCS leak.

BOP following methods:

Monitor OAC NV graphic OR Compare charging flow to letdown flow plus seal return flow

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 15 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments OR Monitor VCT level trend (OAC point M1P1271).

CRS (Step 8) REFER TO the following:

• RP/0/A/5700/000 (Classification of Emergency)

• RP/0/A/5700/010 (NRC Immediate Notification Requirements).

CRS (Step 9) IF AT ANY TIME NC leakage NOTE: This is a Continuous exceeds Tech Spec limits, THEN perform the Action. The CRS will make following: both board operators aware.

• Ensure Outside Air Pressure Filter Train in service PER OP/0/A/6450/011 (Control Area Ventilation/Chilled Water System),

Enclosure 4.4 (Control Room Atmosphere Pressurization During Abnormal Conditions).

• Have another SRO evaluate if leakage exceeds SLC 16.9.7 condition C limits and immediately notify Security if SSF is inoperable.

CRS (Step 10) IF AT ANY TIME VCT level goes NOTE: This is a Continuous below 16% (VCT ABNORMAL LEVEL Action. The CRS will make alarm (1AD-7, D-3) low setpoint), THEN align both board operators aware.

NV pump suction to FWST BOP (Step 11) IF AT ANY TIME Containment NOTE: This is a Continuous pressure exceeds Tech Spec limit (0.3 Action. The CRS will make PSIG), THEN evaluate placing all 4 VL AHU both board operators aware.

mode select switches in HIGH to prevent them from cycling around 0.5 PSIG.

BOP (Step 12) Check seal leakoff on all NC pumps - LESS THAN 6 GPM.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 16 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments BOP (Step 13) Check NC pump thermal barriers intact as follows:

• NC pump thermal barrier KC outlet flows and temperatures on OAC KC graphic NORMAL (flow and temperature should be similar for all 4 NC pumps).

• KC surge tank level rates on OAC KC graphic - NORMAL.

• KC Surge Tank level - NORMAL.

• 1EMF-46A (Train A Component Cooling)

- NORMAL.

• 1EMF-46B (Train B Component Cooling)

- NORMAL.

CRS (Step 14) GO TO Step 16.

BOP (Step 16) Check leak - SUSPECTED ON NOTE: The NCS leak is NOT LETDOWN LINE NEAR DEMINERALIZERS. suspected to be on the Letdown Line near the Demineralizers.

CRS (Step 16 RNO) GO TO Step 18.

BOP (Step 18) Check leak - KNOWN TO BE ON NOTE: The NCS leak is NOT NORMAL LETDOWN LINE. known to be on the Normal Letdown Line.

CRS (Step 18 RNO) GO TO Step 20.

BOP (Step 20) Check leak - KNOWN TO BE ON NOTE: The NCS leak is NOT VCT. known to be on the VCT.

CRS (Step 20 RNO) GO TO Step 22.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 17 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments BOP (Step 22) Check leak - KNOWN TO BE ON NOTE: There is no NCS leak.

NORMAL CHARGING LINE DOWNSTREAM OF 1NV-244A (Charging Line Cont Outside Isol).

CRS (Step 22 RNO) GO TO Step 24.

BOP (Step 24) Check the following indications -

NORMAL:

• Pzr safeties:

• PZR RELIEF VALVE TEMP

• PZR RELIEF LINE NO FLOW acoustic indication light.

• Pzr PORVs:

• PZR RELIEF VALVE TEMP.

• PRT conditions:

• Pressure

• Level

• Temperature BOP (Step 25) check all CLA levels - NORMAL.

BOP (Step 26) Check the following NCDT parameters:

• Level - NORMAL

• Temperature - NORMAL

• PUMP FLOW - AT RECIRC FLOW.

BOP (Step 27) Check Containment floor and equipment sumps - NORMAL.

CRS (Step 28) Check leak location - HAS BEEN NOTE: There is no NCS leak.

IDENTIFIED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 18 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments CRS (Step 28 RNO) Perform the following steps as necessary to identify location of leak:

• IF leak is inside containment, THEN evaluate isolating letdown and charging PER Steps 19 and 23 to see if leak exists on these headers.

• Notify WCC SRO to review recent NOTE: CRS may call WCC to changes in plant status: address the suspected leak.

If so, Booth Instructor acknowledge as WCC, and respond as appropriate.

• Any equipment removed from service

• Any equipment returned to service

• Any venting or draining in progress.

BOP

• Notify Radwaste Chemistry to check the NOTE: CRS may call RW to following tanks and sumps for excessive address the suspected leak.

input: If so, Booth Instructor acknowledge as RW, and respond as appropriate.

• ND/NS sump

• RHT

• Waste Drain Tank

• WEFT

• FDT

• Spent Resin Storage Tank.

• IF affected tank or sump readily identified, BOP

• IF affected tank or sump not identified, THEN check all tanks and sumps in next steps.

• Check inputs to desired tanks and sumps NOTE: CRS may ask U2 BOP PER PT/1/A/4150/001D (Identifying NC to perform.

System Leakage). If so, Floor Instructor acknowledge as U2 BOP.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 19 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments BOP

• IF necessary to check inputs to FDT or NOTE: The suspected NCS WEFT, THEN .. leak location is known to be in the Containment.

• IF leakage suspected through 1NV-137A NOTE: The suspected NCS (NC Filters Otlt 3-Way Cntrl) to RHT, leak location is known to be in THEN the Containment.

CRS (Step 29) Ensure RP is notified of location NOTE: CRS may call and size of leak. WCC/RP to address the NCS leak.

If so, Booth Instructor acknowledge as WCC/RP.

BOP (Step 30) Check normal letdown - IN SERVICE.

CRS (Step 31) Contact station management to NOTE: CRS may call WCC to evaluate need to shutdown. contact management.

If so, Booth Instructor acknowledge as WCC.

CRS (Step 32) Check unit shutdown -

REQUIRED.

CRS (Step 32 RNO) GO TO Step 35 NOTE: After the RP has reported that it is suspected that 1EMF-38(L) has failed high, the operator may suspend use of AP-10.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 20 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.4.15, RCS LEAKAGE DETECTION INSTRUMENTATION CRS LCO 3.4.15, The following RCS leakage detection instrumentation shall be OPERABLE:

The containment floor and equipment sump level monitors and the incore instrument sump level alarm; The containment atmosphere particulate radioactivity monitor; and The containment ventilation unit condensate drain tank level monitor.

CRS APPLICABILITY: MODE 1 for all instrumentation.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 2 Page 21 of 74 Event

Description:

1EMF-38 (LO) fails HIGH/VQ valves fail to Auto CLOSE Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION B and B. Containment B.1 Perform SR Once per 24 D must be entered (C is atmosphere 3.4.13.1. hours particulate already entered).

radioactivity monitor OR inoperable.

B.2 Analyze grab Once per 24 samples of hours the containment atmosphere.

D. Containment D.1 Restore 30 Days atmosphere containment particulate atmosphere radioactivity particulate monitor radioactivity inoperable in monitor to MODE 1. OPERABLE status.

AND Containment OR ventilation unit condensate drain tank level D.2 Restore monitor containment 30 Days inoperable in ventilation MODE 1. unit condensate drain tank level monitor to OPERABLE status.

At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 22 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Following this, 1SA48 will fail OPEN causing the TDCA Pump to start. The crew will recognize that reactor power is rising, and that the pump should not be running, and take action to reduce Turbine load and isolate CA flow to the Steam Generators per the Crew Expectation Manual. The operator will be unable to locally isolate steam to the TDCA pump and leave the CA throttle valves closed. The operator will address Technical Specification LCO 3.7.5, Auxiliary Feedwater (AFW) System, which will require a plant shutdown, and SLC 16.9.7, Standby Shutdown System. The operator may use AP/1/A/5500/1, Steam Leak, to diagnose the failure, and if so, use OP/1/A/6250/002, Auxiliary Feedwater System, in an attempt to stop the pump. Ultimately, the crew will enter AP/1/A/5500/4, Rapid Downpower.

Booth Operator Instructions: Contact the Control Room as the VE System Engineer and request that the BOP report which train of VE is currently in service.

When BOP at VE Panel, insert REM-SA0048ABC = 1.0 Indications Available:

• Reactor power starts to rise

• 1SA48ABC Red status light is LIT

• TDCA Pump Turbine Speed rising Time Pos. Expected Actions/Behavior Comments CONTROL ROOM EXPECTATIONS MANUAL RO/ T/G load reduction during normal ops and BOP transients (no procedure guidance and immediate need to reduce load = transient) for over power events.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 23 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments Normal load changes: Auto is preferred NOTE: The RO will reduce Transient load changes: Manual is Turbine load sufficiently to preferred- immediately reduce 20MWe and maintain Rx power < 90%.

then reduce as needed to maintain Rx power less than pre-transient condition. After the initial 20 MWe load reduction, it is preferred that the operators use multiple and diverse indications to determine how much more load should be reduced. TPBE on the OAC updates once per minute. Other indications (PR meters and Delta T meters) will indicate reactor response more quickly and will enable the operators to control the plant even more precisely. (This combines the Operator Fundamentals of Conservatism and Controlling Plant Evolutions Precisely).

RO/ CA Operation above 10% power.

BOP IF CA Auto start at greater than 3% power NOTE: The BOP will throttle and Main Feedwater is providing flow to the CA flow from the TDCA Pump, steam generators, then CA flow should be rendering the CA Pumps throttled/isolated as soon as practical. This inoperable.

will make the affected CA pumps inoperable due to the control valve not being fully open above 10% as required by the CA Surveillance Requirements.

NOTE: The CRS may or may not address AP1.

If so, the crew may ultimately go to OP/1/A/6250/002 and attempt to shutdown the TDCA Pump.

On the other hand, the operator may elect to leave the pump running, close the CA Control Valves, and investigate the failure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 24 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/01, STEAM LEAK CRS (Step 1) Monitor Foldout page. NOTE: Manual Reactor Trip Criteria is NOT expected to be utilized.

RO (Step 2) Reduce turbine load to maintain the NOTE: The RO will need to following: reduce load to limit reactor power.

• Excore NIs - LESS THAN OR EQUAL TO 100%.

• NC Loop D/Ts - LESS THAN 60°F D/T

• T-Avg - AT T-REF.

CRS (Step 3) Check containment entry - IN NOTE: A Containment Entry is PROGRESS. NOT in progress.

CRS (Step 3 RNO) GO TO Step 5.

BOP (Step 5) Check Pzr pressure prior to event -

GREATER THAN P-11 (1955 PSIG).

BOP (Step 6) Check Pzr level - STABLE OR NOTE: Pzr level is expected to GOING UP. be stable, however, it may be lowering. If so, perform Step 6 RNO. Otherwise continue with Step 7.

BOP (Step 6 RNO) Perform the following as required to maintain level:

• Maintain charging flow less than 200 GPM at all times in subsequent steps.

• Ensure 1NV-238 (U1 Charging Hdr Control) OPENING.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 25 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments

• OPEN 1NV-241 (U1 Seal Water Inj Flow Control) while maintaining NC pump seal flow greater than 6 GPM.

• Reduce or isolate letdown.

• Start additional NV pump.

IF Pzr level going down with maximum NOTE: It is expected that the charging flow BOP will be able to control Pzr level.

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN RETURN TO Step 6. both board operators aware.

CRS (Step 8) GO TO Step 12.

CRS (Step 12) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-1 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO/ (Step 13) Identify and isolate leak on Unit 1 BOP as follows:

• (Step 13a) Check SM PORVs -

CLOSED.

• (Step 13.b) Check condenser dump valves - CLOSED.

• (Step 13.b RNO) IF steam dumps NOTE: The Steam Dumps are required to be closed likely to be closed.

• (Step 13.c) Check containment conditions - NORMAL:

• Containment temperature

• Containment pressure

• Containment humidity

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 26 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments

• Containment floor and equipment sump level.

RO / * (Step 13.d) Check TD CA pump - OFF. NOTE: The TDCA Pump is BOP running.

• (Step 13.d RNO) IF operation of TD CA Examiner NOTE: CRS may pump is causing uncontrolled cooldown direct that the TDCA Pump be AND flow from TD CA pump not stopped per the OP.

required, THEN stop TD CA pump PER If so, continue as scripted.

OP/1/A/6250/002 (Auxiliary Feedwater If NOT, continue with the System) Enclosure 4.4 (Manual remaining steps of AP-1 on Operation of #1 TD CA Pump)

Page 28.

NOTE: The CRS may address Tech Specs based on plant response.

OP/1/A/6250/002, AUXILIARY FEEDWATER SYSTEM ENCLOSURE 4.4, MANUAL OPERATION OF #1 TD CA PUMP BOP (Step 3.1) Evaluate all outstanding R&Rs NOTE: The CRS/BOP may that may impact performance of this call WCC/IAE to address the procedure. R&Rs on the TDCA Pump.

If so, Booth Instructor acknowledge as WCC, and report none exist.

BOP (Step 3.2) Ensure that a pre-job briefing has been performed that includes discussion of reactivity management concerns with this procedure.

BOP (Step 3.3) IF #1 TD CA Pump to be operated NOTE: The pump is NOT to locally be operated locally.

BOP (Step 3.4) Perform the following sections, as applicable:

• Section 3.6, Stopping #1 TD CA Pump

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 27 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments BOP (Step 3.6) Stopping #1 TD CA Pump

• IF stopping pump following EP/AP, NOTE: The CRS may decide check "TURB" depressed on the to take this action if the OP following: was entered from AP1.

• CA Modulating Valves Reset Train A

• CA Modulating Valves Reset Train B

• IF operating #1 TD CA Pump locally NOTE: The pump is NOT to be operated locally.

BOP

• Ensure the following closed:

• 1CA-64AB (U1 TD CA Pump Disch to 1A S/G Control)

• 1CA-52AB (U1 TD CA Pump Disch to 1B S/G Control)

• 1CA-48AB (U1 TD CA Pump Disch to 1C S/G Control)

• 1CA-36AB (U1 TD CA Pump Disch to 1D S/G Control)

BOP

• Ensure RESET lit on TD CA Pump Auto Start Reset.

BOP

• Place #1 TD CA Pump in STOP.

• Ensure the following closed:

• 1SA-48ABC (1C S/G SM Supply To NOTE: The CRS may dispatch U1 TD CA Pump Turb Isol) an AO or contact WCCS/IAE to investigate the failure of 1SA-48ABC.

If so, Floor Instructor acknowledge as AO.

Booth Instructor: Wait 2 minutes and indicate that the valve is OPEN, not sure why, and that it will require further investigation.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 28 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments NOTE: The CRS will recognize that 1SA-48ABC has failed OPEN.

Because of this the CRS may dispatch an AO to locally close the upstream isolation valve 1SA-1. The only other choice is to leave the TDCA Pump running.

If so, Floor Instructor acknowledge as AO.

Booth Instructor: Wait 3 minutes and then call as AO and report that 1SA-1 CANNOT be CLOSED.

• 1SA-49AB (1B S/G SM Supply To U1 TD CA Pump Turb Isol)

NOTE: The CRS will likely conduct a Focus Brief.

AP/1/A/5500/01, STEAM LEAK Examiner NOTE: Continue here if the OP is NOT used to stop TDCA Pump.

BOP * (Step 13.e) Check valves on STEAM NOTE: One or more of these LINE DRAIN VALVES board (1MC-9) - valves may be cycling. The CLOSED. RNO will direct closing the valves.

CRS * (Step 13.f) Check opposite Unit (Unit 2) NOTE: CRS may ask U2 RO STEAM HEADER PRESSURE - for AS Header pressure.

GREATER THAN 200 PSIG. If so, Floor Instructor report as U2 RO that U2 Steam Header pressure is 1000 psig.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 29 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments

• (Step 13.g) Dispatch operator to check NOTE: The CRS may dispatch for leaks. an AO to look for leaks.

If so, Floor Instructor:

acknowledge.

Booth Instructor: Report back in 3-5 minutes that there are no leaks.

NOTE: The CRS may NOT dispatch AOs to look for leaks because it is understood that 1SA48 opening was the reason that AP-1 was entered.

BOP (Step 14) Check UST level - STABLE OR GOING UP.

CRS (Step 15) Evaluate unit shutdown as follows:

• Check unit status - IN MODE 1 OR 2.

• Determine if unit shutdown or load reduction is warranted based on the following criteria:

• Size of leak

• Location of leak

• Rate of depletion of secondary inventory

• IF steam is leaking from a secondary NOTE: No Relief Valve is heater relief OR MSR relief valve, leaking.

THEN reducing turbine load.

• IF turbine trip will isolate steam leak NOTE: A Turbine Trip is NOT (such as feedwater heater leak or needed to isolate the steam MSR leak) leak.

• Check unit shutdown or load reduction - NOTE: Shutdown/Load REQUIRED. Reduction will NOT be required to mitigate the Steam leak.

CRS (Step 15.c RNO) Perform the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 30 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments

• Maintain present plant conditions until leak can be isolated or repaired.

• Exit this procedure.

NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may address Tech Specs based on plant response.

TECHNICAL SPECIFICATION 3.7.5, AUXILIARY FEEDWATER (AFW) SYSTEM CRS LCO 3.7.5 Three AFW trains shall be OPERABLE.

CRS APPLICABILITY: MODE 1, 2, And 3, MODE 4 when steam generator is relied upon for heat removal.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 31 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED COMPLETION ACTION TIME A. One steam A.1 Restore 7 days NOTE: The CRS will supply to steam supply turbine driven to AND determine that ACTION A.1 AFW pump OPERABLE 10 days form must be entered.

inoperable status. discovery of failure to meet the LCO B. One AFW B.1 Restore AFW 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> NOTE: The CRS will train train to inoperable in OPERABLE AND recognize that ACTION B.1 MODE 1, 2, status. 10 days from was entered upon shift or 3 for discovery of turnover.

reasons failure to meet other than the LCO Condition A.

C. Required C.1 Be in Action and MODE 3.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> NOTE: Because the CA associated Valves must remain closed the Completion AND CRS will determine that Time for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> ACTION C.1 and C.2 must be Condition A C.2 Be in or B not entered.

MODE 4.

met. The CRS will note that this condition requires a plant OR shutdown.

Two AFW trains inoperable in MODE 1, 2, or 3.

SELECTED LICENSEE COMMITMENT 16.9.7, STANDBY SHUTDOWN SYSTEM CRS COMMITMENT The Standby Shutdown System (SSS) shall be FUNCTIONAL.

CRS APPLICABILITY: MODES 1, 2, and 3.

CRS REMEDIAL ACTIONS The SRO should ensure that security is notified 10 minutes prior to declaring the SSS inoperable. Immediately upon discovery of the SSS inoperability, Security must be notified to implement compensatory measures within 10 minutes of discovery.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 32 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments CRS CONDITION REQUIRED COMPLETION NOTE: Because the CA ACTION TIME Valves are closed the CRS will A. One or more A.1 Verify the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> determine that SLC 16.9.7 required SSS FUNCTIONA ACTION A.1 and A.2 must be components LITY of fire identified in detection and entered.

Table 16.9.7- suppression 1 non- systems in functional. the associated areas identified in Table16.9.7-1.

AND 7 days A.2 Restore the component to FUNCTIONAL status.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS LCO 3.4.1 RCS DNB parameters for NOTE: If NC System Pressure pressurizer pressure, RCS average drops to < 2216 psig on the temperature, and RCS total flow rate shall be failure, then TS 3.4.1 will be within the limits specified in Table 3.4.1-1. entered and exited during the transient.

CRS APPLICABILITY: MODE 1.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 3 Page 33 of 74 Event

Description:

1SA48 fails OPEN/TDCA Pump starts inadvertently Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTION A.1 A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> must be entered (May be pressure or parameter(s) cleared by the time that the RCS average to within limit.

temperature determination is made).

DNB parameters not within limits.

NOTE: CRS will call WCC/Management to address the CA inoperability.

When this occurs, Booth Instructor acknowledge as WCC, and as Station Management direct the crew to be in Mode 3 within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> due to plant conditions.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 34 of 74 Event

Description:

Rapid Downpower Ultimately, the crew will enter AP/1/A/5500/4, Rapid Downpower.

Booth Operator Instructions: NA Indications Available: NA Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/04, RAPID DOWNPOWER RO/ (Step 1) Monitor Foldout page.

BOP Uncontrolled Cooldown (If Tavg < 551F and lowering..Not Expected)

Power Factor (Adjust power factor during NOTE: The RO will adjust load reduction to maintain power factor MVARS as needed.

between 0.9 to 1.0 lagging, using "VOLTAGE ADJUST" pushbutton)

Manual Rod Control Criteria ( < C-5, Not Expected)

Turbine Shutdown (Turbine Load < 15 MWe Not Expected)

CRS (Step 2) Announce occurrence on page. NOTE: The CRS may ask U2 RO to make Plant Announcement that AP-4 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 3) Check turbine control - IN AUTO.

RO (Step 4) Check MW LOOP - IN SERVICE. NOTE: IF MW LOOP is in service, proceed to Step 5.

RO (Step 4 RNO) Depress MW IN/MW OUT pushbutton.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 35 of 74 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments CRS (Step 5) Check shutdown to Mode 3 -

DESIRED.

CRS (Step 6) Check if "Shutdown Via Reactor Trip from 15% Power" appropriate:

• Shutdown Via Reactor Trip from NOTE: It is normal practice to 15% Power - DESIRED shut down the reactor by driving rods, rather than tripping from 15%.

If the crew elects to trip the reactor from 15% power, the CRS will perform Step 7, rather than the Step 6 RNO.

• At least two CA pumps -

FUNCTIONAL.

CRS (Step 6 RNO) Perform the following:

• IF Mode 3 is timed critical AND the reactor will be shutdown by manually inserting control rods, THEN allow an additional 45 minutes to reach Mode 3 once turbine load reduction is complete.

• IF turbine will be shutdown during downpower, THEN enter target load of 15 MWE in turbine control panel.

• Observe Note prior to Step 8 and GO TO Step 8.

RO (Step 7) Enter target load of 180 MWE in NOTE: Only performed if the turbine control panel. CRS elects to trip the reactor from 15% power.

CRS (Step 8) Determine the required power NOTE: The CRS will reduce reduction rate (MW/min). load at 10-15 MWe/minute.

RO (Step 9) Check control rods - IN AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 36 of 74 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Notify SOC of load reduction (red Booth Instructor: as SOC, dispatcher phone). acknowledge.

RO (Step 11) Initiate turbine load reduction to desired load at desired rate.

BOP (Step 12) Borate NC System as follows:

• Energize all backup Pzr heaters.

CRS

• Check unit to be shutdown - VIA NOTE: It is normal practice to REACTOR TRIP FROM 15% POWER. shut down the reactor by driving rods, rather than tripping from 15%.

CRS (Step 12.b RNO) GO TO Step 12.d.

RO (Step 12.c) Calculate total power change NOTE: Only performed if the

(%): CRS elects to trip the reactor from 15% power.

BOP (Step 12.d) Determine boration amount based on the following:

• Power Reduction Rate (MW/min)

• Present NC System Boron Concentration (ppm)

• Total Power change (%). NOTE: The total power change will be determined by the CRS, and will affect the amount of boron inserted by the BOP.

• Record calculated boration amount:

RO

• Check auto or manual rod control -

AVAILABLE.

BOP

• Perform boration in 4 equal additions during load reduction PER Enclosure 2 (Emergency Boration).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 37 of 74 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments NOTE: The CRS may assign the BOP to perform this action.

If so, BOP Examiner follow actions of Enclosure 2.

Other Examiners follow AP-4 Actions, Step 13, on Page 38.

AP/1/A/5500/04, RAPID DOWNPOWER ENCLOSURE 2, EMERGENCY BORATION BOP (Step 1) Check OAC AVAILABLE.

BOP (Step 2) Use OAC point M1P0785 to monitor boric acid gallons added while 1NV265B (U1 NV Pump Boric Acid Sup Isol) is open.

BOP (Step 3) GO TO Step 5.

BOP (Step 5) Check boric acid transfer pump NOTE: If a Boric Acid Transfer RUNNING. Pump is NOT running, the BOP will start one pump using the RNO, and stop it later, after the boration is complete.

BOP (Step 6) OPEN 1NV265B (U1 NV Pump Boric Acid Sup Isol).

BOP (Step 7) Do not continue until desired amount of boric acid has been added.

BOP (Step 8) CLOSE 1NV265B (U1 NV Pump Examiner NOTE: When the Boric Acid Sup Isol). Turbine Shifts to Manual, move to Event #5.

BOP (Step 9) IF boric acid transfer pump was NOTE: If a Boric Acid Transfer started in Step 5 RNO, THEN perform the Pump was started earlier, it following: will be stopped here.

• Stop boric acid transfer pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 38 of 74 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments

• Ensure one boric acid transfer pump is in auto.

BOP (Step 10) Repeat enclosure as required.

AP/1/A/5500/04, RAPID DOWNPOWER Examiner NOTE: Examiners following the CRS/RO continue HERE.

Examiner NOTE: When the Turbine Shifts to Manual, move to Event #5.

BOP (Step 13) Display Rod Insertion Limits on OAC by entering turn on code RIL.

CRS (Step 14) IF AT ANY TIME "CONTROL ROD NOTE: This is a Continuous BANK LO LO LIMIT" alarm (1AD-2, B-9) is Action. The CRS will make lit, THEN perform one of the following to both board operators aware.

comply with Tech Spec 3.1.6 (Control Bank Insertion Limits):

• Ensure alarm clears within one hour as Xenon builds in.

OR

• Initiate boration as necessary within one hour to restore control rods above insertion limits.

CRS (Step 15) IF AT ANY TIME during this procedure C-7A is received, THEN ensure Transient Monitor freeze is triggered.

CRS (Step 16) REFER TO the following: NOTE: The CRS may ask OSM to address.

If so, Floor Instructor acknowledge as OSM.

• RP/0/A/5700/000 (Classification of Emergency)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 4 Page 39 of 74 Event

Description:

Rapid Downpower Time Pos. Expected Actions/Behavior Comments

• RP/0/A/5700/010 (NRC Immediate Notification Requirements).

CRS (Step 17) Notify Reactor Engineer on duty of NOTE: The CRS may call load reduction. WCC/RE.

If so, Booth Instructor acknowledge.

RO (Step 18) Check target load - LESS THAN 1000 MW.

CRS (Step 19) Check Unit 2 available to supply NOTE: The CRS will ask U2 aux steam as follows: RO.

Floor Instructor: As U2 RO report All these conditions are met.

• Unit 2 Reactor power - GREATER THAN 15%

• Unit 2 2AS-12 (U2 SM to AS Hdr Control Inlet Isol) - OPEN

• Unit 2 - AVAILABLE TO SUPPLY AS HEADER.

RO (Step 20) Check SM flow on all S/Gs -

GREATER THAN 25%.

When the Turbine Shifts to Manual, move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 5 Page 40 of 74 Event

Description:

Turbine Control Unit fails to MANUAL During the downpower, a failure will occur in the Turbine Control Unit causing the unit to shift from Operator Auto to Manual control. The operator will address 1AD-1/F-4, TURBINE IN MANUAL, and control the Turbine manually during the downpower in accordance with OP/1/A/6300/001A, Enclosure 4.1, Turbine Generator Load Change.

Booth Operator Instructions: (Turbine Control Fails to MANUAL) Set in initial conditions. Triggered from 1NV-265B open light ON.

Indications Available:

• Turbine MWe indication stabilizes

• MCB Annunciator 1AD-1/F-4, TURBINE IN MANUAL Time Pos. Expected Actions/Behavior Comments Examiner NOTE: The CRS will continue in AP-4 while the ARP/OP are addressed (Page 41).

NOTE: The BOP may stop the boration.

MCB ANNUNCIATOR 1AD-1/F4, TURBINE IN MANUAL RO Immediate Action: Ensure Turbine/Generator NOTE: The Turbine will operation stabilizes in either Load or Speed stabilize in LOAD Mode.

Modes of operation.

CRS (Step 1) Determine cause and effect, then NOTE: The CRS may call notify IAE of any malfunction. WCC/IAE to address the Turbine Control failure.

If so, Booth Instructor acknowledge as WCC.

RO (Step 2) Refer to OP/1/A/6300/001 A NOTE: The RO will continue (Turbine-Generator Load Change) for the load reduction in MANUAL.

manual operation of Turbine Generator.

CRS (Step 3) WHEN available and desired, return DEH to OPER AUTO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 5 Page 41 of 74 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected Actions/Behavior Comments OP/1/A/6300/001 A, TURBINE-GENERATOR LOAD CHANGE ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load RO (Step 3.5.1) IF Turbine in OPERATOR AUTO RO (Step 3.5.3) IF Turbine in MANUAL perform the following:

• Ensure desired change within Calculated Capability Curve.

• If turbine load will increase or decrease more than 10 MWs, notify Dispatcher of expected load change.

• IF raising load,

• IF decreasing load, depress GV LOWER.

AP/1/A/5500/04, RAPID DOWNPOWER RO (Step 13) Display Rod Insertion Limits on OAC by entering turn on code RIL.

CRS (Step 14) IF AT ANY TIME "CONTROL ROD NOTE: This is a Continuous BANK LO LO LIMIT" alarm (1AD-2, B-9) is Action. The CRS will make lit, THEN perform one of the following to both board operators aware.

comply with Tech Spec 3.1.6 (Control Bank Insertion Limits)

• Ensure alarm clears within one hour as Xenon builds in.

OR

• Initiate boration as necessary within one hour to restore control rods above insertion limits.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 5 Page 42 of 74 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected Actions/Behavior Comments CRS (Step 15) IF AT ANY TIME during this NOTE: This is a Continuous procedure C-7A is received, THEN ensure Action. The CRS will make Transient Monitor freeze is triggered. both board operators aware.

CRS (Step 16) REFER TO the following: NOTE: The CRS may ask OSM to address.

If so, Floor Instructor acknowledge as OSM.

• RP/0/A/5700/000 (Classification of Emergency)

• RP/0/A/5700/010 (NRC Immediate Notification Requirements).

CRS (Step 17) Notify Reactor Engineer on duty of NOTE: The CRS may call load reduction. WCC/RE to address the load reduction.

If so, Booth Instructor acknowledge as WCC/RE.

Examiner NOTE: The CRS may proceed past Step 18 of AP4 while waiting for the BOP to complete the first boration.

If so, wait until the BOP is complete with the first boration and then proceed to the next event.

(Step 18) Check target load - LESS THAN 1000 MW.

(Step 19) Check Unit 2 available to supply aux steam as follows:

• Unit 2 Reactor power - GREATER THAN NOTE: CRS will ask U2 RO 15% for status.

Floor Instructor: Report as U2 RO that Unit 2 is at 100%

power.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 5 Page 43 of 74 Event

Description:

Turbine Control Unit fails to MANUAL Time Pos. Expected Actions/Behavior Comments

• Unit 2 AS-12 (U2 SM to AS Hdr Control NOTE: CRS will ask U2 RO Inlet Isol) - OPEN for valve position.

Floor Instructor: Report as U2 RO that Unit 2 AS-12 is OPEN.

• Unit 2 - AVAILABLE TO SUPPLY AS NOTE: CRS will ask U2 RO HEADER. for AS availability.

Floor Instructor: Report as U2 RO that Unit 2 is available to supply AS Header.

(Step 20) Check SM flow on all S/Gs -

GREATER THAN 25%.

(Step 21) WHEN all SM flows are less than 75%, THEN ensure the following valves ramp CLOSED:

• 1CF-104AB (1A S/G CF Control Bypass)

• 1CF-105AB (1B S/G CF Control Bypass)

• 1CF-106AB (1C S/G CF Control Bypass)

• 1CF-107AB (1D S/G CF Control Bypass)

EXAMINER NOTE: The crew will continue in AP4 as Event 6 is ramping in.

At the discretion of the Lead Examiner, move to Event #6.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 6 Page 44 of 74 Event

Description:

High Vibration on 1B NCP After this, a high vibration condition will develop on the 1B NCP. The operator will respond in accordance with OAC Alarm M1D3041, 1B NC PUMP VIBRATION (HALM), and enter AP/1/A/5500/08, Malfunction of NC Pump. Ultimately, the vibration condition will rise above the Hi-Hi threshold requiring tripping of the reactor and stopping the NCP. The operator will manually trip the reactor and enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection.

Booth Operator Instructions: insertMAL-NCP003B=4.6 (HI Vibration Alarm) insertMAL-NCP003B=5.1 cd =

X05_001E11_1 = 1 (Hi Vibration Alarm Ramp = 300 seconds) (HI-HI Vibration Alarm)

Indications Available:

• OAC Alarm: 1B NC Pump Vibration

• MCB Annunciator 1AD-6/E-11 NC Pump Hi Vibration

• 1B NC Pump hi vibration on NC Pump Vibration Monitor Time Pos. Expected Actions/Behavior Comments NOTE: The performance of Step 5 of AP8 will be dependent upon the timing of addressing the procedure (i.e. Step 5 may be performed when Hi-Hi Vibration exceeds setpoint).

AP/1/A/5500/08, MALFUNCTION OF NC PUMP CASE III, EXCESSIVE VIBRATION BOP (Step 1) Check NC Pump vibration problem -

KNOWN TO BE VALID.

BOP (Step 2) Check affected NC pump vibration indication within operating limits:

• Motor frame vibration - LESS THAN 5 NOTE: The Motor Frame MILS Vibration will be rising.

• All of the following - LESS THAN 20 MILS

• Motor shaft vibration

• Pump shaft vibration

• Motor axial vibration

• Motor flywheel vibration

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 6 Page 45 of 74 Event

Description:

High Vibration on 1B NCP Time Pos. Expected Actions/Behavior Comments CRS (Step 3) IF AT ANY TIME vibration exceeds NOTE: This is a Continuous operating limits, THEN GO TO Step 5 Action. The CRS will make both board operators aware.

CRS (Step 4) GO TO Step 6 CRS (Step 6) Announce occurrence on the NOTE: The CRS may ask paging system. U2 RO to make Plant Announcement that AP-8 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 7) Check NC pumps - ANY RUNNING NOTE: All 4 NCPs are currently running. The CRS will direct the crew to continue monitoring NCP vibrations until the Hi-Hi Vibration alarm actuates.

When alarm occurs, the crew will go to Step 5.

BOP (Step 5) Stop affected NC pump as follows:

• IF A or B NC pump is the affected pump, Then CLOSE associated spray valve:

BOP

• 1NC-27C (1A NC Loop PZR Spray Control).

• 1NC-29C (1B NC Loop PZR Spray NOTE: The 1B RCP is Control). affected.

• Check unit status - IN MODE 1 OR 2.

RO

• Trip reactor BOP

• WHEN reactor power less than 5%,

THEN stop affected NC pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 6 Page 46 of 74 Event

Description:

High Vibration on 1B NCP Time Pos. Expected Actions/Behavior Comments Critical Task:

Trip the Reactor prior to stopping the NCP during a high vibration condition, and trip the NCP only after Reactor power level has dropped to less than 5%.

Safety Significance: The P-8 interlock allows one NCP to be stopped less than 48%

power. If a NCP is stopped in Mode 1 or 2, Tech Spec 3.4.4 requires the unit to be in Mode 3 within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. In addition, T-ave for the idle loop may violate Tech Spec 3.4.2, minimum temperature for criticality. In this case, the unit must be sub-critical within 30 minutes. The transient placed on the unit when a NCP is secured at power can challenge both reactor protection and control systems. Furthermore, an added burden is placed on the operator to stabilize the unit and shut down within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (possibly 30 minutes) to comply with Tech Specs. Even though the plant is designed and analyzed to operate in this configuration for a short time, station management has decided that the conservative approach to dealing with this transient is to trip the reactor anytime a NCP malfunction warrants stopping a pump in Mode 1 or 2.

Guidance is given to wait until reactor power is less than 5% before stopping the NC pump. This will ensure the NC pump will provide adequate flow/core cooling until reactor power is sufficiently low enough to preclude a challenge to fuel integrity. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

CRS

• GO TO EP/1/A/5000/E-0 (Reactor Trip or Safety Injection).

When the crew trips the reactor move to Events #7-9.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 47 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Following the plant trip, a Feedwater Isolation Signal (FWIS) will occur prematurely, the Main Turbine will fail to trip automatically or manually, and the Main Steam Line Isolation signal will fail to automatically actuate. The operator will be required to either manually close the Turbine Governor Valves or the MSIVs. It is likely that SI will actuate due to the delayed Turbine isolation. At the same time, the TDCA Pump, if not already running, will start on low Steam Generator levels. If the TDCA Pump was not running at the start of the event, it will trip on overspeed upon startup. If the TDCA Pump was running at the start of the event, it will trip when the operator initiates flow to the Steam Generators. Furthermore, the 1A MDCA Pump will trip on overcurrent during pump startup, and any attempts to restart the pump will be unsuccessful.

Consequently, a Red Path on Heat Sink will occur shortly after SI actuation, or upon the transition to EP/1/A/5000/ES-0.1, Reactor Trip Response. The operator will transition from EP/1/A/5000/E-0 to EP/1/A/5000/FR-H.1, Response to Loss of Secondary Heat Sink. The operator will eventually restore feed flow using a CF Pump in accordance with Enclosure 8 (Re-establishing CF Flow) of FR-H.1. Upon restoration of feed flow to the Steam Generators, the crew will transition back to E-0.

The scenario will terminate upon the operator returning to E-0, or ES-0.1, after the secondary heat sink has been restored.

Booth Operator Instructions: The following will occur on the Rx trip:

• insert MAL-ISE007A ACT_AUTO cd='H_X01_094_2 EQ 1' (FWIS Train A)

• insert MAL-ISE007B ACT_AUTO cd='H_X01_094_2 EQ 1' (FWIS Train B)

• insertMAL-DEH003A = TRUE (Main Turbine fails to Auto Trip)

• insertMAL-DEH003B = TRUE (Main Turbine fails to Manually Trip)

• insert MAL-CA009A TRUE cd='H_X10_102_4 EQ 1' (MD CA Pump 1A trips on startup)

• insert MAL-CA005 TRIP cd='H_X01_094_2 EQ 1' delay=0, insert MAL-SM029 = 0, cd=H_X01_094_2 EQ1 (TDCA Overspeed Trip occurs and Breaker Open Indicating Light, 1SA-3 fails CLOSED on Reactor Trip)

NOTE: When an AO is dispatched to check the 1A MDCA Pump Breaker.

Acknowledge as AO. Wait five minutes and report back that the breaker has an overcurrent lockout relay showing, and the motor smells of burnt insulation.

NOTE: When an AO is dispatched to check the 1TDCA Pump. Wait five minutes and report back that the TDCA Turbine has tripped on overspeed and will NOT reset.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 48 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Indications Available:

• MCB Annunciator 1AD-4/B-1 through 4, S/G A-D LEVEL DEVIATION

• MCB Annunciator 1AD-4/C-1 through 4, S/G A-D FLOW MISMATCH LO CF FLOW

• MCB Annunciator 1AD-4/E-1 through 4, S/G A-D LO LEVEL ALERT

• RED Path on Heat Sink.

Time Pos. Expected Actions/Behavior Comments NOTE: If the TDCA Pumps is still running from a previous malfunction, the BOP may attempt to open the CA Control Valves to prevent the Red Path on Heat Sink.

However, the TDCA will overspeed shortly after event initiation.

EP/1/A/5000/E-0, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria (Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1.5 ft - Not expected)

Position Criteria for 1NV-150B and 1NV- NOTE: The BOP will 151A (U1 NV Pump Recird Isol) monitor these conditions.

• IF NV S/I flowpath aligned AND NC pressure is less than 1500 PSIG, THEN CLOSE 1NV-150B and 1NV-151A.

• IF NC pressure is greater than 2000 PSIG, THEN OPEN 1NV-150B and 1NV-151A.

Ruptured S/G Aux Feedwater Isolation Criteria (Not expected)

Faulted S/G Aux Feedwater Isolation Criteria (Not expected)

RO (Step 2) Check Reactor trip: Immediate Action

• All rod bottom lights - LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 49 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• Reactor trip and bypass breakers -

OPEN

• I/R amps - GOING DOWN.

RO (Step 3) Check Turbine Trip: Immediate Action

• All throttle valves - CLOSED.

RO (Step 3 RNO) Perform the following: Immediate Action

• Trip turbine.

• IF turbine will not trip, THEN perform the NOTE: Turbine will NOT trip following: manually.

• Place turbine in manual.

• CLOSE governor valves in fast action.

• IF governor valves will not close Critical Tasks:

Manually close the Main Turbine Governor Valves or establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24% (36%).

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, or failure to establish feedwater flow into at least one Steam Generator results in the crew having to rely upon the lower-priority action of having to initiate RCS Bleed and Feed to minimize the possibility of core uncovery. Failure to perform this task, when able to do so, constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers.

BOP (Step 4) Check 1ETA and 1ETB - Immediate Action ENERGIZED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 50 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments Examiner NOTE:

Depending on the timing of diagnosis of the failure of the Main Turbine to trip, the crew may or may not actuate SI.

The script assumes that SI has occurred, and that FR-H.1 will be entered later.

If SI is NOT actuated the crew will transition to EP/1/A/5000/ES-0.1, and with the RED Path on Heat Sink active, transition to FR-H.1 instead. If so, Examiners move forward to Page 53.

RO/ (Step 5) Check if S/I is actuated: Immediate Action BOP

• A SAFETY INJECTION ACTUATED status light (1SI-18) - LIT.

• Both LOCA Sequencer Actuated status lights (1SI-14) - LIT.

CRS (Step 6) Announce Unit 1 Safety Injection. NOTE: CRS may ask U2 RO to make Plant Announcement that Unit 1 Safety Injection has actuated.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 7) Check all Feedwater Isolation status lights (1SI-4) - LIT.

BOP (Step 8) Check Phase A RESET lights -

DARK.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 51 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments BOP (Step 9) Check ESF Monitor Light Panel on energized train(s):

• Groups 1, 2, 5 - DARK.

• Group 3 - LIT.

• Group 4 - LIT AS REQUIRED.

• Group 6 - LIT.

CRS

• GO TO Step 10.

RO/ (Step 10) Check proper CA pump status: NOTE: Both MDCA Pumps BOP are OFF.

• MD CA pumps - ON (Step 10a RNO) Start pumps

• N/R level in at least 3 S/Gs - GREATER THAN 17%.

(Step 10b RNO) Ensure TD CA pump on.

BOP (Step 11) Check all KC pumps - ON BOP (Step 12) Check both RN pumps - ON.

CRS (Step 13) Notify Unit 2 to perform the Floor Instructor: As U2 following: RO report 2A RN Pump is running.

• Start 2A RN pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 52 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• THROTTTLE Unit 2 RN flow to minimum Booth Instructor:

for existing plant conditions. insert LOA-RN087 (Start 2A RN Pump) insert LOA-RN083 8050.000000 delay=0 ramp=10 (Unit 2 Train A Demand Flow)

RO (Step 14) Check all S/G pressures -

GREATER THAN 775 PSIG.

BOP (Step 15) Check Containment Pressure - NOTE: Containment HAS REMAINED LESS THAN 3 PSIG. pressure is normal.

BOP (Step 16) Check S/I flow:

BOP

• Check NV PMPS TO COLD LEG FLOW gauge - INDICATING FLOW.

• Check NC pressure - LESS THAN 1600 PSIG.

BOP (Step 16.b RNO) Perform the following:

BOP

• Ensure ND pump miniflow valve on running pump(s) OPEN:

• 1ND-68A (1A ND Pump & Hx Mini Flow Isol)

• 1ND-67B (1B ND Pump & Hx Mini Flow Isol).

CRS

• IF valve(s) open on all running ND pumps, THEN GO TO Step 17.

CRS (Step 17) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/A/5000/G-1 (Generic OSM to address.

Enclosures), Enclosure 22 (OSM Actions If so, Floor Instructor Following an S/I) within 10 minutes. acknowledge as OSM.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 53 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments (Step 18) Check CA flow:

• Total CA flow - GREATER THAN 450 GPM.

(Step 18 RNO) Perform the following:

• IF N/R level in all S/Gs is less than 11%

(32% ACC), THEN perform the following:

• Ensure correct valve alignment.

• Start CA pumps.

• IF N/R level in all S/Gs is less than 11%

(32% ACC) AND feed flow greater than 450 GPM cannot be established, THEN perform the following:

• Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

• GO TO EP/1/A/5000/FR-H.1 (Response To Loss of Secondary Heat Sink).

NOTE: It is expected that the Red Path on Heat Sink will exist by this time. The CRS will transition to FR-H.1.

EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK CRS (Step 1) IF total feed flow is less than 450 NOTE: This condition is GPM due to operator action NOT met, and the crew will remain in FR-H.1.

RO/ (Step 2) Check if secondary heat sink is BOP required:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 54 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• NC pressure - GREATER THAN ANY NON-FAULTED S/G PRESSURE.

• Any NC T-Hot - GREATER THAN 350°F NOTE: A Secondary Heat (347°F ACC). Sink is required.

RO/ (Step 3) Monitor Foldout Page.

BOP NC System Feed and Bleed Criteria (Applies after Step 2 in the body of the procedure) (3 S/Gs goes below 24% (36% ACC) - Not expected)

Cold Leg Recirc Switchover Criteria (FWST level reaches 95 inches - Not expected)

CA Suction Sources (CA storage tank (water tower) goes below 1.5 ft - Not expected)

BOP (Step 4) Check at least one of the following NV pumps - AVAILABLE:

• 1A NV pump OR

• 1B NV pump.

RO (Step 5) Check if NC System feed and bleed should be initiated:

• Check W/R level in at least 3 S/Gs -

LESS THAN 24% (36% ACC).

RO/ (Step 5.a RNO) Perform the following:

BOP

• Monitor feed and bleed initiation criteria.

• WHEN criteria satisfied, THEN GO TO NOTE: This is a Continuous Step 22. Action. The CRS will make both board operators aware.

CRS

• GO TO Step 6.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 55 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments BOP (Step 6) Ensure S/G BB and NM valves NOTE: The CRS may CLOSED PER Enclosure 3 (S/G BB and assign the BOP (RO) to Sampling Valve Checklist). perform this action.

If so, BOP (RO) Examiner follow actions of Enclosure 3.

Others should move ahead to Step 7 on Page 56 to continue in FR-H.1.

EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 3, S/G BB AND SAMPLING VALVE CHECKLIST BOP (Step 1) Check the following valves - Examiner NOTE: Follow the (RO) CLOSED. actions associated with Enclosure 3 if BOP is assigned by CRS to perform.

• 1BB-1B (1A S/G Blowdown Cont Outside Isol Control) - CLOSED

• 1BB-2B (1B S/G Blowdown Cont Outside Isol Control) - CLOSED

• 1BB-3B (1C S/G Blowdown Cont Outside Isol Control) - CLOSED

• 1BB-4B (1D S/G Blowdown Cont Outside Isol Control) - CLOSED

• 1BB-5A (A S/G BB Cont Inside Isol) -

CLOSED

• 1BB-6A (B S/G BB Cont Inside Isol) -

CLOSED

• 1BB-7A (C S/G BB Cont Inside Isol) -

CLOSED

• 1BB-8A (D S/G BB Cont Inside Isol) -

CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 56 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• 1NM-187A (1A S/G Upper Shell Sample Cont Inside Isol) - CLOSED BOP

• 1NM-190A (1A S/G Blowdown Sample (RO) Cont Inside Isol) - CLOSED

• 1NM-201A (1B S/G Blowdown Sample Hdr Cont Outside Isol) - CLOSED

• 1NM-207A (1C S/G Upper Shell Sample Cont Inside Isol) - CLOSED

• 1NM-210A (1C S/G Blowdown Sample Cont Inside Isol) - CLOSED

• 1NM-221A (1D S/G Blowdown Sample Hdr Cont Outside Isol) - CLOSED

• 1NM-191B (1A S/G Blowdown Sample Hdr Cont Outside Isol) - CLOSED

• 1NM-197B (1B S/G Upper Shell Sample Cont Inside Isol) - CLOSED BOP

• 1NM-200B (1B S/G Blowdown Sample (RO) Cont Inside Isol) - CLOSED

• 1NM-211B (1C S/G Blowdown Sample Hdr Cont Outside Isol) - CLOSED

• 1NM-217B (1D S/G Upper Shell Sample Cont Inside Isol) - CLOSED

• 1NM-220B (1D S/G Blowdown Sample Cont Inside Isol) - CLOSED EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK RO (Step 7) Attempt to establish CA flow to at Examiner NOTE:

(BOP) least one S/G as follows: Examiners NOT following BOP (RO) actions in Enclosure 3, continue HERE.

• Check power to both MD CA pumps - NOTE: The 1A MDCA Pump AVAILABLE. is OOS, and the 1B MDCA Pump has failed upon Auto Start.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 57 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments CRS (Step 7.a RNO) Perform the following:

• IF 1ETA OR 1ETB deenergized, NOTE: 1ETA and 1ETB are THEN.. both energized.

• IF the essential bus is energized, NOTE: The CRS will THEN dispatch operator to determine dispatch an AO.

cause of breaker failure. Booth Instructor:

Acknowledge as AO. Wait five minutes and report back that the breaker has an overcurrent lockout relay showing, and the motor smells of burnt insulation.

RO (Step 7.b) Ensure control room CA valves NOTE: The CRS may (BOP) aligned PER Enclosure 4 (CA Valve assign the RO (BOP) to Alignment). perform this action.

If so, RO (BOP) Examiner follow actions of Enclosure 4.

Others should move ahead to Step 7.c on Page 60 to continue in FR-H.1.

EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 4, CA VALVE ALIGNMENT Examiner NOTE: Follow the actions associated with Enclosure 4 if RO (BOP) is assigned by CRS to perform.

RO (Step 1) Check the following valves - OPEN (BOP)

• 1CA-66AC (U1 TD CA Pump Disch To 1A S/G Isol) - OPEN

• 1CA-62A (1A CA Pump Disch To 1A S/G Isol) - OPEN

• 1CA-54AC (U1 TD CA Pump Disch To 1B S/G Isol) - OPEN

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 58 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• 1CA-58A (1A CA Pump Disch To 1B S/G Isol) - OPEN

• 1CA-50B (U1 TD CA Pump Disch To 1C S/G Isol) - OPEN

• 1CA-46B (1B CA Pump Disch To 1C S/G Isol) - OPEN

• 1CA-38B (U1 TD CA Pump Disch To 1D S/G Isol) - OPEN

• 1CA-42B (1B CA Pump Disch To 1D S/G Isol) - OPEN RO (Step 2) Check the following valves - OPEN (BOP)

• 1CA-64B (U1 TD CA Pump Disch To 1A S/G Control) - OPEN

• 1CA-60A (1A CA Pump Disch To 1A S/G Control) - OPEN

• 1CA-52AB (U1 TD CA Pump Disch To 1B S/G Control) - OPEN

• 1CA-56A (1A CA Pump Disch To 1B S/G Control) - OPEN

• 1CA-48AB (U1 TD CA Pump Disch To 1C S/G Control) - OPEN

• 1CA-44B (1B CA Pump Disch To 1C S/G Control) - OPEN

• 1CA-36AB (U1 TD CA Pump Disch To 1D S/G Control) - OPEN

• 1CA-40B (1B CA Pump Disch To 1D S/G Control) - OPEN RO (Step 3) Check CA Storage Tank (water (BOP) tower) level - GREATER THAN 1.5 FT.

RO (Step 4) Check the following valves -

(BOP) CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 59 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• 1RN-69A (1A RN Assured Supply TO U1 CA Isol) - CLOSED

• 1CA-86A (U1 TD CA Pump Suction From 1A RN Isol) - CLOSED

• 1CA-15A (1A CA Pump Suction From 1A RN Isol) - CLOSED

• 1RN-162B (1B RN Assured Supply To U1 CA Isol) - CLOSED

• 1CA-116B (U1 TD CA Pump Suction From 1B RN Isol) - CLOSED

• 1CA-18B (1B CA Pump Suction From 1B RN Isol) - CLOSED RO (Step 5) Check the following valves - OPEN:

(BOP)

• 1CA-11A (1A CA Pump Suction Isol) -

OPEN

• 1CA-7AC (U1 TD CA Pump Suction Isol)

- OPEN

• 1CA-9B (1B CA Pump Suction Isol) -

OPEN RO (Step 6) GO TO Step 8.

(BOP)

RO (Step 8) Check 1CA-2 (U1 CA Pump Suct (BOP) From CA Storage Tank Isol) - OPEN.

RO (Step 9) Check CA pump suction from UST (BOP) and CA Condensate Storage Tank (service bldg roof tank) valves - CLOSED:

• 1CS-18 (U1 UST To CA Pump Suct Hdr Isol) - CLOSED

• 1CA-4 (U1 CA Pumps Suct From SUT Isol) - CLOSED

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 60 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• 1CA-6 (U1 CA Pumps Suct From CA CST Isol) - CLOSED.

EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK Examiner NOTE:

Examiners NOT following RO (BOP) actions in Enclosure 4, continue HERE.

BOP (Step 7.c) Start all available CA pumps.

(RO)

BOP (Step 7.d) Check TD CA pump - RUNNING. NOTE: The TDCA Pump is (RO) NOT running.

BOP (Step 7.d RNO) Perform the following as (RO) necessary:

• IF 1SA-48BC (SM From S/G C To TD CA NOTE: 1SA-48BC indicates Pump Isol) is closed, THEN OPEN.

• IF 1SA-49AB (SM From S/G B to TD CA NOTE: 1SA-49AB indicates Pump Isol) is closed, THEN OPEN.

CRS

• IF TD CA PUMP STOP VLV NOT NOTE: The CRS will OPEN alarm (1AD-5, F-3) is lit, THEN dispatch an AO.

dispatch operator to reset 1SA-3 (Unit 1 Booth Instructor:

TD CA Pump Turb Stop Valve) PER Acknowledge as AO. Wait EP/1/A/5000/G-1 (Generic Enclosures), five minutes and report Enclosure 24 (Resetting TD CA Stop back that the TDCA Valve). Turbine has tripped on overspeed and will NOT reset.

CRS

• IF reason for loss of steam supply to TD NOTE: The CRS will CA pump not determined, determine from the AO report that the TDCA Pump is unavailable.

RO/ (Step 7.e) Check total flow to S/G(s) - NOTE: There is no BOP GREATER THAN 450 GPM. feedwater flow.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 61 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments RO/ (Step 7.e RNO) Perform the following:

BOP

• IF only one MD CA pump is on, NOTE: There are no MDCA Pumps running.

• IF any CA pump is running, NOTE: There are no CA Pumps running.

• IF any feed flow to at least one S/G is NOTE: There is no indicated, feedwater flow.

CRS

• IF no feed flow indicated, THEN perform the following:

• IF no CA pump can be started, NOTE: The CRS may call THEN dispatch operator and WCC/IAE to address the CA maintenance to CA pumps to try to Pump situation.

restore one CA pump to service. If so, Booth Instructor acknowledge as WCC.

• Dispatch operator to ensure CA NOTE: The CRS will valves aligned PER Enclosure 6 dispatch an AO.

(Local CA Valve Alignment). Floor Instructor/Booth Instructor: Acknowledge as AO.

Booth Instructor: After 5 minutes report completion.

CRS

• GO TO Step 8.

RO (Step 8) Check steam dumps as follows:

• Check condenser available as follows:

• C-9 COND AVAILABLE FOR STEAM DUMP status light (1SI-18) -

LIT

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 62 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• Any MSIV - OPEN. NOTE: The MSIVs may be OPEN or CLOSED. If the MSIVs are CLOSED, proceed to Step 9.

• STEAM DUMP SELECT - IN T-AVG MODE.

• Perform the following to place steam dumps in steam pressure mode:

• Ensure STM PRESS CONTROLLER setpoint at 1090-1095 PSIG.

• Place STM PRESS CONTROLLER in manual.

• Adjust STM PRESS CONTROLLER output to equal STEAM DUMP DEMAND signal.

• Place STEAM DUMP SELECT in steam pressure mode.

• Place STM PRESS CONTROLLER in auto.

BOP (Step 9) Stop all NC pumps.

BOP (Step 10) Reset Feedwater Isolation as follows:

• Check any Condensate Booster pump -

ON.

• Check the following alarms - DARK.

• 1AD-5, G-6 (Inner Doghouse Level Hi)

• 1AD-5, H-6 (Outer Doghouse Level Hi).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 63 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments CRS

• Dispatch operator to block Feedwater NOTE: The CRS will Isolation signal PER Enclosure 7 dispatch an AO.

(Feedwater Isolation Override). Floor Instructor/Booth Instructor: Acknowledge as AO.

Booth Instructor: delIA MAL-ISE007A = 2 (Upon Demand to Reset FWIS) delIA MAL-ISE007B = 2 (Upon Demand to Reset FWIS) insert MAL-ISE007A =

BLK_BOTH (Upon Demand to Reset FWIS) insert MAL-ISE007B =

BLK_BOTH (Upon Demand to Reset FWIS)

As AO, report completion.

Booth instructor: do not delay performance of Enclosure 7 BOP

• Check S/I - HAS BEEN ACTUATED. NOTE: SI may have been actuated.

BOP

• Reset the following:

• S/I

• Sequencers BOP

• IF AT ANY TIME a B/O signal occurs, THEN restart S/I equipment previously on.

BOP

• Do not continue until Enclosure 7 (Feedwater Isolation Override) is completed.

BOP (Step 11) Check CM System in service:

• Hotwell pump(s) - ON

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 64 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• Condensate Booster pump(s) - ON.

RO/ (Step 12) Check CF pumps - AT LEAST NOTE: Both CF Pumps are BOP ONE AVAILABLE TO START. available to start.

CRS (Step 13) Establish CF flow PER Enclosure 8 (Re-establishing CF Flow).

NOTE: The CRS will transition to Enclosure 8.

EP/1/A/5000/FR-H.1, RESPONSE TO LOSS OF SECONDARY HEAT SINK ENCLOSURE 8, RE-ESTABLISHING CF FLOW RO/ (Step 1) Place the following valves in manual BOP and CLOSE:

• S/G CF control valves

• S/G CF control bypass valves.

RO/ (Step 2) Lower output to 0% for the following BOP valves:

• All S/G CF control valves

• All S/G CF control bypass valves.

RO/ (Step 3) CLOSE the following CF control BOP isolation valves:

• CLOSE 1CF-31 (1A S/G CF Control Inlet Isol).

• CLOSE 1CF-22 (1B S/G CF Control Inlet Isol).

• CLOSE 1CF-19 (1C S/G CF Control Inlet Isol).

• CLOSE 1CF-18 (1D S/G CF Control Outlet Isol).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 65 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments CRS (Note prior to Step 4) The following step must be completed even if a Feedwater Isolation signal has not occurred.

BOP (Step 4) Depress and release the Feedwater Isolation reset pushbuttons.

RO/ (Step 5) Check any CF pump - RESET. Examiner NOTE:

BOP If a Safety Injection has NOT occurred the CRS will continue with Step 6.

CRS (Step 5 RNO) GO TO Step 14. Examiner NOTE:

If a Safety Injection HAS occurred the CRS will read Step 5 RNO and transition to Step 14 to reset one CF pump. If so, pick up with scripting for Step 14 on page 68.

RO / (Step 6) Check both CF pumps RESET. NOTE: If a Safety Injection BOP has NOT occurred, both CF pumps will likely be reset.

CRS (Note prior to Step 7) Only one CF pump will be placed in service in subsequent steps.

The other CF pump governor valves are closed to reduce loading on the AS Header.

CRS (Step 7) Isolate steam flow to the CF pump not being placed in service as follows:

RO / (Step 7.a) Place low pressure governor BOP control in manual.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 66 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments RO / (Step 7.b) Place high pressure governor BOP control in manual.

RO / (Step 7.c) Lower low pressure governor BOP control output to 0%.

RO / (Step 7.d) Lower high pressure governor BOP control output to 0%.

CRS (Step 8) Align AS header as follows:

RO / (Step 8.a) CLOSE 1AS9 (U1 C Htr Bleed To BOP AS Hdr Isol).

CRS (Step 8.b) Check Unit 2 as follows:

• Unit 2 Reactor power GREATER THAN NOTE: CRS will ask U2 RO 15% to report power level.

If so, Floor Instructor report 100% as U2 RO.

• Unit 2 2AS12 (U2 SM to AS Hdr Control NOTE: CRS will ask U2 RO Inlet Isol) OPEN to report valve position.

If so, Floor Instructor report 2AS-12 is OPEN.

• Unit 2 AVAILABLE TO SUPPLY AS NOTE: CRS will ask U2 RO HEADER. to report U2 AS Availability.

If so, Floor Instructor report U2 AS is available.

CRS (Step 8.c) Isolate Unit 1 SM to AS header as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 67 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments CRS (Step 8.c.1) IF AT ANY TIME AS header NOTE: This is a Continuous pressure cannot be maintained greater than Action. The CRS will make 140 PSIG while performing the following both board operators aware.

step, THEN GO TO Step 8.e.

RO / (Step 8.c.2) Slowly CLOSE 1AS-12 (U1 SM BOP To AS Hdr Control Inlet Isol) while monitoring AS header pressure.

CRS (Step 8.d) GO TO Step 9.

RO / (Step 9) CLOSE the following valves:

BOP

• CLOSE 1CF-35AB (1A S/G CF Cont Outside Isol).

• CLOSE 1CF-30AB (1B S/G CF Cont Outside Isol).

• CLOSE 1CF-28AB (1C S/G CF Cont Outside Isol).

• CLOSE 1CF-26AB (1D S/G CF Cont Outside Isol).

RO / (Step 10) Check 1HM95 (U1 Aux Steam BOP Supply to CF Pumps Turbine Isol)

CLOSED.

RO / (Step 11) Check the following on CF pump to BOP be placed in service:

• CF pump low pressure governor control -

IN AUTO

• CF pump high pressure governor control

- IN AUTO CRS (Step 12) Perform the following on the CR pump to be placed in service:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 68 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments RO / (Step 12.a) Maintain CF pump governors in BOP auto while performing the following steps.

RO / (Step 12.b) Lower setpoint (SP) to 0 RPM BOP using control located on low pressure governor controller.

RO / (Step 12.c) Do not continue until low BOP pressure governor control output is 0%.

RO / (Step 12.d) OPEN 1HM-95 (U1 Aux Steam BOP Supply to CF Pumps Turbine Isol).

RO / (Step 12.e) Raise speed setpoint (SP) using BOP control located on low pressure governor controller to establish "CF HEADER PRESSURE" 50-100 PSIG above S/G pressure.

CRS (Step 13) GO TO Step 22. Examiner NOTE:

Pick up with Step 22 scripting on page 71.

RO/ (Step 14) Depress RESET on 1A OR 1B Examiner NOTE:

BOP CF PUMP RECIRC VALVE CLOSURE If a Safety Injection HAS CIRCUIT and check RESET light lit. occurred the CRS will transition to this step from the Step 5 RNO.

RO/ (Step 15) Reset CF pump turbine that will be BOP placed in service as follows:

• Depress RESET and hold RESET 2-3 seconds after the RST light is lit on pump to be started.

• Check CF pump turbine to be started RESET.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 69 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments RO (Step 16) Align AS header as follows:

• CLOSE 1AS-9 (U1 C Htr Bleed To AS Hdr Isol).

CRS

• Check Unit 2 as follows:

• Unit 2 Reactor power - GREATER NOTE: CRS will ask U2 RO THAN 15% to report power level.

If so, Floor Instructor report 100% as U2 RO.

• Unit 2 2AS-12 (U2 SM to AS Hdr NOTE: CRS will ask U2 RO Control Inlet Isol) - OPEN to report valve position.

If so, Floor Instructor report 2AS-12 is OPEN.

CRS

• Unit 2 - AVAILABLE TO SUPPLY NOTE: CRS will ask U2 RO AS HEADER. to report U2 AS Availability.

If so, Floor Instructor report U2 AS is available.

RO/

• Isolate Unit 1 SM to AS header as BOP follows:

• IF AT ANY TIME AS header NOTE: This is a Continuous pressure cannot be maintained Action. The CRS will make greater than 140 PSIG while both board operators aware.

performing the following step, THEN GO TO Step 16.e.

RO/

• Slowly CLOSE 1AS-12 (U1 SM To BOP AS Hdr Control Inlet Isol) while monitoring AS header pressure.

CRS (Step 16.d) GO TO Step 17.

RO/ (Step 17) Check 1HM-95 (U1 Aux Steam NOTE: 1HM-95 is CLOSED.

BOP Supply to CF Pumps Turbine Isol) - OPEN.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 70 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments RO/ (Step 17 RNO) Open 1HM-95.

BOP RO/ (Step 18) CLOSE the following valves:

BOP

• CLOSE 1CF-35AB (1A S/G CF Cont Outside Isol).

• CLOSE 1CF-30AB (1B S/G CF Cont Outside Isol).

• CLOSE 1CF-28AB (1C S/G CF Cont Outside Isol).

• CLOSE 1CF-26AB (1D S/G CF Cont Outside Isol).

RO/ (Step 19) Check 1A CF pump - TO BE NOTE: The CRS may elect BOP PLACED IN SERVICE. to use the 1B CF Pump, rather than the 1A CF Pump. If so, similar steps are used to those associated with the starting the 1A CF Pump.

RO/ (Step 20) Place 1A CF pump in service as NOTE: The CRS may elect BOP follows: to use the 1B CF Pump.

• Place the following in auto:

• 1A CF pump turbine low pressure governor control.

• 1A CF pump turbine high pressure governor control.

• OPEN stop valves by depressing RAISE on 1A CF PUMP TURBINE HP-LP SV until MAX light is lit on the following:

• 1SP-15 (1A CFPT Turb Hi Press NOTE: If the 1B CF Pump is Step valve) used, 1SP-17

• 1HM-157 (1A CFPT Turb Lo Press NOTE: If the 1B CF Pump is Step valve) used, 1HM-159

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 71 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• Adjust 1A CF pump turbine speed using NOTE: S/G pressures are control located on low pressure governor 1100 psig.

controller to establish CF HEADER PRESSURE 50-100 PSIG above S/G pressure.

CRS (Step 20.d) GO TO Step 22.

RO/ (Step 22) Check feed and bleed - NOTE: Feed and Bleed has BOP ESTABLISHED IN BODY OF THIS NOT been established.

PROCEDURE.

RO/ (Step 22 RNO) Perform the following:

BOP

• WHEN restoring feed flow in next steps, THEN control feed flow as required to raise S/G levels while preventing an uncontrolled NC system cooldown.

CRS

• GO TO Step 25.

RO (Step 26) OPEN the following valve(s) for the S/Gs to be fed:

• 1CF-126B (1A S/G CF To CA Nozzle Isol)

• 1CF-127B (1B S/G CF To CA Nozzle Isol)

• 1CF-128B (1C S/G CF TO CA Nozzle Isol)

• 1CF-129B (1D S/G CF To CA Nozzle Isol).

RO (Step 27) Establish feed flow to desired S/G(s) as follows:

• THROTTLE OPEN S/G CF control bypass valve for S/G(s) to be fed.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 72 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments

• Monitor CF pump discharge pressure NOTE: This is a Continuous and adjust CF pump speed as needed to Action. The CRS will make maintain CF HEADER PRESSURE 50- both board operators aware.

100 PSIG above S/G pressure.

• IF AT ANY TIME S/G CF control bypass NOTE: This is a Continuous valves are throttled closed, THEN ensure Action. The CRS will make pump speed is controlled at same time to both board operators aware.

avoid a CF pump trip on high discharge pressure (1435 PSIG).

CRS (Step 28) Check Step 24 or 25 in this NOTE: Step 24 or 25 have enclosure - IMPLEMENTED. NOT been implemented.

RO (Step 28 RNO) Perform the following:

• WHEN S/G N/R level is greater than 11%

(32% ACC), THEN control CF flow to maintain N/R level between 11% (32%

ACC) and 50%.

Critical Task:

Manually close the Main Turbine Governor Valves or establish feedwater flow into at least one Steam Generator before Wide Range Level in 3 Steam Generators reaches 24% (36%).

Safety Significance: Failure to trip the Main Turbine when conditions exist that allow the operator to do so, or failure to establish feedwater flow into at least one Steam Generator results in the crew having to rely upon the lower-priority action of having to initiate RCS Bleed and Feed to minimize the possibility of core uncovery. Failure to perform this task, when able to do so, constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers.

CRS (Step 28 RNO b) RETURN TO step in effect NOTE: The CRS will in body of this procedure. transition to Step 14 of FR-H.1.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 2 Event # 7, 8 & 9 Page 73 of 74 Event

Description:

Premature FWIS/Failure of Main Turbine to Trip/Failure of Main Steam Line Isolation/Overspeed Trip of TDCA Pump/1A MDCA Pump trips upon Auto Start Time Pos. Expected Actions/Behavior Comments At the discretion of the Lead Examiner terminate the exam.

UNIT 1 STATUS:

Power Level: 90% NCS [B] 960 ppm Pzr [B]: 960 ppm Xe: Per OAC Power History: At this power level for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Core Burnup: 251 EFPDs CONTROLLING PROCEDURE: OP/1/A/6100/003 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME THE SHIFT:

• The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

• A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service:

• The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C.

• The 1B MDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION B.

• MCB Annunciator 1AD-8, A-4, CF PUMP DISCHARGE HI PRESS, has alarmed spuriously several times over the last hour, and has currently failed ON (IAE is investigating).

Crew Directions:

• Maintain Plant conditions.

Work Control SRO/Offsite Communicator Jim Plant SRO Joe (FB)

AO's AVAILABLE Unit 1 Unit 2 Aux Bldg. John Aux Bldg. Chris Turb Bldg. Bob (FB) Turb Bldg. Mike (FB) 5th Rounds. Carol Extra(s) Bill (FB) Ed (FB) Wayne (FB) Tanya Gus (RW)

Appendix D Scenario Outline Form ES-D-1 Final (Rev_031416)

Facility: McGuire Scenario No.: 3 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 75% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The TDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION A. MCB Annunciator 1AD-12, A-4, B RN PMP DISCHARGE LO PRESS, has alarmed spuriously several times over the last hour, and has currently failed OFF (IAE is investigating).

Event Malf. Event Type* Event No. No. Description 1 NA R-RO Power Increase N-BOP N-SRO 2 1 I(TS)-SRO Pzr Level Channel 3 fails LOW 3 2 C-RO Steam Dump Valve fails OPEN C-SRO 4 3 C-RO Zone 1B Lockout causing Runback/Rods fail to move in C-BOP AUTO/Stuck Rod C(TS)-SRO 5 4 C-BOP 1KC-425 fails CLOSED C-SRO 6 5 M-RO Steam Equalization Header Line Rupture M-BOP M-SRO 7 6 NA MSI fails in Auto/Manual/All MSIVs fail OPEN 8 7 C-BOP 1A/1B MD CA Pumps fail to start in AUTO C-SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 Final (Rev_031416)

McGuire 2016 NRC Scenario #3 The plant is at 75% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The TDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION A. MCB Annunciator 1AD-12, A-4, B RN PMP DISCHARGE LO PRESS, has alarmed spuriously several times over the last hour, and has currently failed OFF (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 100% starting with Step 3.37.10 of Enclosure 4.1, Power Increase, of OP/1/A/6100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with .3, Dilute, of OP/1/A/6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A/6300/001 A, Turbine-Generator Load Change.

During the power increase, Pzr Level channel 3 will fail LOW. The DCS will automatically select a non-failed instrument to replace the failed instrument as the controlling channel, and no NCS inventory control upset will result. The operator will address Technical Specification LCO 3.3.1, Reactor Trip System (RTS) Instrumentation.

After this, the Steam Dump Valve SB-27 will slowly fail to FULL OPEN due to a valve positioner failure. The crew will enter AP/1/A/5500/01, Steam Leak, stabilize turbine load, attempt to close, and ultimately isolate the valve.

Next, a Zone 1B Lockout causes PCB 11 and 12 to open, as well as the 1B Main Generator Breaker to open and the turbine to automatically runback to 56%. The operator will implement AP/1/A/5500/03, Load Rejection. During the runback the operator will notice that the rods do not move in auto, and the operator will need to drive rods in manually. When the Control Rods are driven inward, one Control Bank D rod will stick in its original position. After stabilizing the plant, the operator will address AP/1/A/5500/14, Rod Control Malfunction, to address the Stuck Rod.

The operator will address Technical Specification LCO 3.1.4, Rod Group Alignment Limits, and Technical Specification LCO 3.2.4, Quadrant Power Tilt Ratio.

Subsequently, 1KC-425, NC Pumps Ret Hdr Cont Outside Isol), will fail CLOSED. The operator will respond per OP/1/A/6100/010 G, Annunciator Response for 1AD-6, B1, A NC PUMP UPPER MTR BRG LO KC FLO, and manually open the valve. The operator may enter AP/1/A/5500/08, Malfunction of NC Pump.

Following this a steam break will occur on the Main Steam Equalization Header in the Turbine Building. Simultaneously all four MSIVs will fail OPEN resulting in four faulted Steam Generators (Both Auto and Manual actuations of MSI have failed). Additionally, the 1A/1B MD CA Pump will fail to start automatically. The operator will be expected to manually start the 1A and 1B MD CA Pumps.

The crew will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection and transition to EP/1/A/5000/E-2, Faulted Steam Generator Isolation. On the other hand, due to the NCS cooldown, an Orange Path could exist on the NCS Integrity Critical Safety Function. If so, the Appendix D Scenario Outline Form ES-D-1 Final (Rev_031416) crew will transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition.

If the crew made the transition to E-2, the crew will transition to EP/1/A/5000/ECA-2.1 at Step 4 of E-2 when it is determined that all four Steam Generator pressures are lowering. On the other hand, if the crew transitions to FR-P.1, the crew will take the actions required by ECA-2.1, in FR-P.1 (i.e. reduce feed flow to each Steam Generator to 25 gpm each, depressurize NCS and terminate SI).

It is expected that the crew will eventually transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition.

The scenario will terminate at Step 11.c of FR-P.1 after the operator has closed 1NI-9A and 10B.

Critical Tasks:

Establish 450 gpm of CA Flow to the Steam Generators during the performance of E-0 such that transition to EP/1/A/5000/FR-H.1 is not required.

Safety Significance: Failure to establish a Secondary Heat Sink through the initiation of CA flow unnecessarily challenges both the HEAT SINK and the CORE COOLING Critical Safety Functions.

Additionally, the FSAR Safety Analysis results are predicated on the assumption that at least one train of safeguards actuates and delivers a minimum amount of AFW flow to the Steam Generators. Failure to perform this task, when the ability to do so exists, results in a violation of the Facility License Condition and places the plant in an unanalyzed condition.

Control the CA Flowrate to approximately 25 gpm per SG in order to minimize the NC Cooldown rate in ECA-2.1 or FR-P.1.

Safety Significance: Failure to control the CA flow rate to the SGs, when able to do so, leads to an unnecessary and avoidable severe or extreme challenge to the Integrity CSF. Also, failure to perform the Critical Task increases challenges to the Subcriticality Critical Safety Function which otherwise would not occur. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class ILC 16-1 TOPIC: NRC Simulator Exam Scenario N16-1-3

REFERENCES:

1. OP/1/A/6100/010 N, Annunciator Response for Panel 1AD-13 (Rev 78)

2. Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation (Amendment 235/217)

3. Technical Specification LCO 3.7.5, Auxiliary Feedwater (AFW) System (Amendment 221/203)

4. OP/1/A/6100/003, Controlling Procedure for Unit Operation (Rev 197)

5. OP/1/A/6150/009, Boron Concentration Control (Rev 132)

6. OP/1/A/6300/001A, Turbine Generator Load Change (Rev 12)

7. Technical Specification LCO 3.3.1, Reactor Trip System (RTS) Instrumentation (Amendment 184/166)

8. Crew Expectations Manual (Rev 8/8/12)

9. AP/1/A/5500/01, Steam Leak (Rev 18)

10. Technical Specification LCO 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits (Amendment 219/201)

11. AP/1/A/5500/03, Load Rejection (Rev 30)

12. AP/1/A/5500/14, Rod Control Malfunction (Rev 16)

13. Technical Specification LCO 3.1.4, Rod Group Alignment Limits (Amendment 184/166)

14. Technical Specification LCO 3.2.4, Quadrant Power Tilt Ratio (Amendment 184/166)

15. OP/1/A/6100/010 G, Annunciator Response for Panel 1AD-6 (Rev 68)

16. AP/1/A/5500/08, Malfunction of NC Pump (Rev 14)

17. EP/1/A/5000/E-0, Reactor Trip or Safety Injection (Rev 34)

18. EP/1/A/5000/E-2, Faulted Steam Generator Isolation (Rev 10)

19. EP/1/A/5000/ECA-2.1, Uncontrolled Depressurization of All Steam Generators (Rev 20)

20. EP/1/A/5000/F-0, Critical Safety Function Status Trees (Rev 6)

21. EP/1/A/5000/FR-P.1, Response To Imminent Pressurized Thermal Shock Condition (Rev 14)

22. EP/1/A/5000/ES-1.1, Safety Injection Termination (Rev 27)

Validation Time: 100 minutes Author: David Lazarony, Essential Training & Consulting, LLC Facility Review: ________________________

Rev. 031416 Scenario Event Description NRC Scenario 3 Facility: McGuire Scenario No.: 3 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 75% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The TDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION A. MCB Annunciator 1AD-12, A-4, B RN PMP DISCHARGE LO PRESS, has alarmed spuriously several times over the last hour, and has currently failed OFF (IAE is investigating).

Event Malf. Event Type* Event No. No. Description 1 NA R-RO Power Increase N-BOP N-SRO 2 1 I(TS)-SRO Pzr Level Channel 3 fails LOW 3 2 C-RO Steam Dump Valve fails OPEN C-SRO 4 3 C-RO Zone 1B Lockout causing Runback/Rods fail to move in C-BOP AUTO/Stuck Rod C(TS)-SRO 5 4 C-BOP 1KC-425 fails CLOSED C-SRO 6 5 M-RO Steam Equalization Header Line Rupture M-BOP M-SRO 7 6 NA MSI fails in Auto/Manual/All MSIVs fail OPEN 8 7 C-BOP 1A/1B MD CA Pumps fail to start in AUTO C-SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 3 McGuire 2016 NRC Scenario #3 The plant is at 75% power (MOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift. A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The TDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION A. MCB Annunciator 1AD-12, A-4, B RN PMP DISCHARGE LO PRESS, has alarmed spuriously several times over the last hour, and has currently failed OFF (IAE is investigating).

Shortly after taking the watch, the operator will commence a load increase to 100% starting with Step 3.37.10 of Enclosure 4.1, Power Increase, of OP/1/A/6100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with .3, Dilute, of OP/1/A/6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A/6300/001 A, Turbine-Generator Load Change.

During the power increase, Pzr Level channel 3 will fail LOW. The DCS will automatically select a non-failed instrument to replace the failed instrument as the controlling channel, and no NCS inventory control upset will result. The operator will address Technical Specification LCO 3.3.1, Reactor Trip System (RTS) Instrumentation.

After this, the Steam Dump Valve SB-27 will slowly fail to FULL OPEN due to a valve positioner failure. The crew will enter AP/1/A/5500/01, Steam Leak, stabilize turbine load, attempt to close, and ultimately isolate the valve.

Next, a Zone 1B Lockout causes PCB 11 and 12 to open, as well as the 1B Main Generator Breaker to open and the turbine to automatically runback to 56%. The operator will implement AP/1/A/5500/03, Load Rejection. During the runback the operator will notice that the rods do not move in auto, and the operator will need to drive rods in manually. When the Control Rods are driven inward, one Control Bank D rod will stick in its original position. After stabilizing the plant, the operator will address AP/1/A/5500/14, Rod Control Malfunction, to address the Stuck Rod. The operator will address Technical Specification LCO 3.1.4, Rod Group Alignment Limits, and Technical Specification LCO 3.2.4, Quadrant Power Tilt Ratio.

Subsequently, 1KC-425, NC Pumps Ret Hdr Cont Outside Isol), will fail CLOSED. The operator will respond per OP/1/A/6100/010 G, Annunciator Response for 1AD-6, B1, A NC PUMP UPPER MTR BRG LO KC FLO, and manually open the valve. The operator may enter AP/1/A/5500/08, Malfunction of NC Pump.

Following this a steam break will occur on the Main Steam Equalization Header in the Turbine Building. Simultaneously all four MSIVs will fail OPEN resulting in four faulted Steam Generators (Both Auto and Manual actuations of MSI have failed). Additionally, the 1A/1B MD CA Pump will fail to start automatically. The operator will be expected to manually start the 1A and 1B MD CA Pumps.

The crew will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection and transition to EP/1/A/5000/E-2, Faulted Steam Generator Isolation. On the other hand, due to the NCS cooldown, an Orange Path could exist on the NCS Integrity Critical Safety Function. If so, the Scenario Event Description NRC Scenario 3 crew will transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition.

If the crew made the transition to E-2, the crew will transition to EP/1/A/5000/ECA-2.1 at Step 4 of E-2 when it is determined that all four Steam Generator pressures are lowering. On the other hand, if the crew transitions to FR-P.1, the crew will take the actions required by ECA-2.1, in FR-P.1 (i.e. reduce feed flow to each Steam Generator to 25 gpm each, depressurize NCS and terminate SI).

It is expected that the crew will eventually transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition.

The scenario will terminate at Step 11.c of FR-P.1 after the operator has closed 1NI-9A and 10B.

Critical Tasks:

Establish 450 gpm of CA Flow to the Steam Generators during the performance of E-0 such that transition to EP/1/A/5000/FR-H.1 is not required.

Safety Significance: Failure to establish a Secondary Heat Sink through the initiation of CA flow unnecessarily challenges both the HEAT SINK and the CORE COOLING Critical Safety Functions. Additionally, the FSAR Safety Analysis results are predicated on the assumption that at least one train of safeguards actuates and delivers a minimum amount of AFW flow to the Steam Generators. Failure to perform this task, when the ability to do so exists, results in a violation of the Facility License Condition and places the plant in an unanalyzed condition.

Control the CA Flowrate to approximately 25 gpm per SG in order to minimize the NC Cooldown rate in ECA-2.1 or FR-P.1.

Safety Significance: Failure to control the CA flow rate to the SGs, when able to do so, leads to an unnecessary and avoidable severe or extreme challenge to the Integrity CSF. Also, failure to perform the Critical Task increases challenges to the Subcriticality Critical Safety Function which otherwise would not occur. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

Scenario Event Description NRC Scenario 3 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Sim. Setup Rod Step On Reset to Temp IC 237 T = 0 Malfunctions:

Initiate a Containment Release per Enclosure 4.2 of OP/1/A/6450/17.

insert XMT-WL_1WLLT5591 = 100 (1WLL-5591, VUCDT Tank Level is OOS) insert REM-SA0001 = 0 (Steam 1B Supply to TDCA Pump Closed) insert REM-SA0002 = 0 (Steam 1C Supply to TDCA Pump Closed) insert OVR-1AD12_A04 = OFF (MCB Annunciator 1AD12/A4)

Per Lesson Plan 2016 NRC Exam Scenario 3 insert CA004A = AUTO (1A MD CA Pump fails to start in AUTO Only) insert CA004B = AUTO (1B MD CA Pump fails to start in AUTO Only)

DEL IAMAL-010D12 = 2, Cd X01_094_2 = 1 (Delete Stuck Rod on Rx Trip)

RUN Place Tagout/O-Stick on:

TDCA Pump (Tagout)

Reset all SLIMs 1WLL-5591 (O-stick)

MCB Annunciator 1AD-13, C-7 (O-stick)

MCB Annunciator 1AD-12, A-4 (O-stick)

Update Status Board, NOTE: RMWST DO = <1000 ppb.

Setup OAC Freeze.

Update Fresh Tech.

Spec. Log.

Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Fill out the AO's Available section of Shift Turnover Info.

Prior to Crew RUN Briefing Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide Enclosure 4.1 of OP/1/A/6100/003 marked up as follows:

• Step 2.3 initialed.

• Note prior to Step 3.1 checked.

• Step 3.1 Checkbox is checked.

• Step 3.2 initialed.

• Step 3.3 initialed.

• Step 3.3.1 Checkbox is checked.

• Step 3.3.2 Checkbox is checked, Step 3.37.10 is entered.

• Step 3.3.3 Checkbox is checked.

• Step 3.3.4 Initialed.

• Step 3.37.12 is NA.

• Step 3.37.13 is NA.

4. Provide the crew with OP/1/A/6150/009 (Boron Concentration Control) and OP/1/A/6300/1 A (Turbine-Generator Load Change).

5. Direct the crew to Review the Control Boards taking note of present conditions, alarms.

6. Provide the crew with an In-progress copy of Enclosure 4.2 of OP/1/A/6450/17.

T-0 Begin Familiarization Period At direction of Execute Lesson Plan examiner for Simulator Scenario N16-1-3.

At direction of Event 1 Power Increase examiner At direction of Event 2 Pzr Level Channel 3 fails LOW examiner insert XMT-NC_1NCLT5170 = 0 Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION At direction of Event 3 Steam Dump Valve fails OPEN examiner Insert REM-SB0027 = 1, delay = 0, ramp = 120 seconds Cd=X02_183_1 EQ 1 (OFF/RESET Switch to OFF), insert REM-SB0027 = 0 At direction of Event 4 Zone 1B Lockout causing Runback/Rods fail to examiner move in AUTO/Stuck Rod insert MAL-EP003C =

ACTIVE NOTE: insertLOA-IPB003 Override when directed.

insert MAL-IRE009 =

FAIL_OF_AUTO Insert MAL IRE010D12

TRUE At direction of Event 5 1KC-425 fails CLOSED examiner Insert REM-KC0425A

0 delIA REM-KC0425A =

2, cd=X11_135_1=1 At direction of Event 6 Steam Equalization Header Line Rupture examiner insertMAL-SM009 =

16500000 Scenario Event Description NRC Scenario 3 Bench Mark ACTIVITY DESCRIPTION Post-Rx Trip Event 7 MSI fails in Auto/Manual/All MSIVs fail OPEN insertMAL-ISE006A =

BLOCK_BOTH (MSI Note: These Malfunctions are inserted at Fails in Steam Line Break.

AUTO/MANUAL) insertMAL-ISE006B =

BLOCK_BOTH (MSI Fails in AUTO/MANUAL) insertMAL-SM006A =

TRUE 1A MSIV Fails OPEN (Cd =

H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006B =

TRUE 1B MSIV Fails OPEN (Cd =

H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006C =

TRUE 1C MSIV Fails OPEN (Cd =

H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006D =

TRUE 1D MSIV Fails OPEN (Cd =

H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

Post-Rx Trip Event 8 1A/1B MD CA Pumps fail to start in AUTO insert CA004A = AUTO This malfunction will occur on Reactor Trip.

insert CA004B = AUTO Set in initial conditions.

Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 9 of 67 Event

Description:

Power Increase Shortly after taking the watch, the operator will commence a load increase to 100%

starting with Step 3.37.10 of Enclosure 4.1, Power Increase, of OP/1/A/6100/003, Controlling Procedure for Unit Operation. The operator will dilute the NC System Boron concentration in accordance with Enclosure 4.3, Dilute, of OP/1/A/6150/009, Boron Concentration Control, and raise Turbine load in accordance with OP/1/A/6300/001 A, Turbine-Generator Load Change.

Booth Operator Instructions: NA Indications Available: NA Time Pos. Expected Actions/Behavior Comments OP/1/A/6100/003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.37.10) Prior to increasing to greater NOTE: The power increase than 75% RTP, check all governor valves will be at 2-3 MWe/minute.

open.

RO/ (Step 3.37.11) WHEN 77-80% RTP, enable, NOTE: Based on the extent of BOP OTDT DCS alarming as follows: the power increase, this action may or may not be taken.

• On DCS graphics, select MAINTENANCE MENU.

• Select TAVG, DELTA T INPUTS &

ALARM CHECKING graphic.

• Select ON for the following:

• NCAA 5422

• NCAA 5462

• NCAA 5502

• NCAA 5542

• OTDELTAT-FAIL CRS (Step 3.37.12) IF startup from refueling outage..

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 10 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments (Step 3.37.13) IF performing Generator/Automatic Voltage Regulator (AVR) testing at 78% RTP Examiner NOTE: The CRS may elect to initiate the Turbine Load increase (See Page 14), or Dilute first.

OP/1/A/6150/009, BORON CONCENTRATION CONTROL ENCLOSURE 4.3, DILUTE BOP (Step 3.1) Evaluate all outstanding R&RS NOTE: The CRS may call that may impact performance of this WCC to address the R&Rs.

procedure. If so, Booth Instructor acknowledge as WCC, and report none.

BOP (Step 3.2) IF the lowest NCP seal leakoff is NOTE: All NCP Seal leakoffs less than 2 gpm are normal.

BOP (Step 3.3) Evaluate energizing additional pressurizer heaters per OP/1/A/6100/003 (Controlling Procedure For Unit Operation) to enhance system mixing when changing NC System boron concentration. (R.M.)

BOP (Step 3.4) Determine current blender contents and evaluate any potential Reactivity effects prior to performing this enclosure:

• Rx Makeup Water

• Blend

• Boron BOP (Step 3.5) Determine amount of reactor NOTE: The BOP will add 200 makeup water needed to obtain desired gallons of MU Water.

boron concentration using McGuire Data Book, OAC, Reactor Group Guidance, or plant parameters (T-Ave. Steam Pressure, Xenon worth, etc.). (R.M.)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 11 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments

• Total Reactor Makeup Water:

BOP (Step 3.6) Ensure the following reset to zero:

(R.M.)

• Total Make Up Flow Counter

• Boric Acid Flow Counter BOP (Step 3.7) Set Total Make Up Flow Counter to value determined in Step 3.5.

BOP (Step 3.8) Select DILUTE on NC Sys M/U Controller.

BOP (Step 3.9) IF AT ANY TIME it is desired to adjust reactor makeup water flow, adjust Rx M/U Water Flow Control setpoint to achieve desired flowrate.

BOP (Step 3.10) IF AT ANY TIME it is desired to manually adjust reactor makeup water flow, perform the following:

• Place Rx M/U Water Flow Control in manual.

• Adjust Rx M/U Water Flow Control output to control reactor makeup water flowrate.

BOP (Step 3.11) IF AT ANY TIME it is desired to lower VCT level, perform the following:

• Monitor Letdown Pressure.

• Select HUT on 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl).

• IF Letdown Pressure increases greater than 20 psig, notify CRS.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 12 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments

• AFTER desired level achieved, select AUTO on 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl).

BOP (Step 3.12) IF AT ANY TIME plant parameters require termination of dilution, perform the following:

• Place NC System Make Up to STOP.

(R.M.)

• IF 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl) placed to HUT, place to AUTO.

BOP (Step 3.13) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.14) Check NC System Make Up red light lit.

BOP (Step 3.15) Check 1NV-171A (U1 Boric Acid Blender to VCT Inlet Control) open.

BOP (Step 3.16) Check 1NV-252A (Rx M/U Water Supply To U1 BA Blender Cntrl) open or throttled as required.

BOP (Step 3.17) Check Rx M/U Water Pump start.

BOP (Step 3.18) Monitor Total Make Up Flow Counter. (R.M.)

BOP (Step 3.19) HOLD until one of the following occurs:

• Amount of reactor makeup recorded per Step 3.5 added

• Reactor makeup water addition manually terminated

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 13 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments BOP (Step 3.20) Ensure dilution terminated as follows: (R.M.)

• IF in AUTO, ensure the following off:

• 1A Rx M.U Water Pump

• 1B Rx M/U Water Pump

• Ensure the following closed:

• 1NV-171A (U1 Boric Acid Blender to VCT Inlet Control)

• 1NV-252A (Rx M/U Water Supply To U1 BA Blender Cntrl)

BOP (Step 3.21) Ensure Rx M/U Water Flow Control in auto. (R.M.)

BOP (Step 3.22) IF Rx M/U Water Flow Control adjusted per Step 3.9 OR Step 3.10 BOP (Step 3.23) Ensure 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl) in AUTO.

BOP (Step 3.24) IF desired to flush blender, go to BOP (Step 3.25) Select AUTO for NC Sys M/U Controller.

BOP (Step 3.26) Momentarily select START on NC System Make Up.

BOP (Step 3.27) Check NC System Make Up red light lit.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 14 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments BOP (Step 3.28) Ensure the following reset to zero:

• Total Make Up Flow Counter

• Boric Acid Flow Counter BOP (Step 3.29) Record in Narrative Log that final blender content is Rx Makeup Water.

NOTE: The BOP may repeat this task as needed during the power increase.

OP/1/A/6300/001A, TURBINE-GENERATOR STARTUP/SHUTDOWN ENCLOSURE 4.1, TURBINE-GENERATOR LOAD CHANGE RO (Step 3.5) Changing Turbine Load (Step 3.5.1) IF Turbine in OPERATOR AUTO, perform the following:

• (Step 3.5.1.1) Ensure desired change within Calculated Capability Curve.

• (Step 3.5.1.2) IF turbine load will increase or decrease more than 10 MWs, notify Dispatcher of expected load change.

• (Step 3.5.1.3) Depress LOAD RATE.

• (Step 3.5.1.4) Enter desired load rate in NOTE: the RO will select 2-3 VARIABLE DISPLAY. MWe/Min loading rate.

• (Step 3.5.1.5) Depress ENTER.

• (Step 3.5.1.6) Depress REFERENCE.

• (Step 3.5.1.7) Enter desired load in VARIABLE DISPLAY.

• (Step 3.5.1.8) Depress ENTER.

• (Step 3.5.1.9) Depress GO

• (Step 3.5.1.10) Check load changes at selected rate.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 1 Page 15 of 67 Event

Description:

Power Increase Time Pos. Expected Actions/Behavior Comments OP/1/A/6100/003, CONTROLLING PROCEDURE FOR UNIT OPERATIONS ENCLOSURE 4.1, POWER INCREASE CRS (Step 3.37.14) Continue power increase to NOTE: The power increase 95% RTP. will be at 2-3 MWe/minute.

At the discretion of the Lead Examiner move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 2 Page 16 of 67 Event

Description:

Pzr Level Channel 3 fails LOW During the power increase, Pzr Level channel 3 will fail LOW. The DCS will automatically select a non-failed instrument to replace the failed instrument as the controlling channel, and no NCS inventory control upset will result. The operator will address Technical Specification LCO 3.3.1, Reactor Trip System (RTS)

Instrumentation.

Booth Operator Instructions: insert XMT-NC_1NCLT5170 = 0 Indications Available:

• MCB Annunciator 1AD-2 E8, DCS TROUBLE

• OAC Alarm M1A0976, U1 PZR LEVEL III

• 1NCP-5172, Pzr Level Channel 3 indicates 0%

• DCS Alarm Screen: PZR LVL INPUT TRBL

• Yellow Path on RCS Inventory Time Pos. Expected Actions/Behavior Comments NOTE: The RO will likely go to HOLD on the Turbine.

NOTE: The DCS will auto select a non-failed instrument to control the Pzr level system.

The CRS will evaluate the effect of the failure on Technical specifications.

TECHNICAL SPECIFICATION 3.3.1, REACTOR TRIP SYSTEM (RTS)

INSTRUMENTATION CRS LCO 3.3.1 The RTS instrumentation for NOTE: The CRS will each Function in Table 3.3.1-1 shall be determine that Function 9 (Pzr OPERABLE. Water Level High) of Table 3.3.1-1 is affected by this failure.

CRS APPLICABILITY: According to Table 3.3.1-1.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 2 Page 17 of 67 Event

Description:

Pzr Level Channel 3 fails LOW Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Enter the Immediately NOTE: The CRS will Functions Condition with one or referenced in determine that ACTION A.1 more Table 3.3.1-1 must be entered.

required for the channels channel(s).

inoperable.

M. One channel M.1 Place 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> NOTE: The CRS will inoperable. channel in determine that ACTION M.1 trip.

must be entered.

OR 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> M.2 Reduce THERMAL POWER to

< P-7.

NOTE: The CRS may call WCC/IAE to address.

If so, Booth Instructor acknowledge as WCC/IAE.

NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may re-initiate the power increase.

At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 18 of 67 Event

Description:

Steam Dump Valve fails OPEN After this, the Steam Dump Valve SB-27 will slowly fail to FULL OPEN due to a valve positioner failure. The crew will enter AP/1/A/5500/01, Steam Leak, stabilize turbine load, attempt to close, and ultimately isolate the valve.

Booth Operator Instructions: Insert REM-SB0027 = 1, delay = 0, ramp = 120 seconds Cd=X02_183_1 EQ 1 (OFF/RESET Switch to OFF), insert REM-SB0027 =

0 Indications Available:

• 1SB-27 Red status light LIT

• Tavg-Tref deviation rising

• Rods stepping out in AUTO

• Rx Power rising Time Pos. Expected Actions/Behavior Comments NOTE: The RO will likely go to HOLD on the Turbine, and terminate any dilution in progress.

CONTROL ROOM CREW EXPECTATIONS MANUAL RO Transient load changes: Manual is preferred NOTE: The crew may

- immediately reduce 20MWe and then diagnose an overpower reduce as needed to maintain Rx power less condition and adjust turbine than pre-transient condition. After the initial load per the Crew Expectation 20 MWe load reduction, it is preferred that Manual.

the operators use multiple and diverse indications to determine how much more load should be reduced. TPBE on the OAC updates once per minute. Other indications (PR meters and Delta T meters) will indicate reactor response more quickly and will enable the operators to control the plant even more precisely. (This combines the Operator Fundamental of Conservatism and Controlling Plant Evolutions Precisely).

NOTE: It is likely that the operator will take actions to isolate the Steam Dump Valve prior to being directed by the CRS.

(Step 13)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 19 of 67 Event

Description:

Steam Dump Valve fails OPEN Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/01, STEAM LEAK CRS (Step 1) Monitor Foldout page.

Manual Reactor Trip Criteria: (IF any of the following occur: (1) Steam leak is jeopardizing personnel safety or plant equipment, (2) T-Avg is less than 551°F AND going down, or (3) UST level is less than 1 ft

- NOT Expected).

RO (Step 2) Reduce turbine load to maintain the following:

• Excore NIs - LESS THAN OR EQUAL TO 100%.

• NC Loop D/Ts - LESS THAN 60°F D/T

• T-Avg - AT T-REF.

CRS (Step 3) Check containment entry - IN NOTE: A Containment Entry is PROGRESS. NOT in progress.

CRS (Step 3 RNO) GO TO Step 5.

BOP (Step 5) Check Pzr pressure prior to event -

GREATER THAN P-11 (1955 PSIG).

BOP (Step 6) Check Pzr level - STABLE OR GOING UP.

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN RETURN TO Step 6. both board operators aware.

CRS (Step 8) GO TO Step 12.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 20 of 67 Event

Description:

Steam Dump Valve fails OPEN Time Pos. Expected Actions/Behavior Comments CRS (Step 12) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 13) Identify and isolate leak on Unit 1 as follows:

• (Step 13a) Check SM PORVs -

CLOSED.

RO * (Step 13.b) Check condenser dump NOTE: Steam Dump Valve valves - CLOSED. 1SB-27 was likely closed at the onset of the event. If NOT, it will be closed here.

RO (Step 13b RNO) IF steam dumps required to be closed, THEN perform the following:

• Select OFF RESET on the following NOTE: Selecting OFF/RESET switches: will close the valve.

• STEAM DUMP INTLK BYPASS CHANNEL A

• STEAM DUMP INTLK BYPASS CHANNEL B

• IF valve will not close, THEN dispatch NOTE: The CRS may dispatch operator to CLOSE condenser dump an operator to close the valve isolation valve. isolation valve.

Booth Instructor acknowledge as AO. After 2 Minutes report that the SB-27 inlet isolation valve has been CLOSED (NO LOA).

RO

• WHEN leaking condenser dump valve is isolated OR repaired, THEN return the following switches to ON:

• STEAM DUMP INTLK BYPASS CHANNEL A

• STEAM DUMP INTLK BYPASS Examiner NOTE: This action CHANNEL B. is needed to return the Steam Dumps to operation. Once complete, move forward to Event 4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 21 of 67 Event

Description:

Steam Dump Valve fails OPEN Time Pos. Expected Actions/Behavior Comments BOP * (Step 13.c) Check containment conditions - NORMAL:

• Containment temperature

• Containment pressure

• Containment humidity

• Containment floor and equipment sump level.

RO / * (Step 13.d) Check TD CA pump - OFF.

BOP BOP * (Step 13.e) Check valves on STEAM NOTE: One or more of these LINE DRAIN VALVES board (1MC-9) - valves may be cycling. The CLOSED. RNO will direct closing the valves.

CRS * (Step 13.f) Check opposite Unit (Unit 2) NOTE: CRS may ask U2 RO STEAM HEADER PRESSURE - for AS Header pressure.

GREATER THAN 200 PSIG. If so, Floor Instructor report as U2 RO that U2 Steam Header pressure is 1000 psig.

• (Step 13.g) Dispatch operator to check NOTE: The CRS may dispatch for leaks. an AO to look for leaks.

If so, Floor Instructor:

acknowledge.

Booth Instructor: Report back in 3-5 minutes that there are no leaks.

NOTE: The CRS may NOT dispatch AOs to look for leaks because it is understood that the Steam Dump valve opening was the reason that AP-1 was entered.

BOP (Step 14) Check UST level - STABLE OR GOING UP.

CRS (Step 15) Evaluate unit shutdown as follows:

• Check unit status - IN MODE 1 OR 2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 22 of 67 Event

Description:

Steam Dump Valve fails OPEN Time Pos. Expected Actions/Behavior Comments

• Determine if unit shutdown or load NOTE: CRS may call reduction is warranted based on the WCC/Management to address following criteria: the startup.

If so, Booth Instructor acknowledge as WCC.

• Size of leak

• Location of leak

• Rate of depletion of secondary inventory

• IF steam is leaking from a secondary NOTE: No Relief Valve is heater relief OR MSR relief valve, leaking.

THEN reducing turbine load.

• IF turbine trip will isolate steam leak NOTE: A Turbine Trip is NOT (such as feedwater heater leak or needed to isolate the steam MSR leak) leak.

• Check unit shutdown or load reduction - NOTE: Shutdown/Load REQUIRED. Reduction will NOT be required.

CRS (Step 15.c RNO) Perform the following:

• Maintain present plant conditions until leak can be isolated or repaired.

• Exit this procedure. NOTE: The CRS will likely conduct a Focus Brief.

NOTE: The CRS may address Tech Specs based on plant response.

TECHNICAL SPECIFICATION 3.4.1, RCS PRESSURE, TEMPERATURE, AND FLOW DEPARTURE FROM NUCLEATE BOILING (DNB) LIMITS CRS LCO 3.4.1 RCS DNB parameters for NOTE: If NC System Pressure pressurizer pressure, RCS average drops to < 2216 psig on the temperature, and RCS total flow rate shall be failure, then TS 3.4.1 will be within the limits specified in Table 3.4.1-1. entered and exited during the transient.

CRS APPLICABILITY: MODE 1.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 3 Page 23 of 67 Event

Description:

Steam Dump Valve fails OPEN Time Pos. Expected Actions/Behavior Comments CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. Pressurizer A.1 Restore DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> pressure or parameter(s)

RCS average to within limit.

temperature DNB parameters not within limits.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 24 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Next, a Zone 1B Lockout causes PCB 11 and 12 to open, as well as the 1B Main Generator Breaker to open and the turbine to automatically runback to 56%. The operator will implement AP/1/A/5500/03, Load Rejection. During the runback the operator will notice that the rods do not move in auto, and the operator will need to drive rods in manually. When the Control Rods are driven inward, one Control Bank D rod will stick in its original position. After stabilizing the plant, the operator will address AP/1/A/5500/14, Rod Control Malfunction, to address the Stuck Rod. The operator will address Technical Specification LCO 3.1.4, Rod Group Alignment Limits, and Technical Specification LCO 3.2.4, Quadrant Power Tilt Ratio.

Booth Operator Instructions: insert MAL-EP003C = ACTIVE delay = 10 seconds insert MAL-IRE009 =

FAIL_OF_AUTO insert MAL IRE010D12 = TRUE Indications Available:

• MCB Annunciator 1AD-1, D6, DEH TURBINE RUNBACK, alarms.

• Turbine Generator MWe lowering.

• Tavg-Tref deviation with no Auto Rod motion.

• MCB Annunciator 1AD-11, K3, UNIT 1 LOCKOUT, alarms.

• 1 of 2 Main Generator Breakers is OPEN.

• PCB-11 and 12 OPEN.

Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/03, LOAD REJECTION RO (Step 1) Ensure control rods in auto. Immediate Action NOTE: While the RO will see that the Control Rods are in AUTO, it will also be observed that Rods are NOT moving, and that they are required to move. The RO will inform the CRS of the situation, and the CRS will direct that the RO control the rods in MANUAL to maintain Tavg-Tref.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 25 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments RO (Step 2) Check Turbine Generator response as follows:

• Check Generator - TIED TO GRID.

• Check Generator output - GOING DOWN AS REQUIRED.

RO (Step 3) Check control rod response as follows:

• Check control banks - MOVING IN AS NOTE: The Control Rods will REQUIRED. NOT be moving in as required.

RO (Step 3a RNO) IF no rods will move in auto; THEN perform the following:

• Place Control Rods in manual.

• Insert rods to reduce T-avg equal to programmed T-Ref.

• If no rods will move, THEN.. NOTE: The Control Rods will move in MANUAL.

RO

• Check all rods - ALIGNED WITH ASSOCIATED BANK.

RO (Step 3b RNO) IF two or more control rods NOTE: Only one Control Rod are misaligned greater that 24 steps (D12) is misaligned from Group D.

BOP (Step 4) Check CM system response as follows:

• Standby Hotwell and Condensate Booster pumps - RUNNING.

• 1CM-420 (Unit 1 Generator Load Rejection Bypass control) - OPEN.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 26 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments RO (Step 5) IF runback to 55% power in effect, THEN ensure turbine inlet pressure going down to less than or equal to 500 PSIG.

CRS (Step 6) Announce: UNIT 1 LOAD NOTE: CRS may ask U2 RO REJECTION, NON-ESSENTIAL to make Plant Announcement PERSONNEL STAY OUT OF UNIT 1 that AP-3 has been entered.

TURBINE BLDG. If so, Floor Instructor acknowledge as U2 RO.

RO (Step 7) Check P/R meters - LESS THAN 20%.

CRS / (Step 7 RNO) Perform the following:

RO

• Designate an operator to continuously monitor reactor power.

• IF AT ANY TIME reactor power is less NOTE: This is a Continuous than 20%, THEN perform Step 8 to Action. The CRS will stabilize reactor power. designate the RO to observe this action.

CRS

• GO TO Step 9.

RO (Step 9) Check condenser dump valves - NOTE: If the crew did not MODULATING OPEN. place Steam Dumps back in service, they will need to perform the RNO, and place Steam Dumps in the Steam Pressure Mode.

Otherwise, the crew will go to Step 10.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 27 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments RO (Step 9 RNO) IF TAvg is greater than 4°F NOTE: Depending on Tavg-above TRef, THEN transfer steam dumps to Tref mismatch, the operator steam pressure mode as follows: may or may not place the Steam Dumps in the Steam Pressure Mode.

• Ensure "STM PRESS CONTROLLER" setpoint at 10901095 PSIG.

• Place "STM PRESS CONTROLLER" in manual.

• Adjust "STM PRESS CONTROLLER" output to 0%.

• Using "STEAM DUMP SELECT" switch, place steam dumps in steam pressure mode.

• IF "STEAM HEADER PRESSURE" is greater than 1100 PSIG, THEN manually OPEN steam dumps to control pressure 10901095 PSIG.

• Place "STM PRESS CONTROLLER" in auto.

BOP (Step 10) Check IPB AIR FLOW TROUBLE alarm (1AD-11, J-5) - DARK.

RO (Step 10 RNO) within 15 minutes of lockout initiation, restore IPB cooling as follows:

• IF MAIN GENERATOR less than NOTE: The Main Generator is 10,000 amps NOT < 10,000 amps.

CRS

• Dispatch operator to check the following NOTE: The CRS will dispatch areas for signs of fire and notify Control an AO.

Room of results within 5 minutes:

• 1A Main Step Up Transformer

• 1B Main Step Up Transformer

• Unit 1 IPB Fan Enclosure area.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 28 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments CRS

• Record approximate time lockout occurred.

CRS

• Do not continue until operator has been Booth Instructor:

given sufficient time (approximately 5 Within 3 minutes, as AO minutes) to complete fire inspection. report that there does NOT appear to be a fire around the transformers or IPB Fan area.

CRS

• IF operator confirms a fire has NOTE: No fire has occurred.

occurred CRS

• IF operator confirms no fire has NOTE: The CRS will dispatch occurred, THEN dispatch operator to an AO.

perform the following at the Unit 1 IPB ALARM PANEL:

• Depress LOCKOUT OVERRIDE on Booth Instructor:

the fan in MAN. Insert LOA-IPB003 =

OVERRIDE

• IF IPB fan in MAN cannot be Booth Instructor:

started, Within 3 minutes, as AO report that the Lockout Override has been pressed, and the 1A IPB Fan is running.

CRS

• IF neither IPB fan can be started, . NOTE: The 1A IPB Fan is running.

BOP (Step 11) Check Pzr pressure control response as follows:

• Ensure Pzr heaters are in auto.

• Ensure Pzr spray control valves are in auto.

• Check Pzr PORVs - CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 29 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments

• Check Pzr spray control valves -

CLOSED RO (Step 12) Check load rejection - DUE TO NOTE: The load rejection was LOSS OF CF PUMP. NOT due to a Loss of CF Pump.

CRS (Step 12 RNO) GO TO Step 15 RO (Step 15) Check turbine inlet pressure - NOTE: Turbine Inlet pressure LESS THAN 340 PSIG. is 470 psig.

RO (Step 15 RNO) Perform the following:

• IF AT ANY TIME turbine inlet pressure drops to less than 340 PSIG, THEN GO TO Step 16.

CRS

• GO TO Step 19.

RO (Step 19) Check Main Generator as follows:

• Check Generator Breakers - EITHER GENERATOR BREAKERS CLOSED.

• Check Generator - TIED TO GRID.

• Check generator power factor - 0.9 TO 1.0 LAGGING.

CRS

• GO TO Step 20.

CRS (Step 20) Ensure the following have been NOTE: The CRS may ask implemented: OSM to address.

If so, Floor Instructor acknowledge as OSM.

• RP/0/A/5700/000 (Classification of Emergency)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 30 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments

• RP/0/A/5700/010 (NRC Immediate Notification Requirements).

RO (Step 21) WHEN transient is over, THEN Examiner NOTE: The CRS perform the following: may implement AP14. If so move forward to Page 33.

• Check reactor power - GREATER THAN 40%.

• Check the following on in service CF pump(s):

• Low pressure governor control - IN AUTO

• High pressure governor control - IN AUTO.

• Check SM flow on all S/Gs - LESS NOTE: SM flow is 55%.

THAN 75%.

• Check SM flow on all S/Gs - LESS THAN 25%.

RO (Step 21d RNO) Perform the following:

• Check the following CF control bypass valves - CLOSED:

• 1CF-104AB (1A S/G CF Control Bypass) - CLOSED

• 1CF-105AB (1B S/G CF Control Bypass) - CLOSED

• 1CF-106AB (1C S/G CF Control Bypass) - CLOSED

• 1CF-107AB (1D S/G CF Control Bypass) - CLOSED RO

• IF any CF control bypass valve is open NOTE: All CF control bypass valves are closed.

CRS

• GO TO Step 21.f.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 31 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments BOP

• Slowly CLOSE 1CM-420 (Unit 1 NOTE: The BOP will close Generator Load Rejection Bypass 1CM-420.

Control) while monitoring Condensate Booster pump suction pressure.

• WHEN 1CM-420 is closed, THEN check load rejection signal reset (OAC turn on code CM).

• Reposition manual loader for 1CM-420 to NOTE: The BOP will open 100% OPEN. 1CM-420.

• IF thermal power is greater than 15%,

THEN within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of reaching stable conditions, ensure each power range channel is within 2% of heat balance.

• Check T-Avg - GREATER THAN 561°F.

• Check CONTROL ROD BANK LO LO LIMIT alarm (1AD-2, B-9) - DARK.

• Check CONTROL ROD BANK LO NOTE: 1AD-2, A-9 may be LIMIT alarm (1AD-2, A-9) - DARK. LIT. If so, the operator will perform Step 21.I RNO.

NOTE: The CRS may direct the U2 BOP to conduct a SDM calculation.

If so, Floor Instructor acknowledge.

RO (Step 21.l RNO) Ensure the CONTROL ROD BANK LO LIMIT alarm clears as Xenon builds in.

RO (Step 22) Check load rejection - DUE TO NOTE: The load rejection was LOSS OF CF PUMP. NOT due to a Loss of CF Pump.

CRS (Step 22 RNO) GO TO Step 24.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 32 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments BOP (Step 24) Shutdown unnecessary running NOTE: The CRS may plant equipment as follows: transition to AP-14 based on the failure of Rods to move in AUTO, and the stuck rod.

BOP

• Condensate Booster pumps and place in NOTE: The BOP may stop auto. one Condensate Booster Pump.

• Hotwell pumps and place in auto. NOTE: The BOP may stop one Hotwell Pump.

• IF desired to secure, THEN dispatch operator to shutdown PER OP/1/B/6250/004 (Feedwater Heater Vents, Drains and Bleed System)

Enclosure 4.2 (System Shutdown) the following:

• Unit 1 C Heater Drain Tank pumps

• Unit 1 G Heater Drain Tank pumps.

CRS (Step 25) IF power change greater than 15% NOTE: The CRS may call in one hour, THEN notify Primary Chemistry Chemistry to address the to perform required Tech Spec sampling. power decrease.

If so, Booth Instructor acknowledge as Chemistry.

RO (Step 26) WHEN condenser dump valves closed AND no longer required for temperature control, THEN reset C-7A using STEAM DUMP SELECT switch.

NOTE: The CRS may transition to AP-14 based on the failure of Rods to move in AUTO, and the stuck rod, or assign the RO to perform AP14 simultaneously with AP3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 33 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/14, ROD CONTROL MALFUNCTION RO (Step 1) IF two or more rods are either Immediate Action dropped OR misaligned by great than 24 NOTE: Only one Rod is steps, misaligned during this event.

RO (Step 2) Place control rods in manual. Immediate Action NOTE: The RO will place the rods in Manual.

RO (Step 3) Check rod movement - STOPPED. Immediate Action RO (Step 4) Check all rods - ALIGNED WITH ASSOCIATED BANK.

RO (Step 4 RNO) Perform the following.

• IF misaligned rod(s) due to DRPI NOTE: Only one rod is indication failure only, misaligned.

• IF T-Avg has gone down,.. NOTE: The RO may adjust load on the Turbine to maintain Tavg-Tref = 1oF.

• GO TO Enclosure 1 (Response To Dropped or Misaligned Rod)

NOTE: The CRS will transition to Enclosure 1.

AP/1/A/5500/14, ROD CONTROL MALFUNCTION ENCLOSURE 1, RESPONSE TO DROPPED OR MISALIGNED ROD CRS (Step 1) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement that AP-14 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 34 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments CRS (Step 2) Dispatch rod control system NOTE: The CRS may call qualified IAE to perform the following: WCC/IAE to address.

If so, Booth Instructor acknowledge as WCC/IAE.

After 2-3 Minutes call as IAE and report that Control Rod D-12 has a Blown Lift Coil Fuse.

• Correct cause of misaligned rod.

• Notify Control Room operators when auto or manual rod motion is available for reactivity control.

RO (Step 3) Do not move rods until IAE determines rod movement is available.

CRS (Step 4) IF AT ANY TIME a runback occurs NOTE: A runback has already while in this procedure, THEN .. occurred, and the Control Rods have been moved in MANUAL.

RO (Step 5) Check ROD CONTROL URGENT FAILURE alarm (1AD-2, A-10) - DARK.

RO (Step 6) Use OAC point M1P1385 (Reactor Thermal Power, Best Estimate) to determine reactor power in subsequent steps.

RO (Step 7) Check AFD (Tech Spec 3.2.3) -

WITHIN TECH SPEC LIMITS.

CRS (Step 8) REFER TO the following Tech Specs while continuing in the enclosure:

• Tech Spec 3.1.4 (Rod Group Alignment NOTE: The CRS may check Limits). the TS now and conclude that LCO 3.1.4 must be entered.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 35 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments

• Tech Spec 3.1.5 (Shutdown Bank Insertion Limits).

• Tech Spec 3.1.6 (Control Bank Insertion Limits).

• Tech Spec 3.2.4 (QPTR) NOTE: The CRS may check the TS now and conclude that LCO 3.2.4 must be entered.

• Ensure shutdown margin calculation is performed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Examiner NOTE: It is intended that the CRS evaluate the TS at this point.

If the CRS requests the WCC evaluate the TS, and continues with Enclosure 1 of AP14, move to the next event, and evaluate the TS after the exam has been completed.

TECHNICAL SPECIFICATION 3.1.4, ROD GROUP ALIGNMENT LIMITS CRS LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with all individual indicated rod positions within 12 steps of their group step counter demand position.

CRS APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 36 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments B. One rod not B.1Restore rod 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> NOTE: The CRS will to within within alignment determine that ACTION B.1, alignment B.2.1.1, or B.2.1.2, B.2.2, limits. limits.

B.2.3, B.2.4, B.2.5 and B.2.6 OR must be entered.

B.2.1.1 Verify SDM is 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within the limit specified in the COLR.

OR B.2.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.

AND B.2.2 Reduce 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> THERMAL POWER to

< 75% RTP.

AND B.2.3 Verify SDM is within the Once per limit specified 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> in the COLR.

AND B.2.4 Perform SR 3.2.1.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND B.2.6 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

TECHNICAL SPECIFICATION 3.2.4, QUADRANT POWER TILT RATIO CRS LCO 3.2.4 The QPTR shall be 1.02.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 37 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments CRS APPLICABILITY: MODES 1 with THERMAL POWER >50% RTP.

ACTIONS CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that ACTIONs A.1 through A.7 must be entered A.1 Reduce 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> A. QPTR not THERMAL as long as reactor power within limit. POWER remains > 50%.

3% from RTP for each 1% of QPTR

>1.02.

AND A.2 Perform SR Once per 12 3.2.4.1 and hours reduce THERMAL POWER 3% from RTP for each 1% of QPTR

>1.02.

AND A.3 Perform SR 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 3.2.1.1 and SR 3.2.2.1. AND Once per 7 AND days thereafter A.4 Reduce Power Range 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> Neutron Flux

- High Trip Setpoint 3%

for each 1%

of QPTR >

1.02.

AND A.5 Reevaluate safety Prior to analyses and increasing confirm THERMAL results POWER above

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 38 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments remain valid the more for duration restrictive limit of operation of Required under this Action A.1 or condition. A.2 AND A.6 Calibrate Prior to excore increasing detectors to THERMAL show zero POWER above QPT. the more restrictive limit of Required Action A.1 or AND A.2 A.7 Perform SR 3.2.1.1 and Within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 3.2.2.1. after reaching RTP OR Within 48 hours5.555556e-4 days <br />0.0133 hours <br />7.936508e-5 weeks <br />1.8264e-5 months <br /> after increasing THERMAL POWER above the more restrictive limit of Required Action A.1 or A.2 TECHNICAL SPECIFICATION 3.1.6, CONTROL BANK INSERTION LIMITS CRS LCO 3.1.6 Control banks shall be within the NOTE: Based on rod insertion insertion, sequence, and overlap limits the RIL may NOT be met specified in the COLR. (Figure 3, Control Bank Insertion Limits vs. Percent Rated Thermal Power).

If RIL is exceeded based on Step counter position and Reactor Thermal Power, the ACTION identified below is required.

CRS APPLICABILITY: MODES 1 and 2 with Keff

> 1.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 4 Page 39 of 67 Event

Description:

Zone 1B Lockout causing Runback/Rods fail to move in AUTO/Stuck Rod Time Pos. Expected Actions/Behavior Comments ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME NOTE: The CRS will A. Control bank A.1.1 Verify SDM 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> is within the determine that ACTION A.1.1 insertion limits not limit specified or A.1.2, and A.2 must be met. in the COLR. entered (If RIL has been exceeded).

OR A.1.2 Initiate boration to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> restore SDM to within limit.

AND A.2 Restore control 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> bank(s) to within limits.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 5 Page 40 of 67 Event

Description:

1KC-425 fails CLOSED Subsequently, 1KC-425, NC Pumps Ret Hdr Cont Outside Isol), will fail CLOSED. The operator will respond per OP/1/A/6100/010 G, Annunciator Response for 1AD-6, B1, A NC PUMP UPPER MTR BRG LO KC FLO, and manually open the valve. The operator may enter AP/1/A/5500/08, Malfunction of NC Pump.

Booth Operator Instructions: Insert REM-KC0425A = 0 delIA REM-KC0425A = 2, cd=X11_135_1=1 Indications Available:

• 1KC-425 Green status light LIT, Red status light OFF

• MCB Annunciator 1AD-6, B1-4, A-D NC PUMP UPPER MTR BRG LO KC FLO, alarms

• MCB Annunciator 1AD-6, D1-4, A-D NC PUMP LOWER MTR BRG LO KC FLO, alarms

• OAC Alarm M1Q1320, 1KC425A NC PMPS RET HDR CONT OUTSIDE ISOL CLOSED Time Pos. Expected Actions/Behavior Comments NOTE: The BOP may recognize that 1KC-425A is in Mid-Position, and attempt to OPEN the valve.

If so, the valve will OPEN.

1AD-6, B1, A NC PUMP UPPER MTR BRG LO KC FLO CRS (IA Step 1) IF loss of KC, go to NOTE: The KC System is AP/1/A/5500/021 (Loss of KC or KC System operating as expected.

Leak).

BOP (IA Step 2) Check open:

1KC-338B (NC Pump Sup Hdr Cont Outside Isol) 1KC-424B (NC Pumps Ret Hdr Cont Inside Isol) 1KC-425A (NC Pumps Ret Hdr Cont Outside NOTE: 1KC-425A has Isol) inadvertently closed.

BOP (IA Step 3) IF KC flow inadequate:

Ensure adequate number of KC Pumps running.

Adjust KC flow/pressure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 5 Page 41 of 67 Event

Description:

1KC-425 fails CLOSED Time Pos. Expected Actions/Behavior Comments IF low flow still exists, go to AP/1/A/5500/008 NOTE: The crew may elect to (Malfunction of NC Pump). go to AP8 to re-open the valve.

1AD-6, D1, A NC PUMP LOWER MTR BRG LO KC FLO CRS (IA Step 1) IF loss of KC, go to NOTE: The KC System is AP/1/A/5500/021 (Loss of KC or KC System operating as expected.

Leak).

BOP (IA Step 2) Check open:

1KC-338B (NC Pump Sup Hdr Cont Outside Isol) 1KC-424B (NC Pumps Ret Hdr Cont Inside Isol) 1KC-425A (NC Pumps Ret Hdr Cont Outside NOTE: 1KC-425A has Isol) inadvertently closed.

BOPO (IA Step 3) IF 1KC-388 (A NC Pump Motor NOTE: 1KC-388 has NOT Lwr Brg Clr Throttle) has been closed, return been closed.

valve to throttled position.

BOP (IA Step 4) IF KC flow inadequate:

Ensure adequate number of KC Pumps running.

Adjust KC flow/pressure.

IF low flow still exists, go to AP/1/A/5500/008 NOTE: The crew may elect to (Malfunction of NC Pump). go to AP8 to re-open the valve.

Examiner NOTE: If at any time, the crew re-opens 1KC-425A, or decides to take action to stop the NC Pumps, MOVE to Events 6-9.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 5 Page 42 of 67 Event

Description:

1KC-425 fails CLOSED Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/08, MALFUNCTION OF NC PUMP CASE II, NC PUMP MOTOR OR MOTOR BEARING MALFUNCTION BOP (Step 1) Check abnormal NC Pump parameter - KNOWN TO BE VALID.

RO/ (Step 2) Check NC Pump parameters within BOP operating limits:

All NC Pump stator winding temperatures -

LESS THAN 311°F All NC Pump motor bearing temperatures -

LESS THAN 195°F All NC Pump oil reservoir level computer points - INDICATING BETWEEN (-)1.25 AND (+)1.25.

CRS (Step 3) IF AT ANY TIME any operating limit NOTE: This is a Continuous in Step 2 exceeded, THEN GO TO Step 5. Action. The CRS will make both board operators aware.

CRS (Step 4) GO TO Step 6.

CRS (Step 6) Announce occurrence on paging NOTE: The CRS may ask U2 system. RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

CRS (Step 7) Correct any of the following which may affect NC Pump stator or motor bearing cooling:

• High ambient temperature NOTE: The BOP will report

• Abnormal NC Pump bus voltage that abnormal KC flow

• Interference with ventilation alignment and flow exists. If

• Abnormal RN alignment and flow 1KC-425A has not been

• Abnormal KC alignment and flow previously opened, it will be

• High KC temperature opened here.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 5 Page 43 of 67 Event

Description:

1KC-425 fails CLOSED Time Pos. Expected Actions/Behavior Comments RO/ (step 8) Check all NC Pump oil reservoir BOP level computer alarms - CLEAR.

CRS (Step 9) IF abnormal NC Pump parameter(s) NOTE: CRS may call still exist, THEN contact Engineering for WCC/Engineering to address guidance. the situation.

If so, Booth Instructor acknowledge as WCC.

RO/ (Step 10) Monitor the following NC Pump BOP parameters:

Stator winding temperatures (OAC) -

STABLE OR GOING DOWN Motor bearing temperatures (OAC) -

STABLE OR GOING DOWN Vibration - NORMAL Oil reservoir levels (OAC) - STABLE.

BOP (Step 11) Check NC Pumps - ANY RUNNING.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner, move to Events #6-9.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 44 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Following this a steam break will occur on the Main Steam Equalization Header in the Turbine Building. Simultaneously all four MSIVs will fail OPEN resulting in four faulted Steam Generators (Both Auto and Manual actuations of MSI have failed). Additionally, the 1A/1B MD CA Pump will fail to start automatically. The operator will be expected to manually start the 1A and 1B MD CA Pumps. The crew will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection and transition to EP/1/A/5000/E-2, Faulted Steam Generator Isolation. On the other hand, due to the NCS cooldown, an Orange Path could exist on the NCS Integrity Critical Safety Function. If so, the crew will transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition. If the crew made the transition to E-2, the crew will transition to EP/1/A/5000/ECA-2.1 at Step 4 of E-2 when it is determined that all four Steam Generator pressures are lowering. On the other hand, if the crew transitions to FR-P.1, the crew will take the actions required by ECA-2.1, in FR-P.1 (i.e. reduce feed flow to each Steam Generator to 25 gpm each, depressurize NCS and terminate SI). It is expected that the crew will eventually transition to EP/1/A/5000/FR-P.1, Response to Imminent Pressurized Thermal Shock Condition. The scenario will terminate at Step 11.c of FR-P.1 after the operator has closed 1NI-9A and 10B.

Booth Operator Instructions: insert MAL-SM009 = 16500000 insertMAL-ISE006A = BLOCK_BOTH (MSI Fails in AUTO/MANUAL) insertMAL-ISE006B = BLOCK_BOTH (MSI Fails in AUTO/MANUAL) insertMAL-SM006A = TRUE 1A MSIV Fails OPEN (Cd

= H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006B = TRUE 1B MSIV Fails OPEN (Cd

= H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006C = TRUE 1C MSIV Fails OPEN (Cd

= H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

insertMAL-SM006D = TRUE 1D MSIV Fails OPEN (Cd

= H_X01_094_2 EQ1 [1A Rx Trip Breaker OPEN light ON])

Indications Available:

• Steam flows higher than expected for current plant conditions

• Pzr pressure is lowering

• MSIVs are all OPEN

• SI Actuation Time Pos. Expected Actions/Behavior Comments NOTE: Crew will carry out Immediate Actions of E-0, prior to the CRS addressing the EP.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 45 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments EP/1/A/5000/E-0, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria:

CA Suction Sources:

Position Criteria for 1NV150B and 1NV 151A (U1 NV Pump Recirc Isol):

Ruptured S/G Aux Feedwater Isolation Criteria:

Faulted S/G Aux Feedwater Isolation Criteria:

RO (Step 2) Check Reactor trip: Immediate Action

• All rod bottom lights - LIT

• Reactor trip and bypass breakers -

OPEN

• I/R amps - GOING DOWN.

RO (Step 3) Check Turbine Trip: Immediate Action

• All throttle valves - CLOSED.

BOP (Step 4) Check 1ETA and 1ETB - Immediate Action ENERGIZED.

RO/ (Step 5) Check if S/I is actuated: Immediate Action BOP

• A SAFETY INJECTION ACTUATED status light (1SI-18) - LIT.

• Both LOCA Sequencer Actuated status lights (1SI-14) - LIT.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 46 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments CRS (Step 6) Announce Unit 1 Safety Injection. NOTE: CRS may ask U2 RO to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 7) Check all Feedwater Isolation status lights (1SI-4) - LIT.

BOP (Step 8) Check Phase A RESET lights -

DARK.

BOP (Step 9) Check ESF Monitor Light Panel on energized train(s):

• Groups 1, 2, 5 - DARK.

• Group 3 - LIT.

• Group 4 - LIT AS REQUIRED.

• Group 6 - LIT

• GO TO Step 10 RO/ (Step 10) Check proper CA pump status:

BOP

• MD CA pumps - ON NOTE: Both MDCA Pumps have failed to Auto-start.

RO/ (Step 10.a RNO) Start pumps. NOTE: The crew will be able to BOP start the 1A/1B MDCA Pumps manually.

RO/

• N/R level in at least 3 S/Gs - GREATER BOP THAN 17%.

RO/ (Step 10.b RNO) Ensure TD CA pump on. NOTE: The TD CA Pump is BOP OOS.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 47 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments BOP (Step 11) Check all KC pumps - ON.

BOP (Step 12) Check both RN pumps - ON.

CRS (Step 13) Notify Unit 2 to perform the Floor Instructor: As U2 RO following: report 2A RN Pump is running.

• Start 2A RN pump.

RO

• THROTTLE Unit 2 RN flow to minimum Booth Instructor:

for existing plant conditions. insert LOA-RN087 (Start 2A RN Pump) insert LOA-RN083 8050.000000 delay=0 ramp=10 (Unit 2 Train A Demand Flow)

RO (Step 14) Check all S/G pressures -

GREATER THAN 775 PSIG.

RO (Step 14 RNO) Perform the following: NOTE: ALL SG Pressures are decreasing uncontrollably.

• Check the following valves closed:

• All MSIVs NOTE: All MSIVs are OPEN, and cannot be closed.

• All MSIV Bypass Valves

• All SM PORVs

• IF any valve open, THEN perform the following:

• Initiate Main Steam Isolation signal.

• IF any valve still open, THEN CLOSE valve.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 48 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments RO/ (Step 15) Check containment pressure -

BOP HAS REMAINED LESS THAN 3 PSIG.

BOP (Step 16) Check S/I flow:

• Check NV PMPS TO COLD LEG FLOW gauge - INDICATING FLOW.

• Check NC pressure - LESS THAN 1600 PSIG.

• Check NI pumps INDICATING FLOW.

• Check NC pressure LESS THAN 275 PSIG.

BOP (Step 16.d RNO) Perform the following:

• Ensure ND pump miniflow valve on running pump(s) OPEN:

• 1ND68A (1A ND Pump & Hx Mini Flow Isol)

• 1ND67B (1B ND Pump & Hx Mini Flow Isol).

• IF valve(s) open on all running ND pumps, THEN GO TO Step 17.

CRS (Step 17) Notify OSM or other SRO to NOTE: The CRS may ask perform EP/1/A/5000/G-1 (Generic OSM to address.

Enclosures), Enclosure 22 (OSM Actions If so, Floor Instructor Following an S/I) within 10 minutes. acknowledge as OSM.

RO/ (Step 18) Check CA flow:

BOP

• Total CA flow - GREATER THAN 450 GPM.

BOP

• Check VI header pressure - GREATER THAN 60 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 49 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments RO

• WHEN each S/G N/R level is greater than 11% (32% ACC), THEN control CA flow to maintain that S/G N/R level between 11% (32% ACC) and 50%.

Critical Task:

Establish 450 gpm of CA Flow to the Steam Generators during the performance of E-0 such that transition to EP/1/A/5000/FR-H.1 is not required.

Safety Significance: Failure to establish a Secondary Heat Sink through the initiation of CA flow unnecessarily challenges both the HEAT SINK and the CORE COOLING Critical Safety Functions. Additionally, the FSAR Safety Analysis results are predicated on the assumption that at least one train of safeguards actuates and delivers a minimum amount of AFW flow to the Steam Generators. Failure to perform this task, when the ability to do so exists, results in a violation of the Facility License Condition and places the plant in an unanalyzed condition.

RO (Step 19) Check NC temperatures:

• IF all NC pumps off, THEN check NC T-Colds - STABLE OR TRENDING TO 557°F.

RO (Step 19 RNO) Perform the following based NOTE: The CRS may assign on plant conditions: the RO to perform this action.

If so, RO Examiner follow actions of Enclosure 3.

Others should move ahead to Step 20 on Page 51 to continue in E-0.

• IF temperature less than 557°F AND going down, THEN attempt to stop cooldown PER Enclosure 3 (Uncontrolled NC System Cooldown).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 50 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments E-0, REACTOR TRIP OR SAFETY INJECTION ENCLOSURE 3, UNCONTROLLED NC SYSTEM COOLDOWN RO (Step 1) Check steam dump valves - Examiner NOTE: Follow the CLOSED. actions associated with Enclosure 3 if RO is assigned by CRS to perform.

RO (Step 2) Check all SM PORVs - CLOSED.

RO (Step 3) Check MSR RESET light - LIT.

RO (Step 4) Check any NC pump - ON.

RO (Step 5) Check NC T-avg - GOING DOWN RO (Step 6) Control feed flow as follows:

• IF S/G N/R level is less than 11% (32%

ACC) in all S/Gs, THEN THROTTLE feed flow to achieve the following:

• Minimize cooldown

• Maintain total feed flow greater than 450 GPM.

• WHEN N/R level is greater than 11%

(32% ACC) in at least one S/G, THEN THROTTLE feed flow further to:

• Minimize cooldown

• Maintain at least one S/G N/R level greater than 11% (32% ACC).

RO (Step 7) Check MSIVs - ANY OPEN. NOTE: All MSIVs will be OPEN.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 51 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments RO (Step 8) CLOSE 1SM15 (U1 SM To MSR 2nd Stg Tube Bundles Isol).

RO (Step 9) Check any NC pump ON.

RO (Step 10) Check NC TAvg STABLE.

RO (Step 10 RNO) IF cooldown continues, THEN CLOSE the following valves:

• All MSIVs NOTE: All MSIVs have failed OPEN.

• All MSIV Bypass Valves.

RO (Step 11) Notify Control Room Supervisor of the following:

• NC temperature trend

• Status of MSIV and Bypass Valves.

E-0, REACTOR TRIP OR SAFETY INJECTION Examiner NOTE: Examiners NOT following RO actions in Enclosure 3, continue HERE.

BOP (Step 20) Check Pzr PORV and spray valves:

• All Pzr PORVs - CLOSED.

BOP

• Normal Pzr spray valves - CLOSED.

• At least one Pzr PORV isolation valve -

OPEN.

BOP (Step 21) Check NC subcooling based on core exit T/Cs - GREATER THAN 0°F.

BOP (Step 22) Check if main steamlines intact:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 52 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• All S/G pressures - STABLE OR GOING NOTE: All SG pressures are UP lowering uncontrollably.

• All S/Gs - PRESSURIZED.

BOP (Step 22 RNO) IF any S/G is faulted, THEN perform the following:

CRS

• Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

CRS

• GO TO EP/1/A/5000/E-2 (Faulted Steam NOTE: The CRS will transition Generator Isolation). to E-2.

Examiner NOTE: If at any time, a RED or ORANGE Path on INTEGRITY occurs, proceed to the Actions of FR-P.1 on Page 61.

EP/1/A/5000/E-2, FAULTED STEAM GENERATOR ISOLATION RO/ (Step 1) Monitor Foldout page.

BOP Cold Leg Recirc Switchover Criteria:

CA Suction Sources:

Position Criteria for 1NV-150B and 1NV-151A (U1 NV Pump Recirc Isol):

CRS (Step 2) Maintain any faulted S/G or secondary break isolated during subsequent recovery actions unless needed for NC System cooldown.

RO (Step 3) Check the following - CLOSED:

• All MSIVs NOTE: All MSIVs have failed OPEN.

• All MSIV bypass valves.

RO (Step 3 RNO) Perform the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 53 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• CLOSE valves.

• IF any valve cannot be closed, THEN initiate Main Steam Isolation signal.

RO (Step 4) Check at least one S/G pressure - NOTE: ALL SG pressures will STABLE OR GOING UP. be lowering.

CRS (Step 4 RNO) IF all S/Gs faulted, THEN GO NOTE: The CRS will transition TO EP/1/A/5000/ECA-2.1 (Uncontrolled to ECA-2.1.

Depressurization Of All Steam Generators).

Examiner NOTE: If at any time, a RED or ORANGE Path on INTEGRITY occurs, proceed to the Actions of FR-P.1 on Page 61.

EP/1/A/5000/ECA-2.1, UNCONTROLLED DEPRESSURIZATION OF ALL STEAM GENERATORS RO/ (Step 1) Monitor Foldout page.

BOP NC Pump Trip Criteria S/I Reinitiation Criteria E-2 Transition Criteria SGTR Transition Criteria Cold Leg Recirc Switchover Criteria CA Suction Sources Position Criteria for 1NV-150B and 1NV-151A (NV Pumps Recirculation)

RO/ (Step 2.a.1) Check secondary pressure BOP boundary:

• For 1A S/G:

• Check 1A S/G MSIV CLOSED. NOTE: The MSIV has failed OPEN.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 54 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments RO/ (Step 2.a.1 RNO) Perform the following:

BOP

• CLOSE valve.

• IF MSIV cannot be closed, THEN NOTE: The CRS will dispatch dispatch operator to CLOSE valve PER an AO.

Enclosure 2 (Local Closure Of MSIVs). Floor Instructor/Booth Instructor: as AO, acknowledge.

RO/ (Step 2.a.2-6) Check 1A S/G MSIV bypass BOP valve CLOSED.

• Check 1A SM PORV CLOSED.

• Check "S/G A FDW ISOLATED" status light (1SI4) LIT.

• Check the following BB valves CLOSED:

• 1BB1B (1A S/G Blowdown Cont Outside Isol Control)

• 1BB5A (A S/G BB Cont Inside Isol).

• CLOSE 1SM83 (A SM Line Drain Isol).

RO/ (Step 2.b.1) Check secondary pressure BOP boundary:

• For 1B S/G:

• Check 1B S/G MSIV CLOSED. NOTE: The MSIV has failed OPEN.

RO/ (Step 2.b.1 RNO) Perform the following:

BOP

• CLOSE valve.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 55 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• IF MSIV cannot be closed, THEN NOTE: The CRS will dispatch dispatch operator to CLOSE valve PER an AO.

Enclosure 2 (Local Closure Of MSIVs). Floor Instructor/Booth Instructor: as AO, acknowledge.

RO/ (Step 2.b.2-9) Check 1B S/G MSIV bypass BOP valve CLOSED.

• Check 1B SM PORV CLOSED.

• Check "S/G B FDW ISOLATED" status light (1SI4) LIT.

• Check the following BB valves CLOSED:

• 1BB2B (1B S/G Blowdown Cont Outside Isol Control)

• 1BB6A (B S/G BB Cont Inside Isol).

• CLOSE 1SM89 (B SM Line Drain Isol).

• Check 1A or 1B CA pump AVAILABLE.

• Dispatch operator to trip Unit 1 TD CA NOTE: The TDCA Pump is pump stop valve. OOS.

• Dispatch operator to unlock and CLOSE the following valves:

• 1SA2 (1B S/G SM Supply to Unit 1 NOTE: The TDCA Pump is TD CA Pump Turb Maint Isol) (Unit OOS.

1 interior doghouse, 767+12, FF 53)

• 1SA78 (1B S/G SM Supply to Unit 1 TD CA Pump Turb Loop Seal Isol)

(Unit 1 interior doghouse, 767+10, FF53).

RO/ (Step 2.c.1) Check secondary pressure BOP boundary:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 56 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• For 1C S/G:

• Check 1C S/G MSIV CLOSED. NOTE: The MSIV has failed OPEN.

RO/ (Step 2.c.1 RNO) Perform the following:

BOP

• CLOSE valve.

• IF MSIV cannot be closed, THEN NOTE: The CRS will dispatch dispatch operator to CLOSE valve PER an AO.

Enclosure 2 (Local Closure Of MSIVs). Floor Instructor/Booth Instructor: as AO, acknowledge.

RO/ (Step 2.c.2-9) Check 1C S/G MSIV bypass BOP valve CLOSED.

• Check 1C SM PORV CLOSED.

• Check "S/G C FDW ISOLATED" status light (1SI4) LIT.

• Check the following BB valves CLOSED:

• 1BB3B (1C S/G Blowdown Cont Outside Isol Control)

• 1BB7A (C S/G BB Cont Inside Isol).

• CLOSE 1SM95 (C SM Line Drain Isol).

• Check 1A or 1B CA pump AVAILABLE.

• Dispatch operator to trip Unit 1 TD CA NOTE: The TDCA Pump is pump stop valve. OOS.

• Dispatch operator to unlock and CLOSE the following valves:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 57 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• 1SA1 (1C S/G SM Supply to Unit 1 NOTE: The TDCA Pump is TD CA Pump Turb Maint Isol) (Unit OOS.

1 interior doghouse, 767+10, FF53, above ladder)

• 1SA77 (1C S/G SM Supply to Unit 1 TD CA Pump Turb Loop Seal Isol)

(Unit 1 interior doghouse, 767+10, FF53).

RO/ (Step 2.d.1) Check secondary pressure BOP boundary:

• For 1D S/G:

• Check 1D S/G MSIV CLOSED. NOTE: The MSIV has failed OPEN.

RO/ (Step 2.d.1 RNO) Perform the following:

BOP

• CLOSE valve.

• IF MSIV cannot be closed, THEN NOTE: The CRS will dispatch dispatch operator to CLOSE valve PER an AO.

Enclosure 2 (Local Closure Of MSIVs). Floor Instructor/Booth Instructor: as AO, acknowledge.

RO/ (Step 2.d.2-6) Check 1D S/G MSIV bypass BOP valve CLOSED.

• Check 1D SM PORV CLOSED.

• Check "S/G D FDW ISOLATED" status light (1SI4) LIT.

• Check the following BB valves CLOSED:

• 1BB4B (1D S/G Blowdown Cont Outside Isol Control)

• 1BB8A (D S/G BB Cont Inside Isol).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 58 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• CLOSE 1SM101 (D SM Line Drain Isol).

RO/ (Step 2.e) WHEN any S/G pressure BOP boundary restored, THEN ensure "E2 Transition Criteria" on foldout page is evaluated.

BOP (Step 3) Reset the following:

• S/I.

• Sequencers.

• Phase A Isolation.

• Phase B Isolation.

• IF AT ANY TIME a B/O signal occurs, THEN restart S/I equipment previously on.

BOP (Step 4) Establish VI to containment as follows:

• OPEN the following valves:

• 1VI129B (VI Supply to A Cont Ess VI Hdr Outside Isol).

• 1VI160B (VI Supply to B Cont Ess VI Hdr Outside Isol).

• 1VI150B (Lwr Cont NonEss Cont Outside Isol).

• Check VI header pressure GREATER THAN 85 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 59 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments CRS (Step 5) WHEN TSC is staffed, THEN NOTE: The CRS may call request TSC to evaluate obtaining samples WCC/TSC to address the and monitor shutdown margin during samples.

cooldown as follows: If so, Booth Instructor acknowledge as WCC and report that the TSC is NOT staffed yet.

• Evaluate obtaining samples as follows:

• Consider available cooling of sample Hx's as follows:

• KC will remain isolated to normal sample Hx's for 10 hours1.157407e-4 days <br />0.00278 hours <br />1.653439e-5 weeks <br />3.805e-6 months <br />, until KC is realigned to normal sample Hx's and KF per AP/1/A/5500/41 (Loss Of Spent Fuel Cooling or Level).

• IF sample is desired prior to aligning KC to KC aux bldg.

nonessential header, AND fuel damage is not expected, THEN evaluate obtaining sample PER OP/1/A/6200/128 (Unit 1 Primary Systems Emergency Response Sampling), Enclosure 4.4 (1NC Hot Leg with KC Nonessential Header Isolated).

• Evaluate obtaining periodic NC System boron sample to check shutdown margin during cooldown.

• WHEN each NC boron sample obtained, THEN perform the following:

• Perform shutdown margin calculation for Cold Shutdown PER OP/0/A/6100/006 (Reactivity Balance Calculation).

• Check shutdown margin ADEQUATE.

RO/ (Step 6) Control feed flow to minimize NC BOP System cooldown as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 60 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments Check all S/G N/R levels GREATER THAN NOTE: All S/G NR levels are 11% (32% ACC). likely < 11%.

If not, the crew will proceed to Step 6.b.

RO/ (Step 6 RNO) Maintain at least 25 GPM feed BOP flow to any S/G with a N/R level less than 11% (32% ACC).

RO/ (Step 6.b) Check cooldown rate in NC BOP TColds LESS THAN 100°F IN AN HOUR.

RO/ (Step 6.b RNO) Perform the following:

BOP

• Reduce feed flow to 25 GPM to each S/G.

• GO TO Step 6.d.

Critical Task:

Control the CA Flowrate to approximately 25 gpm per SG in order to minimize the NC Cooldown rate in ECA-2.1 or FR-P.1.

Safety Significance: Failure to control the CA flow rate to the SGs, when able to do so, leads to an unnecessary and avoidable severe or extreme challenge to the Integrity CSF. Also, failure to perform the Critical Task increases challenges to the Subcriticality Critical Safety Function which otherwise would not occur. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

Examiner NOTE: if the crew has established 25 gpm to each S/G here, and not entered FR-P.1, terminate Exam.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 61 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments EP/1/A/5000/FR-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITION Examiner NOTE: The crew may enter this procedure at any time after exiting E-0, based on a RED or ORANGE Path on INTEGRITY.

RO (Step 1) Check NC pressure - GREATER THAN 275 PSIG.

RO/ (Step 2) Monitor Foldout Page.

BOP Cold Leg Recirc Switchover Criteria:

CA Suction Sources:

Position Criteria for 1NV-150B and 1NV-151A (U1 NV Pump Recirc Isol):

RO (Step 3) Check NC T-Colds - STABLE OR GOING UP.

RO (Step 3 RNO) Try to stop NC System cooldown as follows:

• Ensure SM PORVs CLOSED.

• IF any SM PORV cannot be closed, NOTE: The SM PORVs are THEN. CLOSED.

• Ensure condenser dump valves CLOSED.

• IF ND in RHR mode, THEN .. NOTE: The plant is NOT in the ND Mode.

• Identify faulted S/G(s) as follows:

• Any S/G pressure going down in an uncontrolled manner.

OR

• Any S/G depressurized. NOTE: All SGs are Faulted.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 62 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• IF VI is not available for CA flow control in subsequent steps, THEN

• Control feed flow to non-faulted S/G(s) to NOTE: All SGs are Faulted.

stop NC System cooldown as follows:

• Minimize cooldown from faulted S/G(s) as follows:

• Ensure the following valves CLOSED for each faulted S/G:

• MSIV NOTE: All MSIVs have failed OPEN.

• MSIV bypass valve.

• IF TD CA pump is the only source of feedwater, THEN maintain steam flow to it from at least one S/G.

• IF S/G B or C faulted, THEN NOTE: BOTH the 1B and 1C dispatch operator to unlock and SGs are Faulted.

CLOSE isolation valves on faulted S/G(s):

• S/G B: NOTE: The CRS will dispatch an AO.

Floor Instructor: as AO, acknowledge.

Booth Instructor: insert REM-SA0002 = 0 (Close SA-2)

• 1SA-2 (1B S/G SM Supply to Unit 1 TD CA Pump Turb Maint Isol) (Unit 1 interior doghouse, 767+12, FF-53)

• 1SA-78 (1B S/G SM Supply to Unit 1 TD CA Pump Turb Loop Seal Isol) (Unit 1 interior doghouse, 767+10, FF-53).

• S/G C: NOTE: The CRS will dispatch an AO.

Floor Instructor: as AO, acknowledge.

Booth Instructor: insert REM-SA0001 = 0 (Close SA-1)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 63 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• 1SA-1 (1C S/G SM Supply to Unit 1 TD CA Pump Turb Maint Isol) (Unit 1 interior doghouse, 767+10, FF-53, above ladder)

• 1SA-77 (1C S/G SM Supply to Unit 1 TD CA Pump Turb Loop Seal Isol) (Unit 1 interior doghouse, 767+10, FF-53).

• CLOSE 1AS-12 (U1 SM TO AS Hdr Control Inlet Isol).

• IF 1AS-12 will not close AND

• IF 1AS-12 will not close AND

• IF all S/Gs faulted, THEN perform NOTE: All SGs are Faulted.

the following:

• THROTTLE feed flow to 25 GPM to each S/G.

• GO TO Step 4.

NOTE: This action will create a Red Path on FR-H.1. The CRS is expected to address FR-H.1, and immediately return to FR-P.1.

Critical Task:

Control the CA Flowrate to approximately 25 gpm per SG in order to minimize the NC Cooldown rate in ECA-2.1 or FR-P.1.

Safety Significance: Failure to control the CA flow rate to the SGs, when able to do so, leads to an unnecessary and avoidable severe or extreme challenge to the Integrity CSF. Also, failure to perform the Critical Task increases challenges to the Subcriticality Critical Safety Function which otherwise would not occur. If the action can be taken, and is not taken, this demonstrates mis-operation or incorrect operation that could unnecessarily challenge a fission product barrier (NCS).

BOP (Step 4) Check Pzr PORV isolation valves:

• Power to all Pzr PORV isolation valves -

AVAILABLE.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 64 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• At least one Pzr PORV isolation valve -

OPEN.

BOP (Step 5) Check if Pzr PORVs should be closed:

• Check LOW PRESS mode -

SELECTED.

CRS (Step 5.a RNO) GO TO Step 5.d.

BOP

• Check Pzr pressure - LESS THAN 2335 PSIG.

• Check all Pzr PORVs - CLOSED.

• IF AT ANY TIME any Pzr PORV opens NOTE: This is a Continuous due to high pressure, THEN after Action. The CRS will make pressure goes below reseat pressure, both board operators aware.

ensure PORV CLOSES or is isolated.

BOP (Step 6) Check if S/I in service using any of the following:

• Any NI Pump - ON.

OR

• 1NI-9A (NC Cold Leg Inj From NV) -

OPEN.

OR

• 1NI-10B (NC Cold Leg Inj From NV) -

OPEN.

RO/ (Step 7) Check if S/I can be terminated:

BOP

• NC subcooling based on core exit T/Cs -

GREATER THAN 50°F.

• Check RVLIS indication:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 65 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• IF all NC pumps off, THEN check NOTE: The RCPs will likely be REACTOR VESSEL LR LEVEL - OFF.

GREATER THAN 60%.

• IF at least one NC pump on, THEN NOTE: If the RCPs are ON, check "REACTOR VESSEL D/P" - the CRS will evaluate the GREATER THAN REQUIRED Table.

DELTA P FROM TABLE BELOW:

RO/ (Step 8) Reset the following:

BOP

• S/I.

• Sequencers.

• Phase A Isolation.

• Phase B Isolation.

• IF AT ANY TIME a B/O signal occurs, NOTE: This is a Continuous THEN restart S/I equipment previously Action. The CRS will make on. both board operators aware.

RO/ (Step 9) Establish VI to containment as BOP follows:

• OPEN the following valves:

RO/

• 1VI-129B (VI Supply to A Cont Ess BOP VI Hdr Outside Isol).

• 1VI-160B (VI Supply to B Cont Ess VI Hdr Outside Isol).

• 1VI-150B (Lwr Cont Non-Ess Cont Outside Isol).

• Check VI header pressure - GREATER THAN 85 PSIG.

RO/ (Step 10) Stop S/I pumps as follows:

BOP

• All but one NV pump.

• Both NI pumps.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 3 Event # 6, 7, 8 & 9 Page 66 of 67 Event

Description:

Steam Equalization Header Line Rupture/MSI fails in Auto/Manual/All MSIVs fail OPEN/1A/1B MD CA Pumps fail to start in AUTO Time Pos. Expected Actions/Behavior Comments

• Check running ND pumps suction -

ALIGNED TO FWST.

• Stop both ND pumps.

RO/ (Step 11) Isolate NV S/I flowpath as follows:

BOP

• Check the following valves - OPEN.

• 1NV-221A (U1 NV Pump Suct From FWST Isol).

• 1NV-222B (U1 NV Pump Suct From FWST Isol).

• Check the following valves - OPEN.

• 1NV-150B (U1 NV Pump Recirc Isol)

• 1NV-151A (U1 NV Pump Recirc Isol)

RO/ (Step 11.b RNO) Perform the following: NOTE: If 1NV-150B/151A are BOP CLOSED, the RNO will be performed.

• OPEN valves.

• IF both valves open, THEN GO TO Step 11.c.

RO/

• CLOSE the following valves:

BOP

• 1NI-9A (NC Cold Leg Inj From NV).

• 1NI-10B (NC Cold Leg Inj From NV).

At the discretion of the Lead Examiner terminate the exam.

UNIT 1 STATUS:

Power Level: 75% NCS [B] 1038 ppm Pzr [B]: 1038 ppm Xe: Per OAC Power History: At this power level for 3 days Core Burnup: 250 EFPDs CONTROLLING PROCEDURE: OP/1/A/6100/003 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME THE SHIFT:

• The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

• A Containment Air Release is in progress per OP/1/A/6450/17, Containment Air Release and Addition System.

The following equipment is Out-Of-Service:

• The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C.

• The TDCA Pump is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.7.5 ACTION A.

• MCB Annunciator 1AD-12, A-4, B RN PMP DISCHARGE LO PRESS, has alarmed spuriously several times over the last hour, and has currently failed OFF (IAE is investigating).

Crew Directions:

• The crew will raise power to 100% on this shift, starting with Step 3.37.10 of Enclosure 4.1 of OP/1/A/6100/003 Controlling Procedure for Unit Operation.

• The loading rate will be 2-3 MWe/minute.

• RE has recommended a 200 gallon initial dilution using Enclosure 4.3 (Dilute) of OP/1/A/6150/009 (Boron Concentration Control).

• RMWST Dissolved O2 is greater than 1000 ppb.

• Blender content is Reactor Makeup Water.

Work Control SRO/Offsite Communicator Jim Plant SRO Joe (FB)

AO's AVAILABLE Unit 1 Unit 2 Aux Bldg. John Aux Bldg. Chris Turb Bldg. Bob (FB) Turb Bldg. Mike (FB) 5th Rounds. Carol Extra(s) Bill (FB) Ed (FB) Wayne (FB) Tanya Gus (RW)

Appendix D Scenario Outline Form ES-D-1 Final (Rev_031716)

Facility: McGuire Scenario No.: 4 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 4% power (BOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1A EDG is OOS for fuel pump replacement. ACTION has been taken in accordance with Technical Specification LCO 3.8.1 ACTION B. MCB Annunciator 1AD-1, F-9, DEH/MSR SYSTEM MALFUNCT, spuriously alarmed several times during the shift, and is currently failed OFF (IAE is investigating). The crew will hold power steady until on-going maintenance is completed, however a rod height/CB adjustment will be made at the start of the shift at the request of Reactor Engineering.

Event Malf. Event Type* Event No. No. Description 1 NA R-RO Rod Height Adjustment N-BOP N-SRO 2 1 I-BOP Power Range N-41 Upper Detector failure I(TS)-SRO 3 2 C-BOP Ground Fault on 1ETA C(TS)-SRO 4 3 C-RO C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

C-SRO 5 4 C-RO 1A NCP Pump Bearing Oil Cooler Leak C-BOP C-SRO 6 5 M-RO ATWS M-BOP M-SRO 7 6 C-BOP Loss of Switchyard to Unit 1/1B EDG fails to START C-SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Scenario Outline Form ES-D-1 Final (Rev_031716)

McGuire 2016 NRC Scenario #4 The plant is at 4% power (BOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1A EDG is OOS for fuel pump replacement. ACTION has been taken in accordance with Technical Specification LCO 3.8.1 ACTION B. MCB Annunciator 1AD-1, F-9, DEH/MSR SYSTEM MALFUNCT, spuriously alarmed several times during the shift, and is currently failed OFF (IAE is investigating). The crew will hold power steady until on-going maintenance is completed, however a rod height/CB adjustment will be made at the start of the shift at the request of Reactor Engineering.

Shortly after taking the watch, the crew will dilute in accordance with Enclosure 4.3, Dilute of OP/0/A/6150/009, Boron Concentration Control, to adjust Control Bank D rod height to 132 Steps.

After this, Power Range Channel N41 Upper Detector will fail. The operator will enter AP/1/A/5500/16, Malfunction of Nuclear Instrumentation, and perform Case III, Power Range Malfunction. The operator will address Technical Specification 3.3.1, Reactor Trip Instrumentation.

Following this, a ground fault will occur on 1ETA causing the bus to de-energize. The operator will enter AP/1/A/5500/07, Loss of Electrical Power, and start the equipment on the B Train. The operator will address Technical Specification 3.8.1, AC Sources Operating, 3.8.4, DC Sources -

Operating, and 3.8.9 Distribution Systems - Operating.

Afterwards, the C-9 Interlock will fail causing the Steam Dump Valves to close. The SG PORVs will open to maintain Steam Generator pressure at setpoint. As these valves open, the 1B SG PORV Controller will fail such that the valve slowly opens. The operator will implement AP/1/A/5500/01, Steam Leak and take manual control of the 1B SG PORV.

Shortly after this, a leak will develop on the 1A NCP Upper Bearing Oil Reservoir. The operator will respond in accordance with AP/1/A/5500/08, Malfunction of NC Pump, and the operator will be required to trip the reactor, stop the 1A NCP, and go to EP/1/A/5000/E-0, Reactor Trip and/or Safety Injection.

When the operator attempts to manually trip the reactor, an ATWS will occur. The operator will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection, and then transition to EP/1/A/5000/FR-S.1, Response to Nuclear Power Generation/ATWS. During the performance of FR-S.1, the operator will continuously drive rods in manually, and successfully trip the Reactor locally.

After the crew has locally tripped the reactor but still implementing FR-S.1, a loss of the Unit 1 Switchyard will occur, and the 1B Emergency Diesel Generator will fail to start. The operator will immediately transition to EP/1/A/5000/ECA-0.0, Loss of All AC Power. The operator will restore power to 1ETB per Unit 2 6900V busses through SATB per Enclosure 14 Energizing Unit 1 4160V Bus From Unit 2 - SATA or SATB.

The scenario will terminate when one ESF Bus has been re-energized.

Appendix D Scenario Outline Form ES-D-1 Final (Rev_031716)

Critical Tasks:

Manually commence driving rods inward before completing the immediate actions of FR-S.1 (Step 2).

Safety Significance: failure to insert negative reactivity, under the postulated plant conditions, results in an unnecessary situation in which the reactor remains critical or returns to a critical condition. Performance of the critical task would move the reactor towards a subcritical condition to prevent a subsequent return to criticality. A failure to insert negative reactivity constitutes a mis-operation or incorrect crew performance which leads to incorrect reactivity control.

Dispatch an operator to perform Enclosure 2 of ECA-0.0 and a separate operator to perform of ECA-0.0 within 3 minutes and 4 minutes respectively, from the loss of NC Pump Seal Injection Flow (Station Blackout), in order to establish NC Pump Seal Injection flow from the SSF.

Safety Significance: Failure to Establish NC pump seal injection from the SSF within ten minutes as required by Enclosure 13.11, Initiate SSF NCP Seal Injection and Swap to the SSF, of PT/0/A/4600/113, Operator Time Critical Task Verification, when able to do so, constitutes mis-operation or incorrect performance which leads to degraded NC Pump Seals and may result in a Seal Failure/Small Break LOCA. Failure to perform the Critical Task may result in a needless challenge and/or degradation of a fission product barrier at the point of the intact NC Pump Seals.

Since the conditions exist to dispatch both operators, not taking this action constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers.

Dispatch by the CRS within the stated times ensure that NC Pump Seal Injection Flow can be established from the SSF within 10 minutes.

PROGRAM: McGuire Operations Training MODULE: Initial License Operator Training Class ILC 16-1 TOPIC: NRC Simulator Exam Scenario N16-1-4

REFERENCES:

1. OP/1/A/6100/010 N, Annunciator Response for Panel 1AD-13 (Rev 78)

2. Technical Specification LCO 3.4.15, RCS Leakage Detection Instrumentation (Amendment 235/217)

3. Technical Specification 3.8.1, AC Sources - Operating (Amendment 221/203)

4. OP/1/A/6150/009, Boron Concentration Control (Rev 132)

5. AP/1/A/5500/16, Malfunction of Nuclear Instrumentation (Rev 15)

6. Technical Specification 3.3.1, Reactor Trip Instrumentation (Amendment 184/166)

7. AP/1/A/5500/07, Loss of Electrical Power (Rev 36)

8. EP/1/A/5000-G-1, Generic Enclosures (Rev 38)

9. Technical Specification 3.8.4, DC Sources - Operating (Amendment 274/254)

10. Technical Specification 3.8.9, Distribution Systems - Operating (Amendment 184/166)

11. AP/1/A/5500/12, Loss of Letdown, Charging or Seal Injection (Rev 24)

12. AP/1/A/5500/01, Steam Leak (Rev 18)

13. Technical Specification 3.7.4, Steam Generator Power Operated Relief valves (SG PORVs) (Amendment 221/203)

14. Technical Specification LCO 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits (Amendment 219/201)

15. AP/1/A/5500/08, Malfunction of NC Pump (Rev 14)

16. EP/1/A/5000/E-0, Reactor Trip or Safety Injection (Rev 34)

17. EP/1/A/5000/FR-S.1, Response to Nuclear Power Generation/ATWS (Rev 15)

18. EP/1/A/5000/ECA-0.0, Loss of All AC Power (Rev 37)

Validation Time: 115 minutes Author: David Lazarony, Essential Training & Consulting, LLC Facility Review: ________________________

Rev. 031716 Scenario Event Description NRC Scenario 4 Facility: McGuire Scenario No.: 4 Op Test No.: N16-1 Examiners: Operators: (SRO)

(RO)

(BOP)

Initial Conditions: The plant is at 4% power (BOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

Turnover: The following equipment is Out-Of-Service: The VUCDT Level indication is OOS.

ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1A EDG is OOS for fuel pump replacement. ACTION has been taken in accordance with Technical Specification LCO 3.8.1 ACTION B. MCB Annunciator 1AD-1, F-9, DEH/MSR SYSTEM MALFUNCT, spuriously alarmed several times during the shift, and is currently failed OFF (IAE is investigating). The crew will hold power steady until on-going maintenance is completed, however a rod height/CB adjustment will be made at the start of the shift at the request of Reactor Engineering.

Event Malf. Event Type* Event No. No. Description 1 NA R-RO Rod Height Adjustment N-BOP N-SRO 2 1 I-BOP Power Range N-41 Upper Detector failure I(TS)-SRO 3 2 C-BOP Ground Fault on 1ETA C(TS)-SRO 4 3 C-RO C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

C-SRO 5 4 C-RO 1A NCP Pump Bearing Oil Cooler Leak C-BOP C-SRO 6 5 M-RO ATWS M-BOP M-SRO 7 6 C-BOP Loss of Switchyard to Unit 1/1B EDG fails to START C-SRO

• (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Scenario Event Description NRC Scenario 4 McGuire 2016 NRC Scenario #4 The plant is at 4% power (BOL). The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

The following equipment is Out-Of-Service: The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C. The 1A EDG is OOS for fuel pump replacement. ACTION has been taken in accordance with Technical Specification LCO 3.8.1 ACTION B. MCB Annunciator 1AD-1, F-9, DEH/MSR SYSTEM MALFUNCT, spuriously alarmed several times during the shift, and is currently failed OFF (IAE is investigating). The crew will hold power steady until on-going maintenance is completed, however a rod height/CB adjustment will be made at the start of the shift at the request of Reactor Engineering.

Shortly after taking the watch, the crew will dilute in accordance with Enclosure 4.3, Dilute of OP/0/A/6150/009, Boron Concentration Control, to adjust Control Bank D rod height to 132 Steps.

After this, Power Range Channel N41 Upper Detector will fail. The operator will enter AP/1/A/5500/16, Malfunction of Nuclear Instrumentation, and perform Case III, Power Range Malfunction. The operator will address Technical Specification 3.3.1, Reactor Trip Instrumentation.

Following this, a ground fault will occur on 1ETA causing the bus to de-energize. The operator will enter AP/1/A/5500/07, Loss of Electrical Power, and start the equipment on the B Train.

The operator will address Technical Specification 3.8.1, AC Sources Operating, 3.8.4, DC Sources - Operating, and 3.8.9 Distribution Systems - Operating.

Afterwards, the C-9 Interlock will fail causing the Steam Dump Valves to close. The SG PORVs will open to maintain Steam Generator pressure at setpoint. As these valves open, the 1B SG PORV Controller will fail such that the valve slowly opens. The operator will implement AP/1/A/5500/01, Steam Leak and take manual control of the 1B SG PORV.

Shortly after this, a leak will develop on the 1A NCP Upper Bearing Oil Reservoir. The operator will respond in accordance with AP/1/A/5500/08, Malfunction of NC Pump, and the operator will be required to trip the reactor, stop the 1A NCP, and go to EP/1/A/5000/E-0, Reactor Trip and/or Safety Injection.

When the operator attempts to manually trip the reactor, an ATWS will occur. The operator will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection, and then transition to EP/1/A/5000/FR-S.1, Response to Nuclear Power Generation/ATWS. During the performance of FR-S.1, the operator will continuously drive rods in manually, and successfully trip the Reactor locally.

After the crew has locally tripped the reactor but still implementing FR-S.1, a loss of the Unit 1 Switchyard will occur, and the 1B Emergency Diesel Generator will fail to start. The operator will immediately transition to EP/1/A/5000/ECA-0.0, Loss of All AC Power. The operator will restore power to 1ETB per Unit 2 6900V busses through SATB per Enclosure 14 Energizing Unit 1 4160V Bus From Unit 2 - SATA or SATB.

The scenario will terminate when one ESF Bus has been re-energized.

Scenario Event Description NRC Scenario 4 Critical Tasks:

Manually commence driving rods inward before completing the immediate actions of FR-S.1 (Step 2).

Safety Significance: failure to insert negative reactivity, under the postulated plant conditions, results in an unnecessary situation in which the reactor remains critical or returns to a critical condition. Performance of the critical task would move the reactor towards a subcritical condition to prevent a subsequent return to criticality. A failure to insert negative reactivity constitutes a mis-operation or incorrect crew performance which leads to incorrect reactivity control.

Dispatch an operator to perform Enclosure 2 of ECA-0.0 and a separate operator to perform Enclosure 3 of ECA-0.0 within 3 minutes and 4 minutes respectively, from the loss of NC Pump Seal Injection Flow (Station Blackout), in order to establish NC Pump Seal Injection flow from the SSF.

Safety Significance: Failure to Establish NC pump seal injection from the SSF within ten minutes as required by Enclosure 13.11, Initiate SSF NCP Seal Injection and Swap to the SSF, of PT/0/A/4600/113, Operator Time Critical Task Verification, when able to do so, constitutes mis-operation or incorrect performance which leads to degraded NC Pump Seals and may result in a Seal Failure/Small Break LOCA. Failure to perform the Critical Task may result in a needless challenge and/or degradation of a fission product barrier at the point of the intact NC Pump Seals. Since the conditions exist to dispatch both operators, not taking this action constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers. Dispatch by the CRS within the stated times ensure that NC Pump Seal Injection Flow can be established from the SSF within 10 minutes.

Scenario Event Description NRC Scenario 4 SIMULATOR OPERATOR INSTRUCTIONS Bench Mark ACTIVITY DESCRIPTION Sim. Setup Rod Step On Reset to Temp IC 238 T = 0 Malfunctions:

insert XMT-WL_1WLLT5591 = 100 (1WLL-5591, VUCDT Tank Level is OOS) insertMAL-EPQ001A = ACTIVE insertLOA-DG011 = RACKED_OUT insertLOA-DG020 = RACKED OUT insert OVR-1AD1_F09 = OFF (MCB Annunciator 1AD1/F9)

Per Lesson Plan 2016 NRC Exam Scenario 4 Insert MAL-IPE001A = TRUE (ATWS)

Insert MAL-IPE001B = TRUE (ATWS)

Insert MAL-IPE002A = TRUE (ATWS)

Insert MAL-IPE002B = TRUE (ATWS)

RUN Place Tagout/O-Stick on:

1A EDG (Tagout)

Reset all SLIMs 1WLL-5591 (O-stick)

MCB Annunciator 1AD-13, C-7 (O-stick)

MCB Annunciator 1AD-1, F-9 (O-stick)

Update Status Board, NOTE: RMWST DO = <1000 ppb.

Setup OAC Freeze.

Update Fresh Tech.

Spec. Log.

Fill out the AO's Available section of Shift Turnover Info.

Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION Prior to Crew RUN Briefing Crew Briefing

1. Assign Crew Positions based on evaluation requirements

2. Review the Shift Turnover Information with the crew.

3. Provide the crew with a Blank Copy of Enclosure 4.3 (Dilute) of OP/1/A/6150/009 (Boron Concentration Control)

4. Direct the crew to Review the Control Boards taking note of present conditions, alarms.

T-0 Begin Familiarization Period At direction of Execute Lesson Plan examiner for Simulator Scenario N16-1-4.

At direction of Event 1 Rod Height Adjustment examiner NA At direction of Event 2 Power Range N-41 Upper Detector failure examiner insert MAL-ENB013A =

LOSS At direction of Event 3 Ground Fault on 1ETA examiner insert MAL-EP008A AP-7 Actions ACTIVE insertLOA-RN087 = ON delay = 60 seconds (Start 2A RN Pump) insert 1AD11_A01= ON insertREM-RN0040A_1 = 0 (Close 1RN-40A) insert REM-KC0003A = 0 (Close 1KC-3A) insert REM-KC0230A = 0 (Close 1KC-230A)

At direction of Event 4 C-9 Failure causing failure of 1B SG PORV examiner (Manual Control avail)

Insert MAL-IPE004H =

FALSE insert XMT-SM_1SMPT55100 =

1150 Scenario Event Description NRC Scenario 4 Bench Mark ACTIVITY DESCRIPTION At direction of Event 5 1A NCP Pump Bearing Oil Cooler Leak examiner Insert MAL-NCP007AU

= TRUE Upon Attempt Event 6 ATWS to Manually Insert MAL-IPE001A = Note: These Malfunctions are inserted at T=0 Trip the Rx TRUE (ATWS)

Insert MAL-IPE001B =

TRUE (ATWS)

Insert MAL-IPE002A =

TRUE (ATWS)

Insert MAL-IPE002B =

TRUE (ATWS)

At direction of Event 7 Loss of Switchyard to Unit 1/1B EDG fails to examiner START Insert MAL-EP002 AND while in FR-EP002B = TRIP S.1 Insert MAL-DG001B =

TRUE Terminate the scenario upon direction of Lead Examiner Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 1 Page 8 of 65 Event

Description:

Rod Height Adjustment Shortly after taking the watch, the crew will dilute in accordance with Enclosure 4.3, Dilute of OP/0/A/6150/009, Boron Concentration Control, to adjust Control Bank D rod height to 132 Steps.

Booth Operator Instructions: NA Indications Available: NA Time Pos. Expected Actions/Behavior Comments NOTE: The RO will manually insert control rods.

OP/1/A/6150/009, BORON CONCENTRATION CONTROL ENCLOSURE 4.3, DILUTE BOP (Step 3.1) Evaluate all outstanding R&RS NOTE: The CRS may call that may impact performance of this WCC to address the R&Rs.

procedure. If so, Booth Instructor acknowledge as WCC, and report none.

BOP (Step 3.2) IF the lowest NCP seal leakoff is NOTE: All NCP Seal leakoffs less than 2 gpm are normal.

BOP (Step 3.3) Evaluate energizing additional pressurizer heaters per OP/1/A/6100/003 (Controlling Procedure For Unit Operation) to enhance system mixing when changing NC System boron concentration. (R.M.)

BOP (Step 3.4) Determine current blender contents and evaluate any potential Reactivity effects prior to performing this enclosure:

• Rx Makeup Water

• Blend

• Boron

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 1 Page 9 of 65 Event

Description:

Rod Height Adjustment Time Pos. Expected Actions/Behavior Comments BOP (Step 3.5) Determine amount of reactor NOTE: The BOP will add 200 makeup water needed to obtain desired gallons of MU Water.

boron concentration using McGuire Data Book, OAC, Reactor Group Guidance, or plant parameters (T-Ave. Steam Pressure, Xenon worth, etc.). (R.M.)

• Total Reactor Makeup Water:

BOP (Step 3.6) Ensure the following reset to zero:

(R.M.)

• Total Make Up Flow Counter

• Boric Acid Flow Counter BOP (Step 3.7) Set Total Make Up Flow Counter to value determined in Step 3.5.

BOP (Step 3.8) Select DILUTE on NC Sys M/U Controller.

BOP (Step 3.9) IF AT ANY TIME it is desired to adjust reactor makeup water flow, adjust Rx M/U Water Flow Control setpoint to achieve desired flowrate.

BOP (Step 3.10) IF AT ANY TIME it is desired to manually adjust reactor makeup water flow, perform the following:

• Place Rx M/U Water Flow Control in manual.

• Adjust Rx M/U Water Flow Control output to control reactor makeup water flowrate.

BOP (Step 3.11) IF AT ANY TIME it is desired to lower VCT level, perform the following:

• Monitor Letdown Pressure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 1 Page 10 of 65 Event

Description:

Rod Height Adjustment Time Pos. Expected Actions/Behavior Comments

• Select HUT on 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl).

• IF Letdown Pressure increases greater than 20 psig, notify CRS.

• AFTER desired level achieved, select AUTO on 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl).

BOP (Step 3.12) IF AT ANY TIME plant parameters require termination of dilution, perform the following:

• Place NC System Make Up to STOP.

(R.M.)

• IF 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl) placed to HUT, place to AUTO.

BOP (Step 3.13) Momentarily select START on NC System Make Up. (R.M.)

BOP (Step 3.14) Check NC System Make Up red light lit.

BOP (Step 3.15) Check 1NV-171A (U1 Boric Acid Blender to VCT Inlet Control) open.

BOP (Step 3.16) Check 1NV-252A (Rx M/U Water Supply To U1 BA Blender Cntrl) open or throttled as required.

BOP (Step 3.17) Check Rx M/U Water Pump start.

BOP (Step 3.18) Monitor Total Make Up Flow Counter. (R.M.)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 1 Page 11 of 65 Event

Description:

Rod Height Adjustment Time Pos. Expected Actions/Behavior Comments BOP (Step 3.19) HOLD until one of the following occurs:

• Amount of reactor makeup recorded per Step 3.5 added

• Reactor makeup water addition manually terminated BOP (Step 3.20) Ensure dilution terminated as follows: (R.M.)

• IF in AUTO, ensure the following off:

• 1A Rx M.U Water Pump

• 1B Rx M/U Water Pump

• Ensure the following closed:

• 1NV-171A (U1 Boric Acid Blender to VCT Inlet Control)

• 1NV-252A (Rx M/U Water Supply To U1 BA Blender Cntrl)

BOP (Step 3.21) Ensure Rx M/U Water Flow Control in auto. (R.M.)

BOP (Step 3.22) IF Rx M/U Water Flow Control adjusted per Step 3.9 OR Step 3.10 BOP (Step 3.23) Ensure 1NV-137A (U1 NC Filter Otlt to VCT 3-Way Diversion Cntrl) in AUTO.

BOP (Step 3.24) IF desired to flush blender, go to BOP (Step 3.25) Select AUTO for NC Sys M/U Controller.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 1 Page 12 of 65 Event

Description:

Rod Height Adjustment Time Pos. Expected Actions/Behavior Comments BOP (Step 3.26) Momentarily select START on NC System Make Up.

BOP (Step 3.27) Check NC System Make Up red light lit.

BOP (Step 3.28) Ensure the following reset to zero:

• Total Make Up Flow Counter

• Boric Acid Flow Counter BOP (Step 3.29) Record in Narrative Log that final blender content is Rx Makeup Water.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #2.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 13 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure After this, Power Range Channel N41 Upper Detector will fail. The operator will enter AP/1/A/5500/16, Malfunction of Nuclear Instrumentation, and perform Case III, Power Range Malfunction. The operator will address Technical Specification 3.3.1, Reactor Trip Instrumentation.

Booth Operator Instructions: insert MAL-ENB013A = LOSS Indications Available:

• MCB Annunciator, 1AD2 A1, P/R HI FLUX RATE ALERT

• MCB Annunciator, 1AD2 A2, P/R HI FLUX LO STPT ALERT

• MCB Annunciator, 1AD2 A3, P/R HI FLUX HI STPT ALERT

• MCB Annunciator, 1AD2 B3, P/R CHANNEL DEVIATION

• MCB Annunciator, 1AD2 B8, OPDT RUNBACK RUNBACK/ROD STOP ALERT

• MCB Annunciator, 1AD2 C8, P/R OVERPOWER ROD STOP

• MCB Annunciator, 1AD6 F8, OPDT PROTECTION ALERT

• N41 indicates HIGH

• PR41 AFD is off-scale HIGH Time Pos. Expected Actions/Behavior Comments NOTE: The CRS will enter to AP-16 Case III.

AP/1/A/5500/16, MALFUNCTION OF NUCLEAR INSTRUMENTATION CASE III, POWER RANGE MALFUNCTION RO (Step 1) Place control rods in manual. NOTE: The control rods are already in MANUAL.

RO/ (Step 2) Check S/G levels AT BOP PROGRAMMED LEVEL.

CRS (Step 3) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 4) Check P/R channels ONLY ONE CHANNEL FAILED.

CRS (Step 5) Secure any power increase in progress.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 14 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure Time Pos. Expected Actions/Behavior Comments RO (Step 6) Check the following interlocks IN REQUIRED STATE FOR EXISTING PLANT CONDITIONS:

• P7 Lo Power Rx Trips Blocked NOTE: Status light is LIT (Correct position).

• P8 Hi Pwr Lo Flo Rx Trip Blocked NOTE: Status light is LIT (Correct position).

• P10 Nuclear at Power. NOTE: Status light is DARK (Correct position).

BOP (Step 7) Perform the following actions at the "MISCELLANEOUS CONTROL AND INDICATION PANEL" drawer:

• Place the appropriate "ROD STOP BYPASS" switch to the failed channel position.

• Place the "POWER MISMATCH BYPASS" switch to the failed channel position.

BOP (Step 8) Perform the following actions at the "DETECTOR CURRENT COMPARATOR" drawer:

• Place the "UPPER SECTION" switch to the failed channel position.

• Check the "CHANNEL DEFEAT" light for the upper section LIT.

• Place the "LOWER SECTION" switch to the failed channel position.

• Check the "CHANNEL DEFEAT" light for the lower section LIT.

BOP (Step 9) Perform the following actions at the "COMPARATOR AND RATE" drawer:

• Place the "COMPARATOR CHANNEL DEFEAT" switch to the failed channel position.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 15 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure Time Pos. Expected Actions/Behavior Comments

• Check the "COMPARATOR DEFEAT" light LIT.

BOP (Step 10) Trip bistables of failed channel as follows:

• Remove Control Power fuses from "POWER RANGE A" drawer for failed channel.

• IF Power Range Cabinet shows NOTE: There is no sign of evidence of damage (i.e. visible smoke damage.

or flame), THEN remove Instrument Power fuses from "POWER RANGE B" drawer.

RO (Step 11) Check the following status lights for the failed channel LIT:

• "NUC OVERPOWER ROD STOP CH I(II,III,IV) BYP" (1SI19)

• "P/R HI FLUX LO STPT" (1SI2)

• "P/R HI FLUX HI STPT" (1SI2)

• "P/R HI FLUX RATE" (1SI3).

RO (Step 12) Check the following annunciator lights LIT:

• "P/R HI VOLTAGE FAILURE" (1AD2, F 3)

• "P/R HI FLUX HI STPT ALERT" (1AD2, A3)

• "P/R HI FLUX RATE ALERT" (1AD2, A 1).

RO (Step 13) Check the following status lights on 1SI18 LIT:

• "P/R LO SETPOINT TRAIN A TRIP BLOCKED"

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 16 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure Time Pos. Expected Actions/Behavior Comments

• "P/R LO SETPOINT TRAIN B TRIP BLOCKED".

RO/ (Step 13 RNO) Perform the following:

CRS

• Check "P/R HI FLUX LO STPT ALERT" alarm (1AD2, A2) LIT.

• IF alarm is dark, THEN ...

RO/ (Step 14) Check all CF control valves IN BOP AUTO.

RO (Step 15) Adjust control rods to maintain T Avg at TRef.

RO (Step 15 RNO) IF rods will not move in manual, THEN adjust turbine load to maintain TAvg at TRef.

RO (Step 16) WHEN TAvg within 1°F of TRef, NOTE: Due to plant mode of AND auto rod control desired, THEN return operation the rods will be left control rods to auto. in MANUAL.

CRS (Step 17) Instruct IAE to trip the following NOTE: The CRS may call bistables associated with failed P/R channel WCC/IAE to address the within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> of failure PER malfunction.

IP/1/A/3090/014 (Tripping Inoperable If so, Booth Instructor Protection Channels): acknowledge as WCC.

• OPDT

• OTDT.

CRS (Step 18) IF AT ANY TIME failed P/R channel is repaired prior to IAE tripping bistables, THEN..

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 17 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure Time Pos. Expected Actions/Behavior Comments NOTE: The CRS will check the Technical Specifications.

TECHNICAL SPECIFICATION 3.3.1, REACTOR TRIP SYSTEM INSTRUMENTATION CRS LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

CRS APPLICABILITY: According to Table 3.3.1-1 CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Enter the IMMEDIATELY Functions Condition with one or referenced in more Table 3.3.1-1 required for the channels channel(s).

inoperable.

NOTE: One D. One channel channel may be NOTE: The CRS will inoperable.

bypassed for up determine that Function 2.a to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for (Power Range Neutron Flux -

surveillance HIGH), 2.b (Power Range testing and setpoint Neutron Flux - LOW), 3 adjustment. (Power Range Neutron Flux D.1.1 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from Rate), 6 (Overtemperature NOTE: Only discovery of T), 7 (Overpower T), and required to be THERMAL performed when 16.d (Power Range Neutron POWER > 75%

the Power RTP Flux - P10) are affected.

Range Neutron AND The CRS will determine that Flux input to QPTR is Once per 12 Actions D.1.1 AND D.1.2, or inoperable hours thereafter D.2 are required to be taken.

Perform SR 3.2.4.2 AND D.1.2 Place 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> channel in trip.

OR D.2 Be in MODE 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> 3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 2 Page 18 of 65 Event

Description:

Power Range Channel N41 Upper Detector failure Time Pos. Expected Actions/Behavior Comments NOTE: One E. One channel channel may be CRS will determine that inoperable.

bypassed for up Actions E.1 OR E.2 are to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for required to be taken.

surveillance testing.

E.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR E.2 Be in MODE

3. 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> S.1 Verify S. One or more interlock is in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> CRS will determine that channel(s) inoperable. required state for Actions S.1 OR S.2 are existing unit required to be taken.

conditions.

OR S.2 Be in MODE

3. 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner move to Event #3.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 19 of 65 Event

Description:

Ground Fault on 1ETA Following this, a ground fault will occur on 1ETA causing the bus to de-energize. The operator will enter AP/1/A/5500/07, Loss of Electrical Power, and start the equipment on the B Train. The operator will address Technical Specification 3.8.1, AC Sources Operating, 3.8.4, DC Sources - Operating, and 3.8.9 Distribution Systems -

Operating.

Booth Operator Instructions: insert MAL-EP008A ACTIVE Insert 1AD11_A01=ON Indications Available:

• 1SI-14 Status Light for ETA LOSS/UNDERVOLTAGE PHASE X is LIT

• 1SI-14 Status Light for ETA LOSS/UNDERVOLTAGE PHASE Y is LIT

• 1SI-14 Status Light for ETA LOSS/UNDERVOLTAGE PHASE Z is LIT

• MCB Annunciator 1AD-11/A-2U ETA 600V LC TROUBLE

• MCB Annunciator 1AD-11/A-3U ETA 600V/120V TROUBLE

• 1ETA Normal Supply Breaker Green status light is LIT Time Pos. Expected Actions/Behavior Comments AP/1/A/5500/07, LOSS OF ELECTRICAL POWER CASE II, LOSS OF NORMAL POWER TO EITHER 1ETA OR 1ETB BOP (Step 1) Check affected bus(s) - Immediate Action ENERGIZED AND SEQUENCER APPLYING LOADS.

BOP (Step 1 RNO) Perform the following: Immediate Action

• IF both busses deenergized NOTE: 1ETB is energized.

• Ensure the following pumps running on energized bus:

• NV pump NOTE: The BOP will start the 1B NV Pump.

• KC pumps NOTE: The 1B1 and 1B2 KC Pumps are running.

• RN pump. NOTE: The BOP will start the 1B RN Pump.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 20 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 2) Ensure NC pump thermal barrier Immediate Action isolation valves on energized train(s) -

OPEN.

RO (Step 3) Maintain reactor power less than or equal to 100%.

BOP (Step 4) Check 1ETA and 1ETB - BOTH NOTE: ONLY 1ETB is ENERGIZED. energized.

CRS (Step 4 RNO) GO TO Step 6.

BOP (Step 6) Check - S/I HAS OCCURRED NOTE: SI has NOT occurred.

DURING THIS EVENT.

BOP (Step 6 RNO) Perform the following:

• IF both NV pumps off, NOTE: The 1B NV is running.

CRS

• IF any pump was manually started per NOTE: The 1B NV Pump was AP07 Immediate Actions, THEN GO TO manually started.

Step 8.

CRS (Step 8) Check D/Gs - OFF.

BOP (Step 9) Check ND System status:

• ND System - IN RHR MODE AT TIME NOTE: ND is NOT in RHR OF B/O. Mode.

CRS (Step 9a RNO) GO TO Step 10.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 21 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Check any RN pump - RUNNING. NOTE: The 1B RN Pump is running.

BOP (Step 11) Align KC as follows:

• Place recirc valve on operating train in AUTO:

• 1KC-54B (Train B Recirc Isol).

• Ensure KC flow remains less than 4000 GPM per operating KC pump while performing next step.

• Ensure the following valves on energized train are OPEN:

• B Train:

• OPEN 1KC-18B (Trn B Rx Bldg Non Ess Ret Isol)

• OPEN 1KC-228B (Trn B Rx Bldg Non Ess Sup Isol)

• OPEN 1KC-364B (B NC Pump Therm Bar Otlt)

• OPEN 1KC-413B (D NC Pump Therm Bar Otlt).

BOP (Step 12) Check any charging pump -

RUNNING.

BOP (Step 13) Align RN as follows:

• Check 1A RN pump - RUNNING. NOTE: The 1A RN is OFF.

BOP (Step 13a RNO) Align 1B RN as follows:

• Ensure 1RN-187B (B KC Hx Inlet Isol) is OPEN.

• THROTTLE 1RN-190B (RN To B KC Hx Control) for desired KC cooling, while maintaining the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 22 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• 1B RN pump flow - LESS THAN 14,000 GPM.

• 1B RN pump discharge pressure -

GREATER THAN 50 PSIG.

BOP

• Start all available RV pumps. NOTE: Two additional RV pumps will be started.

CRS

• GO TO Step 14.

CRS (Step 14) Notify Unit 2 RO to start 2A RN Floor Instructor: As U2 RO pump. report 2A RN Pump is running.

Booth Instructor:

insertLOA-RN087 = ON delay

= 60 seconds (Start 2A RN Pump)

BOP (Step 15) Check VCT makeup control system.

• Ensure boric acid transfer pump on energized train running.

• Ensure NC System makeup controller in auto.

• Place NC System makeup switch to start.

BOP (Step 16) Check - B/O ON 1ETA.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 23 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 17) Check B and D Pzr heater group Examiner NOTE: IF NV Pump supply breakers on vertical board - not started on B Train within CLOSED. 20 seconds of BO, loss of letdown/ Pzr heaters off will occur, and require RNO actions.

If NV Pump started within 20 seconds, move forward to Step 18.

BOP (Step 17 RNO) Perform the following:

• IF Pzr level is less than 17%, NOTE: Pzr level is most likely

> 17%.

• IF S/I has occurred, ... NOTE: SI has NOT occurred.

• Place the following Pzr heater groups in manual:

• B

• D

• Close the following Pzr heater group supply breakers:

• B

• D

• Close C Pzr heater group supply breaker.

• Return the following Pzr heater groups to auto:

• B

• D BOP (Step 18) Perform one of the following to isolate RN train crosstie:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 24 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• Dispatch operator to close 1RN-40A NOTE: The CRS will dispatch (Train A To Non Ess Hdr Isol) (aux bldg, an AO to close 1RN-40A.

716+7, GG-55 beside Unit 1 side Floor Instructor/Booth stairway to 695 elevation). Instructor: acknowledge as appropriate.

insertREM-RN0040A_1 = 0, delay = 5 min (Close 1RN-40A)

After closing valve, Booth Instructor report action taken to Control Room.

OR Caution: Closing 1RN-41B (Train B To Non Ess Hdr Isol) will isolate 1B Train RN flow to NC pumps and other non essential loads.

• Evaluate CLOSING 1RN-41B (Train B To Non Ess Hdr Isol).

CRS (Step 19) WHEN RN train crosstie is NOTE: This is a Continuous isolated, THEN 1RN-190B (RN To B KC Hx Action. The CRS will make Control) may be throttled further OPEN, both board operators aware.

while maintaining the following:

• 1B RN pump flow - LESS THAN 14,000 GPM.

• 1B RN pump discharge pressure -

GREATER THAN 50 PSIG.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 25 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments CRS (Step 20) Dispatch operator to close the NOTE: CRS will dispatch an following valves: AO to close 1KC-230A and 1KC-3A.

Floor Instructor/Booth Instructor: acknowledge as appropriate.

insert REM-KC0003A = 0, delay = 5 min (Close 1KC-3A) insert REM-KC0230A = 0, delay = 5 min (Close 1KC-230A)

After closing valves, Booth Instructor report action taken to Control Room.

BOP

• 1KC-230A (Trn A Rx Bldg Non Ess Sup Isol) (aux bldg, 750+12, JJ-55, above north end of KC HX 1A)

BOP

• 1KC-3A (Trn A Rx Bldg Non Ess Ret Isol) (aux bldg, 733+8, HH-55, north of column HH-55).

BOP (Step 21) Check 1A ND Train - WAS IN RHR MODE.

CRS (Step 21 RNO) GO TO Step 36.

BOP (Step 36) Check normal letdown - IN NOTE: If normal letdown is in SERVICE. service, the CRS will proceed to Step 37.

CRS (Step 36 RNO) IF desired to establish normal Examiner NOTE: Normal or excess letdown, THEN have any available Letdown may have isolated. If operator establish letdown PER so, the CRS may direct BOP AP/1/A/5500/12 (LOSS OF LETDOWN, to restore Letdown per AP12.

CHARGING OR SEAL INJECTION) while If so, follow actions on Page continuing with this procedure. 34, while crew continues in AP7.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 26 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 37) Check any Unit 1 6900V bus -

ENERGIZED.

CRS (Step 38) GO TO Step 45.

BOP (Step 45) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that the Unit 1 has entered AP-7.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 46) Check - S/I HAS OCCURRED DURING THIS EVENT.

CRS (Step 46 RNO) Perform the following:

• Initiate EP/1/A/5000/G-1 (Generic NOTE: The CRS may ask U2 Enclosures), Enclosure 13 (VC And VA BOP to perform Enclosure 13.

System Operation) within 30 minutes of If so, Floor Instructor B/O. acknowledge and indicate that U2 BOP is unavailable.

Examiner NOTE: While the BOP is at the Ventilation Panel performing Enclosure 13, the Lead Examiner may elect to insert Event 4 to ensure that the RO performs the response actions.

If so, Examiner following RO MOVE to Page 41.

NOTE: The CRS will likely assign the BOP to perform this action.

If so, BOP Examiner follow actions of Enclosure 13.

Other Examiners follow AP-7 Actions, Step 47, on Page 30.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 27 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments EP/1/A/5000/G-1, GENERIC ENCLOSURES ENCLOSURE 13, VC AND VA SYSTEM OPERATION Examiner NOTE: Follow the actions associated with Enclosure 13 if BOP is assigned by CRS to perform.

BOP (Step 1) Check the following HVAC annunciator alarms LIT:

• "VC/YC TRAIN A SAFETY ACTUATION" (0AD11, G1)

• "VC/YC TRAIN B SAFETY ACTUATION" (0AD11, G2).

BOP (Step 1 RNO) Depress VC/YC Safety Actuation "INITIATE" pushbutton(s).

BOP (Step 2) Check the following VC equipment ON:

• "B CONTROL ROOM AHU"

• "A CONTROL ROOM AHU"

• Train selected YC pump.

BOP (Step 2 RNO) Start equipment.

BOP (Step 3) Check train selected Control Room Area Chiller ON.

BOP (Step 3 RNO) Perform the following:

• IF the "STOP" pushbutton is depressed on selected train, THEN.

• IF train selected chiller is off, THEN start opposite train chiller as follows:

• Ensure RN pump aligned to desired chiller is running.

• Perform one of the following:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 28 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• IF desired to start A VC/YC chiller, THEN place the "VC/YC TRN A MODE SELECT" switch to "TRN A".

OR

• IF desired to start B VC/YC chiller, THEN place the "VC/YC TRN B MODE SELECT" switch to "TRN B".

• Depress "START" on chiller to be started.

• Check chiller starts within 2 minutes.

• IF neither chiller can be started, THEN..

• Stop undesired train by performing the following:

• Depress "STOP" on chiller to be stopped.

• WHEN chiller "ON" indication dark, THEN select "OFF" on associated VC/YC mode select switch.

BOP (Step 4) Check the following VC fans ON:

• "B TRAIN CR OUTSIDE AIR PRESS FAN"

• "A TRAIN CR OUTSIDE AIR PRESS FAN".

BOP (Step 4 RNO) Start equipment.

BOP (Step 5) Check "OPEN" lights on the following dampers DARK:

• CRAOAD4 (CR Area Otsd Air Fans Damper)

• CRAOAD3 (CR Area Otsd Air Fans Damper).

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 29 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 5 RNO) CLOSE dampers.

BOP (Step 6) Check the following fans OFF.

• "#1 CRA OTSD AIR FAN"

• "#2 CRA OTSD AIR FAN".

BOP (Step 7) Check the following VC equipment for train selected ON:

B Train:

• 1B SWGR AHU (1ETA Supply)

• 2B SWGR AHU (2ETA Supply)

• 1D SWGR AHU (1ETB Supply)

• 2D SWGR AHU (2ETB Supply)

• "B CR AREA AHU"

• "BATT ROOM B EXH FAN" BOP (Step 8) Check the following AHUs ON:

• 1B NS AHU

• 1B ND AHU

• 1B KF AHU BOP (Step 9) Ensure VA filter units remain in filter mode as follows:

• Place the following switches in "TEST":

• "1B VA FILTER UNITS TEST"

• "1A VA FILTER UNITS TEST"

• Check the following closed:

• 1ABFD3 (1B VA Filter Exh Bypass Damper)

• 1ABFD3 (1A VA Filter Exh Bypass Damper)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 30 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 10) Restart the following EMF Sample Blowers as required:

• EMF 41 (Aux Bldg Ventilation)

• EMF43A (Control Room Air Intake Loc A)

• 1EMF35, 36, 37 (Unit Vent Particulate, Gas, Iodine)

• 1EMF42 (Fuel Bldg Ventilation)

• EMF43B (Control Room Air Intake Loc B).

BOP (Step 11) WHEN time and manpower allow, NOTE: The BOP will contact THEN dispatch operator to ensure VA or dispatch an AO to continue System remains in proper alignment as the local actions.

follows: If so, Floor Instructor/Booth Instructor acknowledge as AO.

AP/1/A/5500/07, LOSS OF ELECTRICAL POWER CASE II, LOSS OF NORMAL POWER TO EITHER 1ETA OR 1ETB Examiner NOTE: Examiners following the CRS/RO continue HERE.

CRS (Step 47) Have available licensed operator NOTE: The CRS may ask initiate Enclosure 7 (DC Bus Alignment) WCCS for an available within 30 minutes of B/O. Licensed Operator to perform Enclosure 7.

If so, Floor Instructor acknowledge as WCCS, and perform.

BOP (Step 48) Check D/G on bus that was NOTE: The 1A D/G is OOS.

blacked out - ON.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 31 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 48 RNO) Perform the following on affected D/G:

• IF D/G was stopped using emergency NOTE: The 1A D/G is OOS.

stop pushbutton,

• IF bus known to be locked out, THEN GO TO Step 50.

NOTE: The CRS will NOT stop to look at Tech Specs while in AP-07. Tech Spec review should occur after completion of scenario. Therefore, at the discretion of the lead examiner, move to Event 4 TECHNICAL SPECIFICATION 3.8.1, AC SOURCES - OPERATING CRS 3.8.1 AC Source - Operating CRS LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

• Two qualified circuits between the offsite transmission network and the Onsite Essential Auxiliary Power System AND

• Two diesel generators (DGs) capable of supplying the Onsite Essential Auxiliary Power Systems AND

• The automatic load sequencers for Train A and Train B shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CRS CONDITION REQUIRED COMPLETION ACTION TIME

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 32 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments A. One offsite A.1 Perform SR 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> NOTE: The CRS will circuit 3.8.1.1 for AND determine that one offsite line inoperable. OPERABLE and one DG are inoperable offsite Once per 8 circuit. hours thereafter because neither are capable of AND supplying the Emergency Bus A.2 Declare 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from (TS Basis pB3.8.1-2).

required discovery of no Consequently, ACTION A.1, features offsite power to one train A.2 and A.3 must be entered.

with no offsite concurrent with Additionally, The CRS will inoperability of power redundant determine that ACTION B.1, available B.2, either B.3.1 or B.3.2 and inoperable required with its feature(s). B.4 must be entered.

redundant required feature(s) is inoperable.

AND 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> A.3 Restore AND offsite circuit 6 days from to failure to meet OPERABLE LCO.

status.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 33 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments B. One DG B.1 Perform SR 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. 3.8.1.1 for AND OPERABLE offsite Once per 8 circuit. hours thereafter.

AND B.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from features discovery of supported Condition B by the concurrent with inoperable inoperability of DG redundant inoperable required when its feature(s).

required redundant feature(s) is inoperable.

AND B.3.1 Determine 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> inoperable DG is not inoperable due to common cause failure.

OR B.3.2 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Perform SR 3.8.1.2 for OPERABLE DG. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND AND B.4 Restore DG 6 days from to failure to meet OPERABLE LCO.

status TECHNICAL SPECIFICATION 3.8.4, DC SOURCES - OPERATING CRS LCO 3.8.4 The four channels of DC sources shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 34 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED COMPLETION NOTE: The CRS will ACTION TIME determine that the AC Battery A.. One A.1 Restore 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Chargers are inoperable. (TS channel of channel of Basis pB3.8.4-3).

DC source DC source to inoperable. OPERABLE Consequently, ACTION A.1, or status. A.2.1 and A.2.2 must be OR 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> entered.

A.2.1 Verify associated bus tie breakers are closed between DC channels.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND A.2.2 Restore channel of DC source to OPERABLE status.

TECHNICAL SPECIFICATION 3.8.9, DISTRIBUTION SYSTEMS - OPERATING CRS LCO 3.8.9 Train A and Train B AC, four channels of DC, and four AC vital buses electrical power distribution subsystems shall be OPERABLE.

CRS APPLICABILITY: MODES 1, 2, 3, and 4.

CRS ACTIONS CONDITION REQUIRED COMPLETION ACTION TIME NOTE: The CRS will A. One or more A.1 Restore AC 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> determine that 1ETA is AC electrical electrical AND power power inoperable.

16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> from distribution distribution discovery of Consequently, ACTION A.1 subsystem(s) subsystem(s) must be entered.

inoperable. to failure to meet OPERABLE LCO.

status.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 35 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments NOTE: If normal letdown is isolated, the CRS may direct the BOP to perform AP-12, while the remainder of the crew continues with AP-7.

If so, BOP Examiner follow the AP-12 steps below.

AP/1/A/5500/12, LOSS OF LETDOWN, CHARGING OR SEAL INJECTION BOP (Step 1) Check if charging is aligned to Regenerative Hx as follows:

• Charging flow - GREATER THAN 20 NOTE: The BOP may take GPM MANUAL control of 1NV-238 to control Charging flow.

• 1NV-241 (U1 Seal Water Inj Flow Control) - THROTTLED OPEN

• 1NV-244A (U1 Charging Hdr Cont Outside Isol) - OPEN

• 1NV-245B (U1 Charging Hdr Cont Outside Isol) - OPEN.

BOP (Step 2) Check Pzr Level - LESS THAN 96%.

BOP (Step 3) Stop any power or temperature changes in progress.

BOP (Step 4) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that AP-12 has been entered.

If so, Floor Instructor acknowledge as U2 RO.

BOP (Step 5) IF this AP entered due to loss of letdown only, THEN GO TO Step 37.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 36 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments BOP (Step 37) Ensure the following valves are CLOSED:

• 1NV-458A (U1 75 GPM L/D Orifice Otlt Cont Isol)

• 1NV-457A (U1 45 GPM L/D Orifice Otlt Cont Isol) 1NV-35A (U1 Variable L/D Orifice Otlt Cont Isol).

BOP (Step 38) Ensure NC System makeup controller is in AUTO.

BOP (Step 39) Ensure charging flow going down NOTE: The BOP may take to maintain Pzr at program level. MANUAL control of 1NV-238 to control Charging flow.

BOP (Step 40) Check LETDN RELIEF HI TEMP alarm (1AD-7, I-4) - HAS REMAINED DARK.

BOP (Step 41) Check 1NV-21A (U1 NV Supply to U1 Aux PZR Spray Isol) - CLOSED.

BOP (Step 42) Operate Pzr heaters as follows:

• Check A, B, and D Pzr heater group supply breakers on vertical board -

CLOSED.

• Check normal Pzr spray - AVAILABLE.

BOP Place the following Pzr heater groups in manual and ON to maximize spray flow:

• A

• B

• D BOP (Step 43) Check the following valves - NOTE: If normal Letdown has OPEN: been isolated, it is likely that these valves are CLOSED.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 37 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• 1NV-1A (U1 NC L/D Isol To Regenerative Hx)

• 1NV-2A (U1 NC L/D Isol To Regenerative Hx).

BOP (Step 43 RNO) Perform the following:

• IF normal letdown known to be NOTE: If Pzr level has been unavailable, . restored, Normal Letdown is available.

• Prior to opening 1NV-1A or 1NV-2A in subsequent step, attempt to evacuate all personnel from lower containment (potential water hammer event).

• Observe Caution prior to Step 45 and GO TO Step 45.

BOP (Caution prior to Step 45) Establishing normal letdown without local pressurization may cause some water hammer.

BOP Determine if conditions allow immediate restoration of normal letdown as follows:

• Check both 1NV-1A (U1 NC L/D Isol To Regenerative Hx) and 1NV-2A (U1 NC L/D Isol To Regenerative Hx) - OPEN WITHIN THE LAST 60 MINUTES.

• Check orifice isolation valves - AUTO CLOSED BOP

• Determine exact time each NV letdown valve went closed on the OAC by performing the following:

o Enter turn on code "ARCHIVE".

o Ensure OAC automatically populates "START TIME" and STOP TIME" (previous hour).

o Enter group name "AP12".

o Click "F3 - VIEW PID".

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 38 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• Check if orifice isolation valves reached fully closed - PRIOR TO 1NV-1A OR 1NV-2A CLOSING.

BOP (Step 46) GO TO Step 49.

BOP (Step 49) Establish normal letdown as follows:

• Ensure 1NV-459 (U1 Variable L/D Orifice Outlet Flow Cntrl) is CLOSED.

• Place 1NV-124 (U1 Letdown Press Control) in manual with output between 40-45% OPEN.

• Check OAC - IN SERVICE.

• Check valve position on OAC for 1NV-124 - INDICATING THROTTLED.

• Check the following valves - OPEN: NOTE: Both valves are expected to be CLOSED.

• 1NV-1A (U1 NC L/D Isol To Regenerative Hx)

• 1NV-2A (U1 NC L/D Isol To Regenerative Hs).

• IF time allows, THEN wait until all personnel are evacuated from lower containment.

• Establish cooling to Regenerative Hx by performing the following concurrently:

BOP

• Establish at least 65 GPM charging NOTE: The BOP will take flow by THROTTLING OPEN 1NV- MANUAL control of 1NV-238 238 (U1 Charging Hdr Control) or to control Charging flow.

raising PD pump speed.

• THROTTLE 1 NV-241 (U1 Seal Water Inj Flow Control) to establish approximately 8 GPM seal injection flow to each NC pump.

BOP

• OPEN letdown line isolation valves as follows:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 39 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• OPEN 1NV-7B (U1 Letdown Cont Outside Isol).

• OPEN 1NV-1A (U1 NC L/D Isol To Regenerative Hx).

• OPEN 1NV-2A (U1 NC L/D Isol To Regenerative Hx).

• OPEN 1NV-35A (U1 Variable L/D Orifice Otlt Cont Isol).

BOP

• Slowly THROTTLE OPEN 1NV-459 (U1 Variable L/D Orifice Outlet Flow Cntrl) until one of the following conditions met:

• Letdown flow - GOES UP OR

• 1NV-459 valve demand - AT 60%.

BOP

• Do not continue until one of the above conditions is met.

BOP

• Check letdown flow - HAS GONE UP.

BOP

• THROTTLE CLOSED 1NV-124 (U1Letdown Press Control) until one of the following conditions is met:

• Letdown pressure is between 250-350 PSIG.

OR

• 1NV-124 is 10-20% OPEN.

BOP

• Adjust charging flow as needed in subsequent steps while maintaining the following:

• NC pump seal injection flow greater than 6 GPM

• Regenerative Hx letdown temperature less than 380°F.

BOP

• Establish desired letdown flow (normally greater than or equal to 75 GPM) by completing the following concurrently:

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 40 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• Slowly THROTTLE OPEN 1NV-459 (U1 Variable L/D Orifice Outlet Flow Orifice Outlet Flow Cntrl) to achieve desired letdown flow.

• As letdown pressure rises, THROTTLE 1NV-124 (U1 Letdown Press Control) to maintain letdown pressure between 250 PSIG and 350 PSIG.

BOP

• Do not continue until desired flow rate is established.

BOP

• Check setpoint for 1NV-124 (U1 Letdown Press Control) - SET BETWEEN 348-352 PSIG.

BOP

• THROTTLE 1NV-124 to obtain letdown pressure between 348-352 PSIG.

BOP

• Place 1NV-124 in auto.

BOP

• Ensure letdown pressure controlling between 348-352 PSIG.

BOP

• IF more letdown flow required.. NOTE: Additional Letdown flow will NOT be required.

BOP

• Adjust charging flow as desired while maintaining the following:

• NC pump seal injection flow greater than 6 GPM

• Regenerative Hx letdown temperature less than 380°F

• Pzr level at program level.

BOP

• Check 1A or 1B NV pump - SUPPLYING NOTE: The 1B NV Pump is NORMAL CHARGING. running.

BOP

• WHEN Pzr level matches program level, THEN perform the following:

• Place 1NV-238 (U1 Charging Hdr Control) in auto.

• On DCS workstation, place "PZR LEVEL MASTER" in auto.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 3 Page 41 of 65 Event

Description:

Ground Fault on 1ETA Time Pos. Expected Actions/Behavior Comments

• THROTTLE 1NV-241 (U1 Seal Water Inj Flow Control) as necessary to maintain approximately 8 GPM seal injection flow to each NC pump.

BOP

• Notify Chemistry that normal letdown is NOTE: The BOP may contact in service. WCCS/Chemistry for this notification.

If so, Booth Instructor acknowledge as WCCS/Chemistry.

BOP

• Check position of 1NV-127A (U1 L/D Hx 3-Way Temp Control) - ALIGNED TO "DEMIN".

BOP

• Operate Pzr heaters as desired.

BOP

• WHEN time allows, THEN notify NOTE: The BOP may contact engineering to document the following WCCS/RE for this notification.

transients: If so, Booth Instructor acknowledge as WCCS/RE.

• Letdown isolation

• Potential charging nozzle transient

• IF NV Aux Spray was in service, THEN spray nozzle transient.

BOP

• Check excess letdown - ISOLATED.

BOP

• RETURN TO procedure and step in NOTE: The BOP will inform effect. the CRS that Normal Letdown has been restored.

At the discretion of the Lead Examiner move to Event #4.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 4 Page 42 of 65 Event

Description:

C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

Afterwards, the C-9 Interlock will fail causing the Steam Dump Valves to close. The SG PORVs will open to maintain Steam Generator pressure at setpoint. As these valves open, the 1B SG PORV Controller will fail such that the valve slowly opens. The operator will implement AP/1/A/5500/01, Steam Leak and take manual control of the 1B SG PORV.

Booth Operator Instructions: Insert MAL-IPE004H = True insert XMT-SM_1SMPT5510 =

1150 Indications Available:

• OAC Alarm: 1SV1 1B SM PORV OPEN

• 1SI-18 C-9 COND AVAILABLE FOR STM DUMP

• 1SV-13AB Red status light is LIT Time Pos. Expected Actions/Behavior Comments NOTE: It is likely that the operator will take actions to close the 1B SG PORV prior to being directed by the CRS.

(Step 13)

AP/1/A/5500/01, STEAM LEAK RO/ (Step 1) Monitor Foldout page.

BOP RO (Step 2) Reduce turbine load to maintain the NOTE: The Turbine is NOT following: operating.

• Excore NIs - LESS THAN OR EQUAL TO 100%.

• NC Loop D/Ts - LESS THAN 60°F D/T

• T-Avg - AT T-REF.

CRS (Step 3) Check containment entry - IN NOTE: A Containment Entry is PROGRESS. NOT in progress.

CRS (Step 3 RNO) GO TO Step 5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 4 Page 43 of 65 Event

Description:

C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Check Pzr pressure prior to event -

GREATER THAN P-11 (1955 PSIG).

BOP (Step 6) Check Pzr level - STABLE OR NOTE: Pzr level will most GOING UP. likely be stable.

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure Pzr level cannot be maintained Action. The CRS will make stable, THEN RETURN TO Step 6. both board operators aware.

CRS (Step 8) GO TO Step 12.

CRS (Step 12) Announce occurrence on paging NOTE: CRS may ask U2 RO system. to make Plant Announcement that the Unit 1 has entered AP-1.

If so, Floor Instructor acknowledge as U2 RO.

RO (Step 13) Identify and isolate leak on Unit 1 as follows:

• (Step 13a) Check SM PORVs - NOTE: The SG PORVs may CLOSED. be Open.

RO (Step 13a RNO) IF S/G pressure is less than 1092 PSIG, THEN

• CLOSE affected S/G SM PORV manual NOTE: Closing the Manual loader. Loader will CLOSE the valve.

• IF SM PORV is still open, THEN NOTE: The 1B SG PORV is CLOSED.

RO * (Step 13.b) Check condenser dump valves - CLOSED.

BOP * (Step 13.c) Check containment conditions - NORMAL:

• Containment temperature

• Containment pressure

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 4 Page 44 of 65 Event

Description:

C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

Time Pos. Expected Actions/Behavior Comments

• Containment humidity

• Containment floor and equipment sump level.

RO / * (Step 13.d) Check TD CA pump - OFF.

BOP BOP * (Step 13.e) Check valves on STEAM LINE DRAIN VALVES board (1MC-9) -

CLOSED.

CRS * (Step 13.f) Check opposite Unit (Unit 2) NOTE: CRS may ask U2 RO STEAM HEADER PRESSURE - for AS Header pressure.

GREATER THAN 200 PSIG. If so, Floor Instructor report as U2 RO that U2 Steam Header pressure is 1000 psig.

• (Step 13.g) Dispatch operator to check NOTE: The CRS may dispatch for leaks. an AO to look for leaks.

If so, Floor Instructor:

acknowledge.

Booth Instructor: Report back in 3-5 minutes that there are no leaks.

NOTE: The CRS may NOT dispatch AOs to look for leaks because it is understood that the SM PORV opening was the reason that AP-1 was entered.

BOP (Step 14) Check UST level - STABLE OR GOING UP.

CRS (Step 15) Evaluate unit shutdown as follows:

• Check unit status - IN MODE 1 OR 2.

• Determine if unit shutdown or load NOTE: CRS may call reduction is warranted based on the WCC/Management to address following criteria: the startup.

If so, Booth Instructor acknowledge as WCC. If needed, as Station Management direct that the crew continue to hold at this power level.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 4 Page 45 of 65 Event

Description:

C-9 Failure causing failure of 1B SG PORV (Manual Control avail)

Time Pos. Expected Actions/Behavior Comments

• Size of leak

• Location of leak

• Rate of depletion of secondary inventory

• IF steam is leaking from a secondary heater relief OR MSR relief valve THEN

• IF turbine trip will isolate steam leak (such as feedwater heater leak or MSR leak THEN

• Check unit shutdown or load reduction - NOTE: Shutdown/Load REQUIRED. Reduction will NOT be required.

CRS (Step 15.c RNO) Perform the following:

• Maintain present plant conditions until leak can be isolated or repaired.

• Exit this procedure.

NOTE: The CRS will likely conduct a Focus Brief.

At the discretion of the Lead Examiner, move to Event #5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 5 Page 46 of 65 Event

Description:

1A NCP Pump Bearing Oil Cooler Leak Shortly after this, a leak will develop on the 1A NCP Upper Bearing Oil Reservoir. The operator will respond in accordance with AP/1/A/5500/08, Malfunction of NC Pump, and the operator will be required to trip the reactor, stop the 1A NCP, and go to EP/1/A/5000/E-0, Reactor Trip and/or Safety Injection.

Booth Operator Instructions: insert MAL-NCP007AU = TRUE Indications Available:

• OAC Alarm M1A1500 1A NC PUMP UPPER OIL RESERVOIR LEVEL Time Pos. Expected Actions/Behavior Comments OAC ALARM M1A1500 1A NC PUMP UPPER OIL RESERVOIR LEVEL CRS (LO-LO Step 1) Go To AP/1/A/5500/08, Malfunction of NC Pump.

NOTE: The CRS will enter AP-08.

AP/1/A/5500/08, MALFUNCTION OF NC PUMP CASE II, NC PUMP MOTOR BEARING MALFUNCTION BOP (Step 1) Check abnormal NC pump NOTE: The BOP will use parameter - KNOWN TO BE VALID. Enclosure 1 to determine that the parameter is known to be valid. (NOT scripted)

BOP (Step 2) Check NC pump parameters within operating limits:

• All NC pump stator winding temperatures

- LESS THAN 311°F.

• All NC pump motor bearing temperatures

- LESS THAN 195°F.

• All NC pump oil reservoir level computer NOTE: The oil reservoir level points - INDICATING BETWEEN (-)1.25 is NOT within band.

AND (+)1.25.

BOP (Step 2 RNO) IF trip criteria valid, THEN GO TO Step 5.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 5 Page 47 of 65 Event

Description:

1A NCP Pump Bearing Oil Cooler Leak Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Stop affected NC pump as follows:

BOP

• IF A or B NC pump is the affected pump, NOTE: The 1A NC Pump is THEN CLOSE associated spray valve: the affected NC Pump.

• 1NC-27C (A NC Loop PZR Spray Control).

• Check unit status - IN MODE 1 OR 2.

RO

• Trip reactor.

BOP

• WHEN reactor power less than 5%, NOTE: The plant power is THEN stop affected NC pump. currently < 5%.

CRS

• GO TO EP/1/A/5000/E-0 (Reactor Trip or Safety Injection).

At the discretion of the Lead Examiner, move to Events #6-7.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 48 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START When the operator attempts to manually trip the reactor, an ATWS will occur. The operator will enter EP/1/A/5000/E-0, Reactor Trip or Safety Injection, and then transition to EP/1/A/5000/FR-S.1, Response to Nuclear Power Generation/ATWS.

During the performance of FR-S.1, the operator will continuously drive rods in manually, and successfully trip the Reactor locally. After the crew has locally tripped the reactor but still implementing FR-S.1, a loss of the Unit 1 Switchyard will occur, and the 1B Emergency Diesel Generator will fail to start. The operator will immediately transition to EP/1/A/5000/ECA-0.0, Loss of All AC Power. The operator will restore power to 1ETB per Unit 2 6900V busses through SATB per Enclosure 14 Energizing Unit 1 4160V Bus From Unit 2 - SATA or SATB. The scenario will terminate when one ESF Bus has been re-energized.

Booth Operator Instructions: Insert MAL-IPE001A = TRUE (ATWS)

Insert MAL-IPE001B = TRUE (ATWS)

Insert MAL-IPE002A = TRUE (ATWS)

Insert MAL-IPE002B = TRUE (ATWS)

NOTE: These malfunctions are entered at T=0 Indications Available:

• MCB Annunciator 1FO-1, MANUAL RX TRIP, is LIT.

• Both Rx Trip Breakers are CLOSED (red status lights are LIT)

• DRPI indicates that all Control Rods are NOT on the bottom of the core.

Time Pos. Expected Actions/Behavior Comments EP/1/A/5000/E-0, REACTOR TRIP OR SAFETY INJECTION RO/ (Step 1) Monitor Foldout page. NOTE: Crew will carry out BOP Immediate Actions of E-0, prior to the CRS addressing the EP.

RO (Step 2) Check Reactor Trip: Immediate Action

• All rod bottom lights - LIT

• Reactor trip and bypass breakers -

OPEN

• I/R amps - GOING DOWN.

RO (Step 2 RNO) Perform the following: Immediate Action

• Trip reactor.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 49 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments RO

• IF reactor will not trip, THEN perform the NOTE: The CRS may following: dispatch an AO to locally trip the reactor.

If so, Booth Instructor After 2 Minutes insert:

LOA-IPE011=TRIP (Rx Trip Bkr 1A)

LOA-IPE012=TRIP (Rx Trip Bkr 1B)

As an Alternate Insert:

LOA-IRE001A = OPEN (MG Set 1A Gen Output Bkr)

LOA-IRE002A = OPEN (MG Set 1B Gen Output Bkr)

• Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).

CRS

• GO TO EP/1/A/5000/FR-S.1 NOTE: The CRS will (Response To Nuclear Power transition to FR-S.1.

Generation/ATWS).

EP/1/A/5000/FR-S.1, RESPONSE TO NUCLEAR POWER GENERATION/ATWS RO (Step 1) Check Reactor Trip: Immediate Action

• All rod bottom lights - LIT

• Reactor trip and bypass breakers -

OPEN

• I/R amps - GOING DOWN.

RO (Step 1 RNO) Perform the following: Immediate Action

• Trip the reactor.

• IF reactor will not trip, THEN manually NOTE: The RO will insert rods. manually drive Rods inward.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 50 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments Critical Task:

Manually commence driving rods inward before completing the immediate actions of FR-S.1 (Step 2).

Safety Significance: failure to insert negative reactivity, under the postulated plant conditions, results in an unnecessary situation in which the reactor remains critical or returns to a critical condition. Performance of the critical task would move the reactor towards a subcritical condition to prevent a subsequent return to criticality. A failure to insert negative reactivity constitutes a mis-operation or incorrect crew performance which leads to incorrect reactivity control.

BOP (Step 2) Check Turbine Trip: Immediate Action

• All throttle valves - CLOSED.

RO/ (Step 3) Monitor Foldout page.

BOP Cold Leg Recirc Switchover Criteria CA Suction Sources Position Criteria for 1NV150B and 1NV 151A (U1 NV Pump Recirc Isol)

BOP (Step 4) Check proper CA pump status:

• MD CA pumps - ON. NOTE: The 1A MDCA Pump does not have power.

BOP (Step 4.a RNO) Start pumps. NOTE: The BOP will NOT attempt to start the 1A MD CA Pump.

BOP

• Check N/R Level in at least 3 S/Gs -

GREATER THAN 17%.

BOP (Step 5) Initiate emergency boration of NC System as follows:

• Ensure one NV pump - ON

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 51 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments

• Align boration flowpath as follows:

• Open 1NV-265B (Boric Acid To NV Pumps).

• Start both boric acid transfer pumps. NOTE: Only the 1B Boric Acid Pump will start.

• Check emergency boration flow -

GREATER THAN 30 GPM.

• Check if NV flowpath aligned to NC System:

• 1NV-244A (Charging Line Cont Outside Isol) - OPEN.

• 1NV-245B (Charging Line Cont Outside Isol) - OPEN.

• Ensure charging flow is greater than emergency Boration flow.

• Check Pzr pressure - LESS THAN 2335 PSIG.

BOP (Step 6) Close the following VQ valves:

• CLOSE 1VQ-1A (U1 Cont Air Release Inside Isol)

• CLOSE 1VQ-6A (U1 Cont Air Addition Inside Isol)

• CLOSE 1VQ-2B (U1 Cont Air Release Outside Isol)

• CLOSE 1VQ-5B (U1 Cont Air Addition Outside Isol)

BOP (Step 7) IF AT ANY TIME while in this NOTE: This is a Continuous procedure an S/I signal exists or occurs, Action. The CRS will make THEN perform the following: both board operators aware.

• Have another Licensed Operator check S/I equipment PER Enclosure 3 (Subsequent S/I Actions).

CRS

• Continue with this procedure.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 52 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments RO (Step 8) Check if the following trips have occurred:

• Reactor trip.

Booth Operator Instructions: Insert MAL-EP002 AND EP002B = TRIP Insert MAL-DG001B = TRUE Indications Available:

• Control Room lights dim.

• 1B EDG does NOT start as required.

NOTE: The CRS will transition to ECA-0.0.

EP/1/A/5000/ECA-0.0, LOSS OF ALL AC POWER NOTE: Crew will carry out Immediate Actions of ECA-0.0, prior to the CRS addressing the EP.

Examiner NOTE: Record the Time of the Loss of All AC Power.

Critical Task 2 Time Start:

CRS (Step 1) CSF Status trees should be monitored for information only. EPs referenced by them should not be implemented.

RO (Step 2) Check Reactor Trip: Immediate Action

• All rod bottom lights - LIT NOTE: DRPI is NOT available on the LOOP.

• Reactor trip and bypass breakers -

OPEN

• I/R amps - GOING DOWN.

RO (Step 3) Check Turbine Trip: Immediate Action

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 53 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments

• All throttle valves - CLOSED.

CRS (Step 4) Establish NC pump seal injection from the SSF as follows:

CRS

• Immediately dispatch operator to SSF to NOTE: The CRS will perform the following: dispatch an AO to complete Enclosure 2.

Booth Instructor acknowledge as appropriate, after seven minutes insert ECA-0.0 (Enclosure 2 SSF Actions) and report that Enclosure 2 is complete.

• Obtain Brown Folder at SSF and Examiner NOTE: Record complete Enclosure 2 (Unit 1 SSF - ECA- the Time of the Dispatch of 0.0 Actions). the Operator to perform Enclosure 2.

Critical Task 2 Time 1 Stop:

(3 Minutes)

CRS

• Dispatch operator to 1ETA room as follows:

• Check if operator will enter aux bldg

- FROM MG SET ROOM.

• Give operator dosimeter from Unit 2 SRO desk.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 54 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS

• Dispatch operator to perform NOTE: The CRS will Enclosure 3 (Unit 1 ETA And ETB dispatch an AO to complete Rooms - ECA-0.0 Actions). Enclosure 3.

If so, Booth Instructor acknowledge as appropriate.

Booth Instructor: wait 2 minutes, then insert ECA-0.0 ENCLOSURE 3, then report that Enclosure 3 is complete.

Examiner NOTE: Record the Time of the Dispatch of the Operator to perform Enclosure 2.

Critical Task 2 Time 2 Stop:

(4 Minutes)

Critical Task:

Dispatch an operator to perform Enclosure 2 of ECA-0.0 and a separate operator to perform Enclosure 3 of ECA-0.0 within 3 minutes and 4 minutes respectively, from the loss of NC Pump Seal Injection Flow (Station Blackout), in order to establish NC Pump Seal Injection flow from the SSF.

Safety Significance: Failure to Establish NC pump seal injection from the SSF within ten minutes as required by Enclosure 13.11, Initiate SSF NCP Seal Injection and Swap to the SSF, of PT/0/A/4600/113, Operator Time Critical Task Verification, when able to do so, constitutes mis-operation or incorrect performance which leads to degraded NC Pump Seals and may result in a Seal Failure/Small Break LOCA.

Failure to perform the Critical Task may result in a needless challenge and/or degradation of a fission product barrier at the point of the intact NC Pump Seals.

Since the conditions exist to dispatch both operators, not taking this action constitutes incorrect performance that leads to degradation of the RCS and/or fuel cladding fission product barriers. Dispatch by the CRS within the stated times ensure that NC Pump Seal Injection Flow can be established from the SSF within 10 minutes.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 55 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS

• Use any of the following to notify security NOTE: The CRS will to immediately dispatch officer with key dispatch a Security Officer to SSF to ensure operator can access to the SSF.

SSF: Booth Instructor:

Acknowledge as Security.

• Security ringdown phone (located on Unit 2 SRO desk)

• 2688

• 4900. Floor Instructor: If asked, U2 does NOT have normal power, and both DGs are running.

RO/ (Step 5) Monitor Foldout Page BOP Alternate Low Pressure Feedwater (applies after Step 8 in body of the procedure)

Loss of Vital Instrumentation or Control Power Low Decay Heat Temperature Control CA Suction Sources (applies after Step 11 in body of the procedure)

BOP (Step 6) Check NC System - ISOLATED:

BOP

• Check the following letdown orifice isolation valves - CLOSED.

• 1NV-458A (U1 75 GPM L/D Orifice Outlet Cont Isol).

• 1NV-457A (U1 45 GPM L/D Orifice Outlet Cont Isol).

• 1NV-35A (U1 Variable L/D Orifice Outlet Cont Isol).

BOP

• CLOSE the following valves:

• 1NV-1A (U1 NC L/D Isol To Regenerative Hx)

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 56 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments

• 1NV-2A (U1 NC L/D Isol To Regenerative Hx).

BOP

• Check Pzr PORVs - CLOSED.

BOP

• Check the following excess letdown isolation valves - CLOSED:

• 1NV-24B (1C NC Loop To Excess L/D Hx Isol)

• 1NV-25B (1C NC Loop To Excess L/D Hx Isol).

BOP

• Check 1NV-121 (U1 ND Letdown Control) - CLOSED.

RO (Step 7) Check total CA flow - GREATER NOTE: it is likely that the THAN 450 GPM. BOP has throttled back CA flow.

BOP (Step 8) Try to restore power to 1ETA or 1ETB as follows:

• Place both trains D/G mode select switches to control room.

• Perform the following for any D/G(s) that are off:

• Depress, then release, RESET on sequencer.

• Start D/G.

• Check both D/Gs - RUNNING.

BOP (Step 8.c RNO) Perform the following:

• Initiate S/I

• Notify Unit 2 to immediately ensure flow NOTE: The CRS will notify path for 2B RN pump PER Enclosure 5 U2.

(Unit 2 Actions). Floor Instructor:

Acknowledge as U2 RO.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 57 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS

• IF at least one D/G starts, THEN NOTE: The 1A D/G is OOS, and the 1B D/G will NOT start.

CRS

• GO TO Step 9 CRS (Step 9) Ensure the following have been NOTE: The CRS may ask implemented: OSM to address.

If so, Floor Instructor acknowledge as OSM.

• RP/0/A/5700/000 (Classification of Emergency)

• RP/0/A/5700/010 (NRC Immediate Notification Requirements).

RO/ (Step 10) Control intact S/G levels as follows:

BOP

• Check N/R level in any intact S/G -

GREATER THAN 11% (32% ACC).

• THROTTLE CA control valves to maintain all intact S/G N/R levels between 11% (32% ACC) and 50%.

• IF AT ANY TIME CA flow control is lost, NOTE: This is a Continuous THEN perform RNO for Step 10.b Action. The CRS will make both board operators aware.

CRS (Step 11) Monitor CA Storage Tank (water tower) level and ensure CA suction source as follows:

• Check if external event that has the potential to damage CA Storage Tank (water tower) (such as seismic or tornado) HAS OCCURRED.

CRS (Step 11.a RNO) Observe Note prior to Step 11.c and GO TO Step 11.c.

BOP (Step 11.c-e) Monitor CA Storage Tank (water tower) level using available Control Room indication.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 58 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments

• IF AT ANY TIME CA Storage Tank (water NOTE: This is a Continuous tower) level indication is lost (invalid Action. The CRS will make reading), THEN dispatch operator to both board operators aware.

locally monitor level PER EP/1/A/5000/G 1 (Generic Enclosures), Enclosure 31 (Local CA Storage Tank (Water Tower)

Level Monitoring).

• Ensure CA Suction Sources is monitored on Foldout Page.

CRS (Step 12) Have Unit 2 perform Enclosure 5 NOTE: The CRS will ask (Unit 2 Actions). U2 to address.

If so, Floor Instructor acknowledge as U2 BOP.

RO (Step 13) Check unit status IN MODE 3.

RO/ (Step 14) Stabilize S/G pressures using SM NOTE: Only the 1A, 1C and BOP PORVs as follows: 1D SG PORVs are available.

• Reset Main Steam Isolation.

• Reset SM PORVs.

• Close all SM PORV manual loaders.

• Place SM PORVs in manual.

• Control S/G pressure between 1000 and 1100 PSIG using SM PORVs.

BOP (Step 15) Ensure VC/YC cooling available as follows:

• Check VC/YC alignment using Unit 1 status board AT LEAST ONE OPERABLE VC/YC TRAIN ALIGNED TO AN ENERGIZED UNIT 2 4160V BUS.

• Notify an available operator to initiate NOTE: The CRS will likely EP/1/A/5000/G1 (Generic Enclosures), direct the BOP to check this.

Enclosure 13 (VC and VA System Operation) within 30 minutes of loss of power.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 59 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS (Step 16) IF event has occurred that could NOTE: No such event has have caused damage to mechanical systems occurred.

internal to plant (seismic, tornado, etc),

THEN.

RO/ (Step 17) Check if S/I is actuated as follows: NOTE: SI was actuated in BOP an attempt to start the 1B D/G.

• "SAFETY INJECTION ACTUATED" status light (1SI18) LIT.

• Reset S/I.

CRS (Step 18) Dispatch operator to open the NOTE: The CRS will following breakers to sequencer DC control dispatch an AO.

power:

Booth Instructor acknowledge as appropriate, after three minutes insert MAL-EQB002A and EQB002B =

FAILURE and report that the Sequencer DC Control Breakers have been opened.

• A Train 1EVDA Breaker 6

• B Train 1EVDD Breaker 8.

CRS (Step 19) IF AT ANY TIME operator NOTE: This is a Continuous dispatched to perform Enclosure 3 (Unit 1 Action. The CRS will make ETA And ETB Rooms ECA0.0 Actions) both board operators aware.

determines that lockout exists, THEN perform the following:

• Have IAE clear or isolate fault from bus.

• WHEN fault cleared or isolated from bus, NOTE: The CRS will THEN reset lockout. dispatch an AO.

Booth Instructor acknowledge as appropriate, after one minute report that the there is a Lockout on 1ETA and there is NOT a lockout on 1ETB.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 60 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS (Step 20) Restore power to 1ETA or 1ETB using any of the following while continuing with this procedure:

• Local reset and start of D/G PER Enclosure 12 (Energizing Unit 1 4160V Bus With D/G)

OR

• Unit 1 offsite power PER Enclosure 13 (Energizing Unit 1 4160V Bus From Unit 1)

OR

• Unit 2 6900V busses through SATA or NOTE: This is the only SATB PER Enclosure 14 (Energizing Unit option for re-powering 1 4160V Bus From Unit 2 SATA or 1ETB.

SATB).

The CRS will address Enclosure 14, or hand the Enclosure off to the BOP, and continue in ECA-0.0 with the RO.

EP/1/A/5000/ECA-0.0, LOSS OF ALL AC POWER ENCLOSURE 14, ENERGIZING UNIT 1 4160V BUS FROM UNIT 2 - SATA OR SATB CRS (Step 1) Perform one of the following:

• IF 1ETA is to be energized from Unit 2, THEN observe Note prior to Step 22 and GO TO Step 22.

OR

• IF 1ETB is to be energized from Unit 2, THEN observe Note prior to Step 2 and GO TO Step 2.

BOP (Step 2) Ensure SATB is not supplying Unit 2 NOTE: The CRS/BOP will 2ETB. ask U2 to address.

If so, Floor Instructor acknowledge as U2 BOP, and report that Unit 2 SATB Feeder Breaker is not supplying Unit 2 2ETB.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 61 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments BOP (Step 3) Check the following 4160V breakers OPEN.

• 1ETB Normal Breaker

• 1ETB Standby Breaker

• 1ETB Emergency Breaker.

CRS (Step 4) Have Unit 2 RO check Unit 2 SATB NOTE: The CRS will ask Feeder Breaker CLOSED. U2 to address.

If so, Floor Instructor acknowledge as U2 BOP, and report that Unit 2 SATB Feeder Breaker is CLOSED.

CRS (Step 5) GO TO Step 8.

CRS (Step 8) Dispatch operator to 1ETB room to NOTE: The CRS will perform the following: dispatch an AO.

Booth Instructor acknowledge as appropriate, after three minutes insert ECA-0.0 (Enclosure 14) and report that 1ETB-1 has been racked out, and 1ETB-2 has been racked in.

• Obtain a copy of OP/0/A/6350/008 (Operation of Station Breakers),

Enclosure 4.2 (Operation of 4.16KV Essential Switchgear Breakers) to bring to 1ETB room.

• Check 1ETB1 (Incoming Breaker Fed From Norm Transf. No. 1ATD)

RACKED IN.

• Rack out 1ETB1 PER OP obtained in Step 8.a.

• Remove kirkkey from 1ETB1 as follows:

• Push plunger (located below kirk key) toward back of cubicle and hold.

• Rotate kirkkey to extend bolt.

• Remove kirkkey.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 62 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments

• Release plunger.

• Insert kirkkey (removed from 1ETB1) into 1ETB2 (Incoming Breaker Fed From Stby. Transf. No. SATB), making sure number on key matches number on lock.

• Check kirkkeys in 1ETB2 TWO INSERTED.

• Operate kirkkey device inside 1ETB2 as follows:

• Push plunger (located below kirk keys) toward back of cubicle and hold.

• Rotate both kirkkeys to retract bolt.

• Release plunger and allow it to move outward.

• Pull plunger outward as necessary to ensure fully extended.

• Rack in 1ETB2 breaker PER OP obtained in step 8.a.

CRS (Step 9) Do not continue until the following is performed:

• Ensure Steps 2 through 8 are completed.

• Ensure operators are away from breakers.

CRS (Step 10) Have Unit 2 RO check Unit 2 SATB NOTE: The CRS will ask Feeder Breaker CLOSED. U2 to address.

If so, Floor Instructor acknowledge as U2 BOP, and report that Unit 2 SATB Feeder Breaker is CLOSED.

BOP (Step 11) Check if S/I is actuated as follows:

• "SAFETY INJECTION ACTUATED" NOTE: SI was previously status light (1SI18) LIT. reset.

CRS (Step 11.a RNO) GO TO Step 12.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 63 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments CRS (Step 12) Check "SEQ B LOSS OF CONTROL PWR" alarm (1AD11, E2)

LIT.

BOP (Step 13) Open 1B CA pump breaker.

BOP (Step 13 RNO) Open breaker by depressing 1B CA pump "START" and "STOP" at same time.

RO/ (Step 14) Open the remaining pump BOP breakers:

• 1B NV pump

• 1B ND pump

• 1B NI pump

• 1B1 KC pump

• 1B2 KC pump

• 1B RN pump

• 1B KF pump

• 1B NS pump BOP (Step 15) Open the following 600 V essential load center feeder breakers:

• 1ELXB

• 1ELXD

• 1ELXF BOP (Step 16) Check 1B D/G Mode Select switch IN CONTROL ROOM POSITION.

BOP (Step 17) Close 1ETB Standby Breaker.

BOP (Step 18) Place 1B D/G Mode Select switch to "AUTO" position.

Appendix D Operator Action Form ES-D-2 Op Test No.: N16-1 Scenario # 4 Event # 6&7 Page 64 of 65 Event

Description:

ATWS/ Loss of Switchyard to Unit 1/1B EDG fails to START Time Pos. Expected Actions/Behavior Comments BOP (Step 19) Check 1ETB bus ENERGIZED.

BOP (Step 20) Notify Control Room Supervisor to GO TO Step 47 in body of this procedure.

At the discretion of the Lead Examiner terminate the exam.

UNIT 1 STATUS:

Power Level: 4% NCS [B] 1988 ppm Pzr [B]: 1988 ppm Xe: Per OAC Power History: At this power level for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> Core Burnup: 25.1 EFPDs CONTROLLING PROCEDURE: OP/1/A/6100/003 Controlling Procedure for Unit Operation OTHER INFORMATION NEEDED TO ASSUME THE SHIFT:

• The area has experienced steady light rain for the past 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, with light wind from the South at 2-5 mph, and this is expected to continue throughout the shift.

• The crew will hold power steady until on-going maintenance is completed, however a rod height/CB adjustment will be made at the start of the shift at the request of Reactor Engineering.

The following equipment is Out-Of-Service:

• The VUCDT Level indication is OOS. ACTION has been taken in accordance with Technical Specification LCO 3.4.15 ACTION C.

• The 1A Emergency Diesel Generator is OOS for bearing replacement. ACTION has been taken in accordance with Technical Specification LCO 3.5.2 ACTION A.

• MCB Annunciator 1AD-1, F-9, DEH/MSR SYSTEM MALFUNCT, spuriously alarmed several times during the shift, and is currently failed OFF (IAE is investigating).

Crew Directions:

• The crew will hold power steady until on-going maintenance is completed.

• RE has requested that the Control Rods be placed at 132 Steps on Bank D, and recommended a 200 gallon dilution to adjust CB to 1984 ppm.

• Blender content is Reactor Makeup Water.

Work Control SRO/Offsite Communicator Jim Plant SRO Joe (FB)

AO's AVAILABLE Unit 1 Unit 2 Aux Bldg. John Aux Bldg. Chris Turb Bldg. Bob (FB) Turb Bldg. Mike (FB) 5th Rounds. Carol Extra(s) Bill (FB) Ed (FB) Wayne (FB) Tanya Gus (RW)

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM A 2016 Systems - Control Room JPM A (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 17 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Emergency Borate the Reactor JPM No.: 2016 Systems - Control Coolant System Using the PD Pump Room JPM A (Alternate Path)

K/A

Reference:

EPE 029 EA2.10 (3.1/3.4)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Ensure Handout 1 is on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

Initial Conditions:

• Unit 1 was at 100% power with A NV pump and the A Boric Acid Transfer Pump tagged for maintenance.

• A lockout occurred on Zone 1B.

• Due to a relaying failure, busses 1TB and 1TD failed to swap to their alternate power source.

• The 1B Diesel Generator started and loaded 1ETB.

• The reactor coolant pumps tripped on under frequency.

• An automatic reactor trip FAILED to occur. EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generator/ATWS) has been implemented and completed through Step 4.

• Normal Letdown has just automatically isolated.

• The reactor has just been tripped locally.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 3 of 17 Form ES-C-1 Job Performance Measure Worksheet Initiating Cue: The CRS has directed you to emergency borate the NC System in accordance with Step 5 of EP/1/A/5000/FR-S.1, Response To Nuclear Generation/ATWS.

Task Standard: The operator will attempt to start the 1B NV Pump, and when it fails to start, start the PD Pump, and then commence emergency boration with the 1B Boric Acid Transfer Pumps running and 30 gpm or greater emergency boration flow indicated.

Required Materials: None General

References:

EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generation/ATWS),

Rev 15 EP/1A/5000/G-1 (Generic Enclosure -17, PD Pump Start), Rev 38 Handouts: Handout 1: Control Room Copy of EP/1/A/5000/FR-S.1, Response To Nuclear Power Generation/ATWS, marked up for place-keeping through Step 4.

Handout 2: Blank copy of Step 5 of EP/1/A/5000/FR-S.1 (Pages 3-4 of 29).

Handout 3: Laminated copy (Control Room Copy) of Generic Enclosure

-17, PD Pump Start Time Critical Task: NO Validation Time: 18 minutes 2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 4 of 17 Form ES-C-1 Job Performance Measure Worksheet Critical Step Justification Step 1 This step is critical because pressing the START pushbutton for the 1B NV Pump is necessary to attempt to start the 1B NV Pump.

Step 25 This step is critical because depressing the 1NV-265B OPEN pushbutton is necessary to commence emergency boration with the 1A Boric Acid Transfer Pumps running and 30 gpm or greater emergency boration flow indicated.

Step 29 This step is critical because using the UP arrow on the PD Pump SLIMs is necessary to commence emergency boration with the 1A Boric Acid Transfer Pumps running and 30 gpm or greater emergency boration flow indicated.

Alternate Path Critical Step Justification Step 7 This step is critical because depressing the 1RN-252B and 1RN-277B CLOSE pushbuttons is necessary to start the PD Pump.

Step 14 This step is critical because depressing the 1RN-63B and 1RN-64A OPEN pushbuttons is necessary to start the PD Pump.

Step 20 This step is critical because depressing the PD Pump START pushbutton is necessary to start the PD Pump.

Step 22 This step is critical because using the UP arrow on the PD Pump SLIMs is necessary to adjust flow of the PD Pump to maximum.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 5 of 17 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset to IC # 39, 100% Power, MOL. Go to RUN.

2. Insert:

a. MALF-IPE001A = TRUE Failure of Auto Reactor Trips - Train A MALF-IPE001B = TRUE Failure of Auto Reactor Trips - Train B

b. MALF-IPE002A = TRUE Failure of Manual Reactor Trips - Train A MALF-IPE002B = TRUE Failure of Manual Reactor Trips - Train B

c. LOA-NV046 = RACKED OUT Rack out 1A NV pump LOA-NV046A = RACKED OUT Rack out 1A NV Pump Control Power

d. MALF-EP006B = ACTIVE Failure of 1TB to auto swap MALF-EP006D = ACTIVE Failure of 1TD to auto swap

e. MALF-EP003C = ACTIVE Zone 1B Lockout

f. LOA-NV043 = RACKED OUT 1A BA Transfer Pump Breaker Rackout

3. Go To RUN and execute

4. Insert MALF-NV029B = TRUE NV pump trips on over current

5. Perform steps 1 through 4 of EP/1/A/5000/FR-S.1.

6. Trip the reactor 1 minute after starting the JPM by deleting:

• MALF-IPE001A, Failure of Auto Reactor Trips - Train A

• MALF-IPE001B, Failure of Auto Reactor Trips - Train B

7. Ensure Letdown isolated.

8. Allow plant time to stabilize and then Freeze Simulator.

OR

1. Reset Simulator to Temporary Snap IC-242 (October, 2015).

2. Momentarily place Simulator in Run to acknowledge alarms/Reset SLIMS.

3. Leave Simulator in FREEZE until operator is ready to begin.

4. Place Control Board Sticker on 1A NV Pump.

NOTE: During the performance of this JPM, the simulator operator will need to control CA flow to avoid NCS Cooldown and SI actuation.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 6 of 17 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Ensure Handout 1 is on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

• 1 (Step 5) Initiate emergency The operator presses the boration of the NC System: START pushbutton for the 1B NV Pump, and observes (Step 5.a) Ensure one NV that the Green status light Pump - ON. remains LIT, and the Red status light is OFF.

The operator recognizes that there are no NV Pumps operating and proceeds to Step 5.a RNO (Alternate Path).

2 (Step 5.a RNO) Place PD The operator obtains pump in service PER EP/1/A/5000/G-1 (Generic EP/1/A/5000/G-1 (Generic Enclosures), Enclosure 17.

Enclosures), Enclosure 17 (PD Pump Startup).

CUE:

WHEN the operator has located Generic Enclosure 17, provide Handout 3.

3 (Enclosure 17, Step 1) The operator observes that Check power to PD pump - the Green status light is LIT, AVAILABLE. and determines that power is available to the PD Pump.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 7 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Steps 2.a-d) Reset the The operator observes that following: the SI reset lights are LIT.

S/I The operator observes that Sequencers the A Train Sequencer reset Phase B Isolation light is LIT.

If at any time a B/O signal The operator depresses the occurs then start S/I B Train Sequencer reset equipment previously on. pushbutton and observes that the Sequencer reset light is LIT.

The operator observes that the Phase B Isolation reset lights are LIT.

5 (Step 3) Close the following:

The operator observes the Close 1RN-279B (AB Vent 1RN-279B Green status Sys Return Isol). light LIT, Red status light OFF.

The operator depresses the Close 1RN-299A (AB Vent 1RN-299A CLOSE Sys Return Isol). pushbutton and observes Green status light LIT, Red status light OFF.

Close 1RV-79A (U1 VU The operator depresses the AHUS RV Cont Outside 1RV-79A CLOSE Supply Hdr Isol). pushbutton and observes Green status light LIT, Red status light OFF.

The operator depresses the Close 1RV-101A (U1 VU 1RV-101A CLOSE AHUS RV Cont Inside pushbutton and observes Return Hdr Isol). Green status light LIT, Red status light OFF.

The operator depresses the Close 1RV-32A (U1 VL/VT 1RV-32A CLOSE AHUS RV Cont Outside pushbutton and observes Supply Hdr Isol). Green status light LIT, Red status light OFF.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 8 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 5 Close 1RV-76A (U1 VL/VT The operator depresses the AHUS RV Cont Inside 1RV-76A CLOSE (Contd) Return Hdr Isol). pushbutton and observes Green status light LIT, Red status light OFF.

The operator depresses the Close 1RV-80B (U1 VU 1RV-80B CLOSE AHUS RV Cont Inside pushbutton and observes Supply Hdr Isol).

Green status light LIT, Red status light OFF.

Close 1RV-102B (U1 VU The operator depresses the AHUS RV Cont Outside 1RV-102B CLOSE Return Hdr Isol). pushbutton and observes Green status light LIT, Red status light OFF.

Close 1RV-33B (U1 VL/VT The operator depresses the AHUS RV Cont Inside 1RV-33B CLOSE Supply Hdr Isol). pushbutton and observes Green status light LIT, Red status light OFF.

The operator depresses the Close 1RV-77B (U1 VL/VT 1RV-77B CLOSE AHUS RV Cont Outside pushbutton and observes Return Hdr Isol). Green status light LIT, Red status light OFF.

Note:

Since these steps are bulleted, the operator need not wait for the valve to completely cycle before taking action with the next valve.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 9 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 6 (Step 4) Check any NC The operator observes the pump -ON NC Pump Safety breakers Green status light LIT, Red status lights OFF, determines that no NC pumps are on and proceeds to the Step 4 RNO.

• 7 (Step 4 RNO) Close the following: The operator depresses the 1RN-252B CLOSE 1RN-252B (RB Non Ess pushbutton and observes Sup Cont Outside Isol) Green status light LIT, Red status light OFF.

The operator depresses the 1RN-277B (RB Non Ess 1RN-277B CLOSE Ret Cont Outside Isol) pushbutton and observes Green status light LIT, Red status light OFF.

8 (Step 5) Place the following The operator depresses the RF pumps in MAN and A RF Jockey Pump MAN ensure they are off: pushbutton and observes the Green status light is LIT, A Jockey pump Red status light OFF.

B Jockey pump The operator depresses the B RF Jockey Pump MAN pushbutton and observes the Green status light is LIT, Red status light OFF.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 10 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 9 (Step 6) Dispatch operator The operator contacts an to close 2RL-267 (Unit 2 AO and directs that 2RL-6900V Swgr Room AHU 267 be closed.

Supply From RN Inlet Isol)

(service bldg, 739+5, U-31, BOOTH Instructor:

NE corner of service bldg over pit, near KR storage When asked, report an tank). operator has been dispatched to close 2RL-267.

10 (Caution prior to Step 7) The operator reads Caution Both trains RN valves must and proceeds to Note prior be aligned in Step 7 unless to Step 7.

specified otherwise, even if power is lost.

11 (Note prior to Step 7) If The operator reads Note OAC is unavailable to check and proceeds to Step 7.

any deenergized valve positions, RNO contains required actions if position unknown.

12 (Steps 7/7.a) Align RN to The operator observes that AB Non Essential Header the 1A RN Pump Red as follows: Breaker status light is LIT.

Ensure 1A RN pump - ON.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 11 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 13 (Step 7.b) Check at least one of the following valves -

CLOSED:

The operator observes that 1RN-41B (Train B To Non the Green status light is LIT, Ess Hdr Isol) and the Red status light is OFF.

OR The operator observes that 1RN-43A (Train B To Non the Red status light is LIT, Ess Hdr Isol).

and the Green status light is OFF (May not be performed if 1RN-41B is observed first).

14 (Step 7.c.1-4) Open the following valves:

Open 1RN-40A (Train A to The operator observes the Non Ess Hdr Isol) 1RN-40A Red status light LIT, Green status light OFF.

Open 1RN-42A (AB Non The operator observes the Ess Supply Isol) 1RN-42A Red status light LIT, Green status light OFF.

The operator depresses the

• Open 1RN-63B (AB Non 1RN-63B OPEN pushbutton Ess Return Isol) and observes Red status light LIT, Green status light OFF.

The operator depresses the 1RN-64A (AB Non Ess 1RN-64A OPEN pushbutton

• Return Isol) and observes Red status light LIT, Green status light OFF.

15 (Step 7.d) GO TO Step 8. The operator proceeds to Step 8.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 12 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 16 (Step 8) Check if NV S/I The operator observes the flow path is open as follows: Green status light LIT for both valves, determines that 1NI-9A (NC Cold Leg Inj neither valve is OPEN, and From NV) - OPEN proceeds to the Step 8 RNO.

OR 1NI-10B (NC Cold Leg Inj From NV) - OPEN 17 (Step 8 RNO a-b) Perform The operator observes that the following: the 1B NV Pump Green IF 1A AND 1B NV pumps status light is LIT, Red OFF, THEN open 1NV-241 status lights are OFF.

(Seal Inj Flow Control) The operator adjusts the 1NV-241 controller output to 100% (Both Red and Black GO TO step 10. Needles to 100%).

Note:

The operator may use the OAC to check 1NV-241 valve position.

The operator proceeds to Step 10.

18 (Step 10) ADJUST PD The operator observes the pump speed control output PD Pump Speed Controller to 0%. in MANUAL and selects output on the SLIMs to be 0%.

19 (Step 11) Open 1NV-1047A The operator depresses the (U1 PD PUMP Recirc Isol) 1NV-1047A OPEN pushbutton and observes Red status light LIT, Green status light OFF.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 13 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 20 (Step 12) Start the PD The operator depresses the Pump. PD Pump START pushbutton and observes the Red status light LIT, Green status light OFF.

21 (Step 13) Ensure 1NV- After two minutes, the 1047A (U1 NV PD Pump operator observes that the Recirc Isol) closes after 2 1NV-1047 Green status minutes. light is LIT, Red status light is OFF.

• 22 (Step 14) WHEN 1NV- The operator uses the UP 1047A (U1 NV PD Pump arrow on the PD Pump Recirc Isol) is closed, THEN SLIMs, over at least a 45 slowly raise PD Pump second period, and speed, taking at least 45 observes Charging flow is seconds to reach desired increasing.

speed, to establish charging flow.

Cue:

IF asked, indicate that desired Charging flow is 90 gpm (Otherwise, any flow is acceptable).

23 (Note prior to Step 15) The operator reads Note Cooling water for areas in and proceeds to Step 15.

next step was isolated by Step 6.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 14 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 24 (Step 15) Notify station The operator notifies the management to monitor CRS.

temperature in both units 6900v switchgear room, Cue:

turbine bldg, and service bldg areas. Station Management has been notified.

The operator returns to EP/1/A/5000/FR-S.1, Step 5.b.

• 25 (EP/1/A/5000/FR-S.1/Step The operator depresses the 5.b/.b1) Align boration 1NV-265B OPEN flowpath: pushbutton and observes Red status light LIT, Green OPEN 1NV-265B (U1 NV status light OFF.

Boric Acid Sup Isol).

26 (Step 5.b.2) Start both boric The operator observes the acid transfer pumps. 1A Boric Acid Transfer Red and Green status light OFF.

The operator observes the 1B Boric Acid Transfer Pump Red status light LIT, Green status light OFF.

27 (Step 5.b.3) Check The operator observes emergency boration flow - boration flow on 1NVP-5440 GREATER THAN 30 GPM to be 70-80 gpm.

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 15 of 17 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 28 (Step 5.c) Check if NV flowpath aligned to NC System The operator observes 1NV-244A (Charging Line 1NV-244A Red status light Cont Isol Outside Isol) - LIT, Green status light OFF.

OPEN The operator observes 1NV-245B (Charging Line 1NV-245B Red status light Cont Outside Isol) - OPEN LIT, Green status light OFF.

• 29 (Step 5.d) Ensure charging The operator uses the UP flow is greater than arrow on the PD Pump emergency boration flow. SLIMs, as needed, and observes Charging flow is increasing.

Cue:

If asked for desired emergency boration flowrate, ask them for their recommendation and use it. Anything greater than the EB flowrate is acceptable.

30 (Step 5.e) Check Pzr The operator observes that pressure - LESS THAN Pzr Pressure is less than 2335 PSIG 2335 psig on 1NCP-5161 (or equivalent).

Terminating Cue: Another Operator will continue with the procedure.

STOP TIME:

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Page 16 of 17 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM A Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM A NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 was at 100% power with A NV pump and the A Boric Acid Transfer Pump tagged for maintenance.

• A lockout occurred on Zone 1B.

• Due to a relaying failure, busses 1TB and 1TD failed to swap to their alternate power source.

• The 1B Diesel Generator started and loaded 1ETB.

• The reactor coolant pumps tripped on under frequency.

• An automatic reactor trip FAILED to occur. EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generator/ATWS) has been implemented and completed through Step 4.

• Normal Letdown has just automatically isolated.

• The reactor has just been tripped locally.

INITIATING CUE: The CRS has directed you to emergency borate the NC System in accordance with Step 5 of EP/1/A/5000/FR-S.1, Response To Nuclear Generation/ATWS.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM B 2016 Systems - Control Room JPM B (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 12 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

CA Suction Source Realignment JPM No.: 2016 Systems - Control Room JPM B (Alternate Path)

K/A

Reference:

061 A2.07 (3.4/3.5)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• Unit 1 has just tripped from 100% power, due to seismic activity.

• The crew is now implementing EP/1/A/5000/ES-0.1 (Reactor Trip Response).

• The CA Storage Tank has developed a leak, and level has lowered to 1.5 feet.

Initiating Cue: The CRS has directed you to perform EP/1/A/5000/G-1, Generic Enclosure 20 (CA Suction Source Realignment), while the crew continues with ES-0.1.

Task Standard: The operator will realign the suction of the CA Pumps from the non-safety related to the safety-related source (RN). During the course of this action, the operator will recognize that RN Supply to the 1B MDCA Pump cannot be established, and stop the pump.

Required Materials: None 2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 3 of 12 Form ES-C-1 Job Performance Measure Worksheet General

References:

EP/1/A/5000/E-0 (Reactor Trip or Safety Injection), Rev 34 EP/1/A/5000/ES-0.1 (Reactor Trip Response), Rev 42 EP/1/A/5000/G-1 (Generic Enclosures), Rev 37 OMP 4-3 (Use of Abnormal and Emergency Procedures), Rev 42 Handouts: Handout 1: Enclosure 20 (CA Suction Source realignment) of EP/1/A/5000/G-1 (Generic Enclosures).

Time Critical Task: NO Validation Time: 8 minutes 2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 4 of 12 Form ES-C-1 Job Performance Measure Worksheet Critical Step Justification Step 4 This step is critical because pressing the 1RN-69A OPEN pushbutton is necessary to realign the suction of the CA Pumps from the non-safety related to the safety-related source.

Step 5 This step is critical because pressing the 1CA-15A OPEN pushbutton is necessary to realign the suction of the CA Pumps from the non-safety related to the safety-related source.

Step 6 This step is critical because pressing the 1CA-86A OPEN pushbutton is necessary to realign the suction of the CA Pumps from the non-safety related to the safety-related source.

Alternate Path Critical Step Justification Step 12 This step is critical because pressing the STOP pushbutton for the 1B MDCA Pump is necessary to stop the 1B MDCA pump.

Step 15 This step is critical because pressing the 1CA-11A CLOSE pushbutton is necessary to realign the suction of the CA Pumps from the non-safety related to the safety-related source.

Step 19 This step is critical because pressing the 1CA-7AC CLOSE is necessary to to realign the suction of the CA Pumps from the non-safety related to the safety-related source.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 5 of 12 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset simulator to IC-39 (100%).

2. Place Simulator in RUN.

3. Ensure that the B Train of RN is in operation.

4. Insert REM-CA0018B=0 to ensure that 1CA-18B (1B CA Pump Suction from 1B RN Isol) will not OPEN.

5. Adjust CACST to less than 30%, but greater than 0%.

6. Insert (CA) PLP-078 = 1.48 - (Simulates Leak in CAST).

7. Override ON OBE Exceeded Annunciator (1AD-13 E-7). (1AD13_E07 = ON)

8. Manually trip the reactor and perform the actions of EP/1/A/5000/E-0, and transition to EP/1/A/5000/ES-01.

9. Ensure both MDCA Pumps are running, acknowledge and silence all annunciators, and Freeze the Simulator.

OR

1. Reset to IC-243 (October, 2015)

2. Momentarily go to RUN to acknowledge Alarms then place Simulator in FREEZE.

3. Leave Simulator in FREEZE until operator is ready to begin.

NOTE: The Booth/Floor Instructor will need to control BOP during the performance of this JPM and ENSURE that SI Actuation is NOT needed.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 6 of 12 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

1 (Enclosure 20, Step 1/1.a) The operator recognizes Check if RN assured CA from the Initial Conditions suction should be that a CAST leak exists, immediately aligned as and proceeds.

follows:

Check if failure (causing leak) of CA Storage Tank (water tower) or associated CA suction piping KNOWN TO EXIST.

2 (Step 1.b) GO TO Step 4. The operator proceeds to Step 4.

3 (Step 4) Align A train RN to The operator observes the CA suction as follows: 1A RN Pump Red status light LIT, Green status light (Step 4.a) Start 1A RN OFF; and motor amps at pump. 88 amps, and determines the 1A RN Pump is running.

• 4 (Step 4.b) OPEN 1RN-69A The operator presses the (1A RN Assured Supply To 1RN-69A OPEN pushbutton U1 CA Isol). and observes the Red status light LIT, Green status light OFF.

The operator will acknowledge alarm on 1AD-5.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 7 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 5 (Step 4.c) OPEN 1CA-15A The operator presses the (1A CA Pump Suction From 1CA-15A OPEN pushbutton 1A RN Isol) and observes the Red status light LIT, Green status light OFF.

The operator will acknowledge alarm on 1AD-5.

• 6 (Step 4.d) OPEN 1CA-86A The operator presses the (U1 TD CA Pump Suction 1CA-86A OPEN pushbutton From 1A RN Isol). and observes the Red status light LIT, Green status light OFF.

The operator will acknowledge alarm on 1AD-5.

7 (Step 5) Align B train RN to CA suction as follows:

(Step 5.a) Start 1B RN The operator observes the pump. 1B RN Pump Red status light LIT, Green status light OFF; and motor amps at 88 amps, and determines the 1B RN Pump is running.

8 (Step 5.b) OPEN 1RN-162B The operator presses the (1B RN Assured Supply To 1RN-162B OPEN U1 CA Isol). pushbutton and observes the Red status light LIT, Green status light OFF.

The operator will acknowledge alarm on 1AD-5.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 8 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 9 (Step 5.c) OPEN 1CA-18B The operator presses the (1B CA Pump Suction From 1CA-18B OPEN pushbutton 1B RN Isol). and observes the Green status light remains LIT, Red status light OFF (Alternate Path).

The operator proceeds to the RNO.

10 (Step 5.c RNO) IF 1B CA The operator may press the pump is on, THEN stop 1B RESET Pushbuttons and MD CA pump as follows: observes RESET status lights LIT for both Train A (Step 5.c RNO 1) Reset S/I. and B SI. (Already RESET) 11 (Step 5.c RNO 2) Reset 1B The operator may press the Sequencer. Sequencer RESET and observes RESET status lights LIT Pushbuttons for both Train A and B.

(Already RESET)

• 12 (Step 5.c RNO 3) Stop 1B The operator presses the CA pump. STOP pushbutton for the 1B MDCA Pump and observes the Green status light LIT, Red status light OFF; and that motor amps drop to 0.

13 (Step 5.c RNO 4) IF 1B CA The operator observes that pump still on,. the 1B MDCA Pump is OFF, and proceeds.

14 (Step 5.d) OPEN 1CA-116B The operator presses the (U1 TD CA Pump Suction 1CA-116B OPEN From 1B RN Isol). pushbutton and observes the Red status light LIT, Green status light OFF.

The operator will acknowledge alarm on 1AD-5.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 9 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 15 (Step 6) Isolate nonsafety The operator presses the CA suction sources from 1CA-11A CLOSE MD CA pumps as follows: pushbutton and observes the Green status light LIT, Red status light OFF.

(Step 6.a) CLOSE 1CA-11A (1A CA Pump Suction Isol).

16 (Step 6.b) CLOSE 1CA-9B The operator presses the (1B CA Pump Suction 1CA-9B CLOSE pushbutton Isol). and observes the Green status light LIT, Red status light OFF.

17 (Step 7) Isolate non-safety CA suction sources from TD CA pump as follows:

(Step 7.a) Check the following valves - OPEN:

1RN-69A (1A RN Assured The operator observes the Supply To U1 CA Isol) 1RN-69A Red status light LIT, Green status light OFF.

1CA-86A (U1 TD CA Pump The operator observes the Suction From 1A RN Isol). 1CA-86A Red status light LIT, Green status light OFF.

18 (Step 7.b) GO TO Step 7.d. The operator proceeds to Step 7.d.

• 19 (Step 7.d) CLOSE 1CA- The operator presses the 7AC (U1 TD CA Pump 1CA-7AC CLOSE Suction Isol). pushbutton and observes the Green status light LIT, Red status light OFF.

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 10 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 20 (Step 7) WHEN time allows, THEN. Cue:

Another operator will complete the remaining steps.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Page 11 of 12 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM B Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM B NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 has just tripped from 100% power, due to seismic activity.

• The crew is now implementing EP/1/A/5000/ES-0.1 (Reactor Trip Response).

• The CA Storage Tank has developed a leak, and level has lowered to 1.5 feet.

INITIATING CUE: The CRS has directed you to perform EP/1/A/5000/G-1, Generic Enclosure 20 (CA Suction Source Realignment), while the crew continues with ES-0.1.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM C 2016 Systems - Control Room JPM C (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 12 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Establish Excess Letdown following JPM No.: 2016 Systems - Control a loss of Normal Letdown in Mode 4 Room JPM C (Alternate Path)

K/A

Reference:

004 A4.06 (3.6/3.1)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM).

Initial Conditions:

• Unit 1 is performing a plant shutdown and cooldown to Mode 5.

• The plant is currently at 345°F and 600 psig.

• The crew has entered AP/1/A/5500/12, Loss of Letdown, Charging or Seal Injection, due to a loss of Normal Letdown.

• It is not expected that the crew will be able to re-establish Normal Letdown without corrective maintenance.

Initiating Cue: The CRS has directed you to establish Excess Letdown per AP/1/A/5500/12 starting with Step 52, and maintain Pressurizer level between 85-96%.

Task Standard: The operator will attempt to place Excess Letdown in service in accordance with Step 52 of AP/1/A/55/12; and then after recognizing that Excess Letdown cannot be placed in service, establish letdown to the PRT using the Rx Head Vessel Vents in accordance with Step 53 of AP/1/A/5500/12 and maintain Pressurizer level between 85-96%.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 3 of 12 Form ES-C-1 Job Performance Measure Worksheet Required Materials: None General

References:

OP/1/A/6100/SD-4 (Cooldown to 240 Degrees F), Rev 68 OP/1/A/6100/SD-2 (Cooldown to 400 Degrees F), Rev 54 AP/1/A/5500/12 (Loss of Letdown, Charging or Seal Injection), Rev 24 Handouts: Handout 1: AP/1/A/5500/12 (Loss of Letdown, Charging or Seal Injection) marked up through Step 43 RNO, open on the CRS Desk.

Time Critical Task: NO Validation Time: 8 minutes Critical Step Justification Step 3 This step is critical because pressing the 1KC-315B and 305B OPEN pushbutton is necessary to attempt to place Excess Letdown in service in accordance with Step 52 of AP/1/A/55/12.

Step 10 This step is critical because pressing the 1NV-24B OPEN pushbutton is necessary to attempt to place Excess Letdown in service in accordance with Step 52 of AP/1/A/55/12.

Alternate Path Critical Step Justification Step 10 This step is critical because recalling that IF AT ANY TIME excess letdown cannot be established, THEN observing Note prior to Step 53 is necessary to establish letdown to the PRT using the Rx Head Vessel Vents in accordance with Step 53 of AP/1/A/5500/12.

Step 16 This step is critical because pressing the 1NC-272AC and 1NC-273AC, or the 1NC-274B and 1NC-275B OPEN pushbutton is necessary to establish letdown to the PRT using the Rx Head Vessel Vents in accordance with Step 53 of AP/1/A/5500/12.

Step 17 This step is critical because knowing that Pzr level must be lowered to 85% is necessary to establish letdown to the PRT using the Rx Head Vessel Vents in accordance with Step 53 of AP/1/A/5500/12 while minimizing the cycling of the Rx Head Vents.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 4 of 12 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset the Simulator to a Mode 4 IC (prior to placing ND in service)

2. Adjust plant parameters such that:

NCS Temperature is 345+/-3°F NCS pressure is 500-700 psig Pzr Level is 85%

3. Allow plant conditions to stabilize as needed.

4. Insert REM-NV0024B = 0 (1NV-24B (C NC LOOP TO EXS L/D HX ISOL) is stuck CLOSED).

5. Insert REM-NV0001A = 0 (1NV-1A (NC L/D ISOL TO REGEN HX) spuriously closes and cannot be opened).

6. Perform AP/1/A/5500/12 through Step 43 RNO (Handout 1).

7. Allow pressurizer level to rise to 95 %.

8. Stabilize plant conditions and Freeze the Simulator OR

1. Reset Simulator to Temporary Snap IC-244 (October, 2015)

2. Momentarily place Simulator in Run to acknowledge alarms.

3. Leave Simulator in FREEZE until operator is ready to begin.

NOTE: During the performance of this JPM, the Simulator Instructor will need to monitor unrelated alarms and silence as needed.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 5 of 12 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM).

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

1 (Step 52) Establish excess The operator observes seal letdown as follows:

injection flow to be greater than 6 GPM.

(Step 52.a) Adjust charging to minimum while The operator observes that maintaining the following: Pressurizer level is 95%

and slowly rising.

• NC pump seal injection The operator observes that flow greater than 6 charging flow is adjusted to GPM minimum.

• Pzr level at program level.

2 (Step 52.b) IF AT ANY The operator reads the TIME excess letdown conditional step, and cannot be established, proceeds.

THEN observe Note prior to Step 53 and GO TO Step 53 to establish letdown using Rx Vessel Head Vents.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 6 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 3 (Step 52.c) OPEN the The operator presses the following valves: 1KC-315B OPEN pushbutton, and observes 1KC-315B (U1 Excess L/D the Red status light is LIT, Hx KC Ret Hdr Cont Otsd Green status light is OFF.

Isol).

The operator presses the 1KC-305B (U1 KC To 1KC-305B OPEN Excess L/D Hx Cont pushbutton, and observes Outside Isol).

the Red status light is LIT, Green status light is OFF.

4 (Step 52.d) Ensure 1NV- The operator observes the 27B (U1 Excess L/D Hx 1NV-27B White VCT status Outlet 3-Way Cntrl) light is LIT, White NCDT selected to "VCT" position.

status light is OFF.

5 (Note prior to Step 52.e) The operator reads the Opening and then closing Note, and proceeds.

1NV-26B (U1 Excess L/D Hx Outlet Cntrl) in the next steps will reduce the possibility of water hammer by ensuring that the excess letdown line is filled with water.

6 (Step 52.e) OPEN 1NV-26B The operator rotates the (U1 Excess L/D Hx Outlet Manual Loader control knob Cntrl).

clockwise until both the Black and Red needles indicate 100%.

7 (Step 52.f) Wait 2 minutes. The operator takes no additional action for 2 minutes.

Cue:

Two minutes have elapsed.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 7 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 8 (Step 52.g) CLOSE 1NV- The operator rotates the 26B (U1 Excess L/D Hx Manual Loader control knob Outlet Cntrl). counter-clockwise until both the Black and Red needles indicate 0%.

9 (Step 52.h) Check the following valves - OPEN:

The operator observes the

• 1NV-94AC (U1 NC 1NV-94AC Red status light Pumps Seal Water is LIT, Green status light is Return Cont Inside Isol)

OFF.

• 1NV-95B (U1 NC The operator observes the Pumps Seal Water 1NV-95B Red status light is Return Cont Outside LIT, Green status light is Isol). OFF.

• 10 (Step 52.i) OPEN 1NV-24B The operator presses the (1C NC Loop To 1NV-24B OPEN Excess L/D Hx Isol). pushbutton, and observes the Green status light remains LIT, Red status light is OFF. (Alternate Path)

The operator recalls that IF AT ANY TIME excess letdown cannot be established, THEN observe Note prior to Step 53 and GO TO Step 53 to establish letdown using Rx Vessel Head Vents.

The operator proceeds to Step 53.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 8 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 11 (Note prior to Step 53) The The operator reads the following step is performed Note, and proceeds.

in conjunction with OP/1/A/6150/004 (Pressurizer Relief Tank),

Enclosure 4.3 (PRT Cue:

Cooling).

Another operator will perform Enclosure 4.3 of OP/1/A/6150/004.

12 (Step 53) Establish letdown The operator observes NCS to PRT using Rx temperature and the Rx Trip Vessel Head Vents as Breakers and determines follows: that the plant is in Mode 4.

(Step 53.a) Check unit status - IN MODE 3, 4 OR 5.

13 (Step 53.b) IF AT ANY The operator reads the TIME normal letdown OR conditional step, and excess letdown available, proceeds.

THEN perform one of the following:

Establish normal letdown PER Steps 43 through 49.

OR Establish excess letdown PER Step 52.

14 (Caution prior to Step 53.c) The operator reads the PRT rupture disk relieves at Caution, and proceeds.

100 psig.

15 (Note prior to Step 53.c) The operator reads the Cycling of head vents in the Note, and proceeds.

following step should be minimized due to water hammer concerns in vent line.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 9 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 16 (Step 53.c) IF AT ANY The operator reads the TIME Pzr level approaches conditional step, and 96%, THEN perform the observes Pressurizer level following:

to be 96%.

(Step 53.c.1) OPEN one The operator presses the train of head vent valves: 1NC-272AC OPEN pushbutton, and observes Train A: the Red status light is LIT,

• 1NC-272AC (U1 A Train Green status light is OFF.

Head Vent to PRT Isol) The operator presses the

• 1NC-273AC (U1 A Train 1NC-273AC OPEN Head Vent to PRT Isol). pushbutton, and observes the Red status light is LIT, OR Green status light is OFF.

OR Train B:

• 1NC-274B (U1 B Train The operator presses the Head Vent to PRT Isol) 1NC-274B OPEN

• 1NC-275B (U1 B Train pushbutton, and observes Head Vent to PRT Isol). the Red status light is LIT, Green status light is OFF.

The operator presses the 1NC-275B OPEN pushbutton, and observes the Red status light is LIT, Green status light is OFF.

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 10 of 12 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 17 (Step 53.c.2) WHEN Pzr at The operator observes desired level, THEN Pressurizer level to be CLOSE head vent valves lowering toward 96%, and opened above. then continues to lower Pressurizer level toward 85%.

Cue:

Another operator will continue with this procedure.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Page 11 of 12 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM C Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM C NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 is performing a plant shutdown and cooldown to Mode 5.

• The plant is currently at 345°F and 600 psig.

• The crew has entered AP/1/A/5500/12, Loss of Letdown, Charging or Seal Injection, due to a loss of Normal Letdown.

• It is not expected that the crew will be able to re-establish Normal Letdown without corrective maintenance.

INITIATING CUE: The CRS has directed you to establish Excess Letdown per AP/1/A/5500/12 starting with Step 52, and maintain Pressurizer level between 85-96%.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM D 2016 Systems - Control Room JPM D (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 16 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Remove Pressurizer Heaters from JPM No.: 2016 Systems - Control Service Room JPM D (Alternate Path)

K/A

Reference:

010 A4.02 (3.6/3.4)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• Unit 1 has just increased reactor power to 100% per OP/1/A/6100/003 (Controlling Procedure for Unit Operation).

• Chemistry has confirmed that the Boron Concentration difference between the Pzr and the NC System is 4 ppm.

Initiating Cue:

• The CRS has directed you to remove Pzr Heater Groups A, B and D from service per Enclosure 4.6 (Operation of Pzr Heaters) of OP/1/A/6100/003, and ensure that NC System pressure is being controlled normally at 2235 psig.

• All outstanding R&Rs that may impact performance of Enclosure 4.6 have been evaluated.

Task Standard: The operator will remove the A, B and D Pzr Heater Groups from service in accordance with Step 3.4.4 of Enclosure 4.6, and then after responding to the failure of the C Pzr Heater Group, manually control pressure by re-energizing at least one heater group. The operator will place at least one Pzr Heater Group in service in accordance with Step 3.3.1 (or equivalent) of Enclosure 4.6, before MCB Annunciator 1AD-6, C6 alarms.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 3 of 16 Form ES-C-1 Job Performance Measure Worksheet Required Materials: None General

References:

OP/1/A/6100/003 (Controlling Procedure for Unit Operation), Rev. 197 OP/1/A/6100/010G (Annunciator Response for Panel 1AD-6), Rev. 68 AD-HU-ALL-0004 (Procedure and Work Instruction Use and Adherence), Rev. 3 Handouts: Handout 1: Enclosure 4.6 (Operation of Pzr Heaters) of OP/1/A/6100/003 (Controlling Procedure for Unit Operation)

Time Critical Task: NO Validation Time: 12 minutes 2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 4 of 16 Form ES-C-1 Job Performance Measure Worksheet Critical Step Justification Step 7 This step is critical because rotating either the A, B or D Pzr Htr Mode Select Switch counter - clockwise to AUTO is necessary to remove the 1st Pzr Heater group from service.

Step 10 This step is critical because rotating either the A, B or D Pzr Htr Mode Select Switch counter - clockwise to AUTO is necessary to remove the 2nd Pzr Heater group from service.

Step 16 This step is critical because rotating either the A, B or D Pzr Htr Mode Select Switch counter - clockwise to AUTO is necessary to remove the 3rd Pzr Heater group from service.

Step 18 This step is critical because selecting Pzr Pressure Master and selecting M is necessary to remove the A, B and D Pzr Heater Groups from service in accordance with Step 3.4.4 of Enclosure 4.6.

Step 19 This step is critical because adjusting the Master Pressure Controller the error signal is < 15 psig is necessary to remove the A, B and D Pzr Heater Groups from service in accordance with Step 3.4.4 of Enclosure 4.6.

Step 20 This step is critical because selecting Pzr Pressure Master and selects A is necessary to remove the A, B and D Pzr Heater Groups from service in accordance with Step 3.4.4 of Enclosure 4.6.

Alternate Path Critical Step Justification Step 21 This step is critical because observing MCB Annunciator 1AD6/D6 and addressing the ARP is necessary to recognize that all Pressurizer Heaters are OFF.

Step 24 This step is critical because re-energizing at least one set of Pressurizer heaters is necessary to place at least one Pzr Heater Group in service in accordance with Step 3.3.1 (or equivalent) of Enclosure 4.6, before MCB Annunciator 1AD-6, C6 alarms.

Step 25 This step is critical because re-energizing at least one set of Pressurizer heaters is necessary to place at least one Pzr Heater Group in service in accordance with Step 3.3.1 (or equivalent) of Enclosure 4.6, before MCB Annunciator 1AD-6, C6 alarms.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 5 of 16 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset simulator to IC-39 (100%)

2. Ensure Simulator reflects having been completed through Step 3.38.10.3 of OP/1/A/6100/003, Enclosure 4.1 (Power Increase).

3. Ensure that Pzr Heater groups A, B, and D are energized.

4. Acknowledge Alarms and Freeze Simulator

5. Create Lesson Plan NRC JPM D (Failure of Pzr Variable Heaters).

(ANN) 1AD6-D06 = ON Insert X10_190_1 = False (0) (C heaters energize/de-energize Red Status light - OFF)

OR

1. Reset Simulator to Temporary Snap IC-245 (October, 2015).

2. Execute Lesson Plan NRC JPM C (Failure of Pzr Variable Heaters).

3. Momentarily place Simulator in Run to acknowledge alarms.

4. Leave Simulator in FREEZE until operator is ready to begin.

NOTE: During the performance of this JPM, the simulator operator will need to execute failure at Step 20 of the JPM.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 6 of 16 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

1 (Enclosure 4.6, Step 3.1) The operator recognizes Evaluate all outstanding that this step has already R&Rs that may impact been performed (Initial performance of this Conditions), and proceeds.

procedure.

2 (Note prior to Step 3.2) The operator reads the During steady state Note and proceeds.

conditions, Pzr Htr Groups are normally OFF and in AUTO.

3 (Step 3.2) Perform the The operator recognizes following sections as that Section 3.4 is the applicable: applicable section and proceeds to Section 3.4.

• Section 3.3, Placing A, B, D Pzr Heater Groups in Service.

• Section 3.4, Removing A, B, D Pzr Heater Groups form Service.

• Section 3.5, Placing C Pzr Heater Group in Service.

• Section 3.6, Removing C Pzr Heater Group from Service.

• Section 3.7, Manual Operation of A, B, D Pzr Heater Groups 2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 7 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Step 3.4) Removing A, B, D Pzr Heater Groups From Service (Caution prior to Step 3.4.1) The operator reads the Pzr Htr Groups and Pzr Caution and proceeds.

Spray Controls should be operated with extreme caution to prevent NC System pressure transients.

(Step 3.4.1) Ensure Boron The operator recognizes Concentration difference that this condition is already between Pzr and NC met (Initial Conditions), and System less than 50 ppm. proceeds.

5 (Step 3.4.2) IF three Pzr Htr The operator recognizes Groups in service AND that this step is NOT desire to operate with two applicable and proceeds.

Pzr Htr Groups in service..

6 (Step 3.4.3) IF three Pzr Htr The operator recognizes Groups in service AND that this step is NOT desire to operate with one applicable and proceeds.

Pzr Htr Group in service..

(Step 3.4.4) IF three Pzr Htr

• 7 Groups in service AND desire to remove all Pzr Htr Groups from service, perform the following:

(Step 3.4.4.1) Place one of The operator rotates either the following in AUTO: the A, B or D Pzr Htr Mode A Pzr Htr Mode Select Select Switch counter -

clockwise to AUTO.

B Pzr Htr Mode Select D Pzr Htr Mode Select 2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 8 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 8 (Step 3.4.4.2) Check The operator observes the associated Pzr Htr Group in Green status light LIT and OFF. the Red status light OFF for the heater group, whose A Pzr Htr Group Mode Select Switch was B Pzr Htr Group moved to AUTO in the D Pzr Htr Group previous step.

9 (Step 3.4.4.3) Monitor Pzr The operator observes pressure for 2 minutes. actual Pressurizer Pressure and Spray Valve position (Or equivalent) for 2 minutes and determines that Pzr Pressure has stabilized.

Examiner Cue:

If pressure is stabilized, Two minutes has elapsed.

• 10 (Step 3.4.4.4) Place second Pzr Htr Mode Select Switch in AUTO:

The operator rotates either A Pzr Htr Mode Select the A, B or D Pzr Htr Mode B Pzr Htr Mode Select Select Switch counter-D Pzr Htr Mode Select clockwise to AUTO.

11 (Step 3.4.4.5) Check The operator observes the associated Pzr Htr Group in Green status light LIT and OFF. the Red status light OFF for the heater group, whose A Pzr Htr Group Mode Select Switch was B Pzr Htr Group moved to AUTO in the D Pzr Htr Group previous step.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 9 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 12 (Step 3.4.4.6) Monitor Pzr The operator observes pressure for 2 minutes. actual Pressurizer Pressure and Spray Valve position (Or equivalent) for 2 minutes and determines that Pzr Pressure has stabilized.

Examiner Cue:

If pressure is stabilized, Two minutes has elapsed.

13 (Note prior to Step 3.4.4.7) The operator reads the Placing Pzr Press Master in Note and proceeds.

manual makes automatic operation of 1NC-34A (Pzr PORV) unavailable and should be evaluated using Electronic Risk Assessment Tool. This assessment should be performed prior to placing Pzr Press Master in manual.

14 (Step 3.4.4.7) IF time allows The operator informs the AND Unit 1 in Modes 1-4, CRS.

evaluate unavailability of 1NC-34A (Pzr PORV) using Electronic Risk Assessment Examiner Cue:

Tool.

As the CRS/STA, indicate that the ERAT has been evaluated with no issues.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 10 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 15 (Note prior to Step 3.4.4.8) The operator reads the Steps 3.4.4.8 - 3.4.4.10 C Note and proceeds.

should be performed without delay.

• 16 (Step 3.4.4.8) Place third The operator rotates either Pzr Htr Mode Select in the A, B or D Pzr Htr Mode AUTO: Select Switch counter-A Pzr Htr Mode Select clockwise to AUTO.

B Pzr Htr Mode Select D Pzr Htr Mode Select 17 (Step 3.4.4.9) Check The operator observes the associated Pzr Htr Group in Green status light LIT and OFF. the Red status light OFF for the heater group, whose A Pzr Htr Group Mode Select Switch was B Pzr Htr Group moved to AUTO in the D Pzr Htr Group previous step.

• 18 (Step 3.4.4.10) On the DCS The operator observes the Work Station, Pressurizer NC-Pressurizer and PRT and PRT graphic, perform DCS Screen and observes the following: Pressurizer pressure.

(Step 3.4.4.10 A) Place The operator selects Pzr PZR PRESS MASTER in Pressure Master and manual. selects M (Turns RED).

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 11 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 19 (Step 3.4.4.10 B) Adjust Using the NC-Pressurizer PZR PRESS MASTER and PRT DCS Screen, the output until the following operator adjusts Pzr Press occurs: Master output (DOWN) until the error signal is < 15 psig.

C Pzr Htr Group begins cycling The operator observes C 1NC-27C (A Loop Pzr Pzr Heater Group Red Spray Control) Closes Status light cycling ON and 1NC-29C (B Loop Pzr OFF, and determines that Spray Control) Closes the C Pzr Htr Group is cycling.

The operator observes the 1NC-27C SLIMs Limit Switch and determines that 1NC-27C is CLOSED.

The operator observes the 1NC-29C SLIMs Limit Switch and determines that 1NC-29C is CLOSED.

• 20 (Step 3.4.4.10 C) Place Using the NC-Pressurizer PZR PRESS MASTER in and PRT DCS Screen, the auto. operator selects Pzr Pressure Master and selects A (Turns GREEN).

Simulator Instructor NOTE: Execute & Activate Lesson Plan (Failure of Pzr Variable Heaters) (Alternate Path)

It is expected that MCB Annunciator 1AD6/D6 (PZR HTR CONTROLLER TROUBLE) will alarm.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 12 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 21 (Step 3.4.4.11) Monitor Pzr The operator observes pressure for 2 minutes. actual Pressurizer Pressure and Spray valve Position (Or equivalent) and determines that Pzr Pressure is lowering.

The operator observes MCB Annunciator 1AD6/D6 and addresses ARP.

22 (OP/1/A/6100/010 G, The operator observes the Immediate Action 1) C Pzr Heater Group Green Remove Group C Heater and Red Breaker Status Group from automatic light are OFF.

control by opening supply breaker. The operator may observe the OAC indicating a demand on the C Pzr Heater Group (Red Heater lines), and depress the C Pzr Heater Group OPEN pushbutton (No effect, both status lights are OFF).

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 13 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 23 (OP/1/A/6100/010 G, The operator recognizes Immediate Action 2) that no Pzr htrs are Manually control pressure energized and proceeds to using other heater groups. Enclosure 4.6, Step 3.3.1 (Or Equivalent) to place one Pzr Htr Group in service.

Examiner Note:

The operator may use one or more Pzr Heater Groups to maintain NC System Pressure within the normal band.

The operator MUST place at least one Pzr Htr Group in service to complete the Critical nature of this task.

The operator should realize the need to get one set of htrs on for pressure control and MAY start one set of htrs based on ARP guidance to manually control pressure. If NOT, the required OP Steps of Section 3.3.1 are scripted.

However, Section 3.7 of Enclosure 4.6 may be used as well.

Examiner Note:

IF MCB Annunciator 1AD-6, C6, alarms before the operator energizes one set of Heaters, the Critical Step is Failed.

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 14 of 16 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 24 (Enclosure 4.6, Step 3.3)

Placing A, B, D Pzr Heater Groups in service.

(Caution prior to Step 3.3.1) The operator reads the Pzr Htr Groups and Pzr Caution, and proceeds.

Spray Controls should be operated with extreme caution to prevent NC System pressure transients.

(Step 3.3.1) IF desired to operate with one Pzr Htr group in service, perform the following:

(Step 3.3.1.1) Place of the The operator rotates either following in MAN: the A, B or D Pzr Htr Mode A Pzr Htr Mode Select Select Switch clockwise to MAN.

B Pzr Htr Mode Select D Pzr Htr Mode Select

• 25 (Step 3.3.1.2) Place the The operator depresses the associated Pzr Htr Group in ON pushbutton for the ON: heater group, whose Mode Select Switch was moved to A Pzr Htr Group MAN in the previous step, B Pzr Htr Group and observes the Red D Pzr Htr Group status light LIT and the Green status light OFF.

26 (Step 3.3.1.3) Monitor Pzr The operator observes pressure for 2 minutes. Pressurizer Pressure and Spray valve Position (Or equivalent) for 2 minutes and determines that Pzr Pressure has stabilized at 2235 +/-15 psig.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Page 15 of 16 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM D Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM D NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 has just increased reactor power to 100% per OP/1/A/6100/003 (Controlling Procedure for Unit Operation).

• Chemistry has confirmed that the Boron Concentration difference between the Pzr and the NC System is 4 ppm.

INITIATING CUE:

• The CRS has directed you to remove Pzr Heater Groups A, B and D from service per Enclosure 4.6 (Operation of Pzr Heaters) of OP/1/A/6100/003, and ensure that NC System pressure is being controlled normally at 2235 psig.

• All outstanding R&Rs that may impact performance of Enclosure 4.6 have been evaluated.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM E 2016 Systems - Control Room JPM E (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 11 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Depressurize NCS During Natural JPM No.: 2016 Systems - Control Circulation Cooldown Room JPM E (Alternate Path)

K/A

Reference:

EPE E09 EA1.1 (3.5/3.5)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

Initial Conditions:

• Unit 1 has tripped from 100% power due to a Loss of Off-Site Power.

• The crew is currently implementing EP/1/A/5000/ES-0.2 (Natural Circulation Cooldown), and is currently at Step 15.

• Normal Letdown is in service.

Initiating Cue: The CRS has directed you to depressurize the NC system to 1905 PSIG using aux spray per Generic Enclosures, Enclosure 3 (Establishing NV Aux Spray).

Task Standard: The operator will place Auxiliary Spray in service and lower Pzr Pressure to 2030 psig; and after diagnosing a loss of Normal Letdown immediately remove Aux Spray from service.

Required Materials: None 2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 3 of 11 Form ES-C-1 Job Performance Measure Worksheet General

References:

EP/1/A/5000/E-0 (Reactor Trip or Safety Injection), Rev 34 EP/1/A/5000/ES-0.1 (Reactor Trip Response), Rev 42 EP/1/A/5000/ES-0.2 (Natural Circulation Cooldown), Rev 12 EP/1/A/5000/G-1 (Generic Enclosures), Rev 38 OP/1/A/6200/001 A (Chemical and Volume Control System Letdown),

Rev 53 Handouts: Handout 1: EP/1/A/5000/ES-0.2 (Natural Circulation Cooldown) marked up for this JPM.

Handout 2: Generic Enclosure 3 (Establishing NV Aux Spray)

Handout 3: Enclosure 4.7 (Operator Action With NV Aux Spray In Service) of OP/1/A/6200/001 A (Chemical and Volume Control System Letdown)

Time Critical Task: NO Validation Time: 12 minutes Critical Step Justification Step 9 This step is critical because pressing the 1NV-21A OPEN pushbutton is necessary to place Auxiliary Spray in service and lower Pzr Pressure to 2030 psig.

Step 10 This step is critical because pressing the 1NV-16A CLOSE pushbutton is necessary to place Auxiliary Spray in service and lower Pzr Pressure to 2030 psig.

Step 11 This step is critical because adjusting the 1NV-238 controller and 1NV-241 manual loader to ensure that Regenerative Hx letdown temperature remains less than 380°F, and Pzr spray water delta T remains less than 320°F is necessary to place Auxiliary Spray in service and lower Pzr Pressure to 2030 psig.

Alternate Path Critical Step Justification Step 13 This step is critical because pressing the 1NV-13B OPEN pushbutton and the 1NV-21A CLOSE pushbutton is necessary to remove Aux Spray from service after diagnosing a loss of Normal Letdown.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 4 of 11 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset Simulator to IC-39 (100% power)

2. Insert MALF EP002A and EP002B (Loss of Off-site Power)

3. Implement E-0, ES-0.1 and ES-0.2 through Step 15.

4. Ensure NCS System parameters as follows:

• Thots - < 550°F

• Pzr Level - at Setpoint

• Pzr Pressure 2335 psig

• SG NR Levels 39%

5. Ensure Normal Letdown is in service.

6. Ensure that all available Pzr Heaters are ON.

7. Place REM-NV0007B=0 cd H_X10_125_1 LT 2030 and on TRIGGER #1 (1NV-7B inadvertently closed).

8. Freeze Simulator.

OR

1. Reset Simulator to Temporary Snap IC-246 (October, 2015).

NOTE: During the performance of the JPM, the Simulator Instructor will be required to:

• Acknowledge spurious alarms unrelated to the task being performed.

• The Letdown isolation is triggered to occur at 2030 psig. If Normal Letdown isolation does NOT occur as expected, Operate TRIGGER #1 at Step 12-13 of JPM when Pzr Pressure has lowered to 2030 psig.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

1 (Enclosure 3, Step 1) IF S/I The operator recognizes has occurred, THEN. that SI has NOT occurred, and proceeds.

2 (Step 2) REFER TO The operator seeks a copy OP/1/A/6200/001 A of Enclosure 4.7 of (Chemical and Volume OP/1/A/6200/001 A.

Control System Letdown),

Enclosure 4.7 (Operator Cue:

Actions with NV Aux Spray in Service). Provide operator with Handout 3.

The operator reviews the Enclosure, and proceeds.

3 (Caution prior to Step 3) The operator reads the Raising charging flow will Caution, and proceeds.

raise NV aux spray water delta T and raise spray flowrate.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Notes prior to Step 3) Pzr The operator reads the spray water delta T can be Notes, and proceeds.

determined by subtracting "REGEN HX CHARGING TEMP" from "PZR VAPOR SPACE TEMP".

Controlling flow through 1NV241 (U1 Seal Water Inj Flow Control) also controls NV aux spray flow.

5 (Step 3) Control charging The operator reads the and letdown flow in Step, and proceeds.

subsequent steps as required to:

Maintain Pzr spray water delta T less than 320°F.

Maintain Regenerative Hx letdown temperature less than 380°F.

6 (Step 4) IF AT ANY TIME The operator reads the normal letdown is lost, conditional Step, and THEN immediately isolate proceeds.

NV aux spray.

7 (Step 5) CLOSE the The operator observes the following normal Pzr spray 1NC27C SLIMS and valves and leave closed observes the output to be while NV aux spray is used: 0%, and that the Red closed light is LIT.

1NC27C (1A NC Loop PZR Spray Control) The operator observes the 1NC29C SLIMS and 1NC29C (1B NC Loop observes the output to be PZR Spray Control). 0%, and that the Red closed light is LIT.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 8 (Caution prior to Step 6) The operator the Caution, The number of times the and proceeds.

following valves are cycled should be kept to minimum, to limit the number of thermal transients on charging nozzle.

• 9 (Step 6) Establish NV aux The operator presses the spray as follows: 1NV-21A OPEN pushbutton and observes the Red (Step 6.a) OPEN 1NV21A status light is LIT, and the (U1 NV Supply to U1 Aux Green status light is OFF.

PZR Spray Isol).

10 (Step 6.b) CLOSE the following valves:

The operator observes the 1NV13B (U1 NV Supply 1NV-13B Green status light To 1A NC Loop Isol) is LIT, and the Red status light is OFF.

The operator presses the 1NV16A (U1 NV Supply 1NV-16A CLOSE

• To 1D NC Loop Isol). pushbutton and observes the Green status light is LIT, and the Red status light is OFF.

• 11 (Step 7) Slowly control The operator adjusts the charging flow as desired to 1NV-238 controller and control depressurization 1NV-241 manual loader to rate. ensure that Regenerative Hx letdown temperature remains less than 380°F, and Pzr spray water delta T remains less than 320°F.

The operator observes Pzr Pressure is slowly lowering.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 12 (Caution prior to Step 8) If The operator reads the excessive depressurization Caution, and proceeds.

occurs, the following step may need to be performed immediately.

Simulator Instructor NOTE: If Normal Letdown is NOT already isolated when Pzr Pressure is 2030 psig, Operate TRIGGER #1.

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 9 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Note:

When the operator determines that normal Letdown is lost, the operator will either perform Step 8 of Enclosure 3 (JPM Step 13 scripted BELOW), or its equivalent step on Enclosure 4.7 of OP/1/A/6200/001 A (Handout 3 provided to the operator in JPM Step 2).

If the equivalent Step is performed (Step 3.2 of Enclosure 4.7) the operator will:

• Close 1NV-21A

• OPEN either 1NV-13B or 1NV-16A

• 13 (Step 8) IF AT ANY TIME The operator observes NV aux spray must be Letdown flow at 0 gpm or stopped, THEN perform the responds to Group 4 C5, following: 1NV-7B LETDOWN CONT ISOL OTSD CLOSED, annunciator on the ESF Monitor Status Panel (Alternate Path).

(Step 8.a) OPEN 1NV13B The operator presses the (U1 NV Supply To 1A NC 1NV-13B OPEN pushbutton Loop Isol). and observes the Red status light is LIT, and the (Step 8.b) IF 1NV13B will Green status light is OFF.

not open, THEN ..

(Step 8.c) CLOSE 1NV21A The operator presses the (U1 NV Supply to U1 Aux 1NV-21A CLOSE PZR Spray Isol). pushbutton and observes the Green status light is LIT, (Step 8.d) WHEN desired to and the Red status light is restore NV aux spray, OFF.

THEN RETURN TO Step 1.

Terminating Cue: Another Operator will continue with this procedure.

STOP TIME:

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM E Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM E NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 has tripped from 100% power due to a Loss of Off-Site Power.

• The crew is currently implementing EP/1/A/5000/ES-0.2 (Natural Circulation Cooldown), and is currently at Step 15.

• Normal Letdown is in service.

INITIATING CUE: The CRS has directed you to depressurize the NC system to 1905 PSIG using aux spray per Generic Enclosures, Enclosure 3 (Establishing NV Aux Spray).

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM F 2016 Systems - Control Room JPM F (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 11 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Perform the 1A Annulus Ventilation JPM No.: 2016 Systems - Control Operability Test Room JPM F K/A

Reference:

027 A4.01 (3.3/3.3)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• Unit 1 is operating at 100% power and the Unit 1 VE System is aligned for Engineered Safeguards Operation.

• PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test) is on the Operations schedule for today.

• AO John has been briefed on the performance of this Surveillance, and is standing by to assist in the operation.

Initiating Cue: The CRS has directed you to perform PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test).

Task Standard: The operator will place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed. The 1A VE Fan will be shut down after flow verification and returned to normal alignment.

Required Materials: None General

References:

PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test) Rev 26 2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 3 of 11 Form ES-C-1 Job Performance Measure Worksheet Handouts: Handout 1: PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test) marked up as follows:

Step 7.1 - Initialed Step 8.1 - Initialed Step 12.1 - Initialed Time Critical Task: NO Validation Time: 12 minutes Note: This JPM should be pre-briefed in the Briefing Room.

Critical Step Justification Step 1 This step is critical because rotating the 1AVS-D-3 Mode Select switch clockwise to MAN is necessary to place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed.

Step 2 This step is critical because pressing the 1AVS-D-3 CLOSE pushbutton is necessary to place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed.

Step 3 This step is critical because rotating the 1AVS-D-2 Mode Select switch clockwise to MAN is necessary to place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed.

Step 4 This step is critical because pressing the 1AVS-D-2 CLOSE pushbutton is necessary to place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed.

Step 6 This step is critical because rotating the 1A VE Fan Control Switch clockwise to ON is necessary to place the 1A VE Fan in Recirculation Mode with the cross connect from B Train closed.

Step 15 This step is critical because rotating the 1A VE Fan Control Switch counter-clockwise to RESET is necessary to shut down the 1A VE Fan and return the system a to normal alignment.

Step 19 This step is critical because rotating the 1AVS-D-3 Mode Select switch counter-clockwise to AUTO is necessary to return the system a to normal alignment.

Step 21 This step is critical because rotating the 1AVS-D-2 Mode Select switch counter-clockwise to AUTO is necessary to return the system a to normal alignment.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 4 of 11 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset the Simulator to IC-39 (100% Power)

2. Allow conditions to stabilize.

3. Freeze the Simulator OR

1. Reset Simulator to Temporary Snap IC-247 (October, 2015).

2. Momentarily place Simulator in Run to acknowledge alarms.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 1 (Step 12.2) Place "1AVS-D- The operator rotates the 3 Mode Select" in "MAN". 1AVS-D-3 Mode Select switch clockwise to MAN.

• 2 (Step 12.3) Close 1AVS-D- The operator presses the 3 (1A VE Disch Damper to 1AVS-D-3 CLOSE Unit Vent). pushbutton and observes Green status light is LIT, Red status light is OFF.

• 3 (Step 12.4) Place "1AVS-D- The operator rotates the 2 Mode Select" in "MAN". 1AVS-D-2 Mode Select switch clockwise to MAN.

• 4 (Step 12.5) Open 1AVS-D- The operator presses the 2 (1A VE Disch Damper to 1AVS-D-2 OPEN Annulus). pushbutton and observes Red status light is LIT, Green status light is OFF.

5 (Step 12.6) Ensure 1AVS- The operator observes the D-9 (1B VE Fan Suct X- 1AVS-D-9 Green status Connect) closed. light is LIT, Red status light is OFF.

• 6 (Step 12.7) Start 1A VE The operator rotates the 1A Fan. VE Fan Control Switch clockwise to ON and observes Red status light is LIT, Green status light is OFF.

7 (Step 12.8) Check "RESET" The operator observes the lit for "1A VE Train Preheat Yellow 1A VE Train Preheat Hi Temp Reset". Hi Temp Reset light is LIT.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 8 (Note prior to Step 12.9) The operator reads the Heater operability and Note and proceeds.

compliance with McGuire Tech Spec requirements (Reference 2.1) is determined by PT/1/A/4450/003 D (Annulus Filter 1A Heater Dissipation Test).

9 (Step 12.9) Check: The operator observes the White 1A A VE Preheater

• "A VE Preheater No. 1 No. 1 On light is LIT.

On"

• "A VE Preheater No. 2 The operator observes the On" White 1A A VE Preheater

• Positive D/P across any No. 2 On light is LIT.

filter within Filter Package The operator observes the four DP gages indicate between 1-3 inches H2O.

10 (Step 12.10) Record date The operator records the and time of test start: current date and time.

Date: ______________

Time: ______________

11 (Step 12.11) HOLD until The operator identifies that test is run for at least 10 the test must continue for hours. the next ten hours.

Cue:

Using Time Compression, ten hours have elapsed.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 12 (Note prior to Step 12.12) The operator reads the Heater operability and Note and proceeds.

compliance with McGuire Tech Spec requirements (Reference 2.1) is determined by PT/1/A/4450/003 D (Annulus Filter 1A Heater Dissipation Test).

13 (Step 12.12) Check the The operator observes the following: White 1A A VE Preheater No. 1 On light is LIT.

• "A VE Preheater No. 1 On" The operator observes the

• "A VE Preheater No. 2 White 1A A VE Preheater On" No. 2 On light is LIT.

• Positive D/P across any filter within Filter The operator observes the Package four DP gages indicate between 1-3 inches H2O.

14 (Note prior to Step 12.13) The operator reads the Heaters may cause an Note and proceeds.

HVAC 0AD12 annunciator to alarm and "Carbon Bed Temp >190°F" status light to actuate after the 1A VE Fan is stopped.

• 15 (Step 12.13) Stop 1A VE The operator rotates the 1A Fan by rotating "1A VE Fan" VE Fan Control Switch to "RESET". counter-clockwise to RESET and observes Green status light is LIT, Red status light is OFF.

16 (Step 12.14) Check "1A VE The operator releases the Fan" returns to "AUTO". 1A VE Fan Control Switch and observes that the switch spring-returns to AUTO.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 17 (Step 12.15) Record date The operator records the and time of test completion: current date and time.

Date: ______________

Time: ______________

18 (Note prior to Step 12.16) The operator reads the Train 1A VE Dampers will Note and proceeds.

reposition when damper mode select switches are positioned to "AUTO".

• 19 (Step 12.16) Place "1AVS- The operator rotates the D-3 Mode Select" in 1AVS-D-3 Mode Select "AUTO". switch counter-clockwise to AUTO.

20 (Step 12.17) Check 1AVS- The operator observes the D-3 (1A VE Disch Damper 1AVS-D-3 Red status light to Unit Vent) "OPEN". is LIT, Green status light is OFF.

• 21 (Step 12.18) Place "1AVS- The operator rotates the D-2 Mode Select" in 1AVS-D-2 Mode Select "AUTO". switch counter-clockwise to AUTO.

22 (Step 12.19) Check 1AVS- The operator observes the D-2 (1A VE Disch Damper 1AVS-D-2 Green status to Annulus) "CLOSED". light is LIT, Red status light is OFF.

23 (Step 12.20) Ensure 1AVS- The operator observes the D-9 (1B VE Fan Suct X- 1AVS-D-9 Green status Connect) closed. light is LIT, Red status light is OFF.

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 9 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 24 (Notes prior to Step 12.21) The operator reads the 5 to 10 minutes may need Notes and proceeds.

to pass after 1A VE Fan is stopped to obtain the "RESET" indication for "1A VE Train Preheat Hi Temp Reset".

"RESET" indication for "1A VE Train Preheat Hi Temp Reset" must be obtained to ensure VE operability.

25 (Step 12.21) Depress The operator presses the "RESET" for "1A VE Train 1A VE Train Preheat Hi Preheat Hi Temp Reset". Temp Reset pushbutton (Status light is already LIT).

26 (Step 12.22) Check The operator observes the "RESET" lit for "1A VE Train 1A VE Train RESET status Preheat Hi Temp Reset". light is LIT.

27 (Note prior to Step 12.23) The operator reads the Annulus doors must be Note and proceeds.

closed to ensure Reactor Building operability.

(McGuire Tech Spec.

3.6.16) 28 (Step 12.23) Evaluate 1A The operator notifies the VE operability. CRS to evaluate 1A VE operability.

Cue:

The CRS acknowledges and indicates that another operator will continue with this procedure.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM F Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM F NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 is operating at 100% power and the Unit 1 VE System is aligned for Engineered Safeguards Operation.

• PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test) is on the Operations schedule for today.

• AO John has been briefed on the performance of this Surveillance, and is standing by to assist in the operation.

INITIATING CUE: The CRS has directed you to perform PT/1/A/4450/003 A (Annulus Ventilation System Train 'A' Operability Test).

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM G 2016 Systems - Control Room JPM G (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 9 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Restore Power to 6900V Buses JPM No.: 2016 Systems - Control Room JPM G K/A

Reference:

062 A2.05 (2.9/3.3)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• A total loss of Offsite Power has occurred to the Unit 1 Switchyard.

• Unit 1 tripped from 100% power.

• The Electrical Grid has remained energized throughout this event.

• Unit 1 has implemented AP/1/A/5500/07 (Loss of Electrical Power),

Case I (Loss of Normal Power to 1ETA and 1ETB).

• Power has been restored to the Unit 1 Switchyard.

• The crew is preparing to restore power to the 6900VAC Buses, and is complete through Step 43.p.

Initiating Cue:

• The CRS has directed you to restore power to the 6900V buses starting with Step 43.q of AP/1/A/5500/07 (Loss of Electrical Power),

Case I (Loss of Normal Power to 1ETA and 1ETB) using the Normal Supply breakers.

• Toddville has indicated that all Unit 1 Switchyard PCBs are available, and has given permission to close them as needed.

Task Standard: The operator will re-energize all four 6900V Buses per AP/1/A/5500/07 Steps 43.q-r.3.

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 3 of 9 Form ES-C-1 Job Performance Measure Worksheet Required Materials: None General

References:

AP/1/A/5500/07 (Loss of Electrical Power), Rev 36 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection), Rev 34 EP/1/A/5000/ES-0.1 (Reactor Trip Response), Rev 42 Handouts: Handout 1: Step 43 of Case I (Loss of Normal Power to Both 1ETA and 1ETB) of AP/1/A/5500/07 (Loss of Electrical Power) marked up for this JPM.

Time Critical Task: NO Validation Time: 7 minutes Critical Step Justification Step 1 This step is critical because pressing the CLOSE pushbutton for PCB8 AND pressing the CLOSE pushbutton for PCB12 are necessary to re-energize all four 6900V Buses per AP/1/A/5500/07 Steps 43.q-r.3.

Step 3 This step is critical because pressing the CLOSE pushbutton for 1TA, 1TB, 1TC and 1TD normal breakers are necessary to re-energize all four 6900V Buses per AP/1/A/5500/07 Steps 43.q-r.3.

Step 4 This step is critical because placing the 1TA, 1TB, 1TC, and 1TD Mode Select Switch to AUTO is necessary to re-energize all four 6900V Buses per AP/1/A/5500/07 Steps 43.q-r.3.

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 4 of 9 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset to IC-39 (100% Steady-state)

2. Insert the following malfunctions:

MALF-EP001 Station Blackout

3. Place Simulator in Run and acknowledge Annunciator Alarms.

4. Implement EP/1/A/5000/E-0, EP/1/A/5000/ES-0.1 and AP/1/A/5500/07, Case I through Step 43.n.

5. Stabilize plant.

6. Remove MALF-EP001

7. Insert LOA-EP172, 173 and 174 (Switchyard Lockout Reset).

8. Acknowledge alarms and Freeze the Simulator.

OR

1. Reset Simulator to Temporary Snap IC-248 (October, 2015).

NOTE: During the performance of the JPM, the Simulator Instructor will be required to acknowledge spurious alarms unrelated to the task being performed.

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

1 (Step 43.q) Close available PCBs as directed by Toddville TCC. The operator presses the CLOSE pushbutton for

• PCB8 PCB8 and observes the Red status light LIT and Green status light OFF (The 1A Transformer voltage will rise to 24KV).

The operator presses the

• PCB9 CLOSE pushbutton for PCB9 and observes the Red status light LIT and Green status light OFF.

The operator presses the CLOSE pushbutton for

• PCB11 PCB11 and observes the Red status light LIT and Green status light OFF (The 1B Transformer voltage will rise to 24KV).

The operator presses the

• PCB12 CLOSE pushbutton for PCB12 and observes the Red status light LIT and Green status light OFF.

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 2 (Step 43.r) WHEN busline energized, THEN energize The operator observes that 6900V busses as follows: Electrical Grid has remained energized (Step 43.r.1) Check throughout this event (Initial electrical grid - HAS Conditions), and proceeds.

REMAINED ENERGIZED DURING THIS EVENT.

• 3 (Step 43.r.2) Close the normal or standby breaker on de-energized busses: The operator presses the CLOSE pushbutton for 1TA

• 1TA normal breaker and observes the Red status light LIT, Green status light OFF.

The operator presses the

• 1TB CLOSE pushbutton for 1TB normal breaker and observes the Red status light LIT, Green status light OFF.

The operator presses the

• 1TC CLOSE pushbutton for 1TC normal breaker and observes the Red status light LIT, Green status light OFF.

The operator presses the

• 1TD. CLOSE pushbutton for 1TD normal breaker and observes the Red status light LIT, Green status light OFF.

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 7 of 9 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 4 (Step 43.r.3) Place the The operator places the mode select switches for 1TA Mode Select Switch to the following 6900V busses AUTO.

in auto:

The operator places the

• 1TA 1TB Mode Select Switch to

• 1TB AUTO.

• 1TC

• 1TD. The operator places the 1TC Mode Select Switch to AUTO.

The operator places the 1TD Mode Select Switch to AUTO.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM G Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM G NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• A total loss of Offsite Power has occurred to the Unit 1 Switchyard.

• Unit 1 tripped from 100% power.

• The Electrical Grid has remained energized throughout this event.

• Unit 1 has implemented AP/1/A/5500/07 (Loss of Electrical Power), Case I (Loss of Normal Power to 1ETA and 1ETB).

• Power has been restored to the Unit 1 Switchyard.

• The crew is preparing to restore power to the 6900VAC Buses, and is complete through Step 43.p.

INITIATING CUE:

• The CRS has directed you to restore power to the 6900V buses starting with Step 43.q of AP/1/A/5500/07 (Loss of Electrical Power), Case I (Loss of Normal Power to 1ETA and 1ETB) using the Normal Supply breakers.

• Toddville has indicated that all Unit 1 Switchyard PCBs are available, and has given permission to close them as needed.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet SIM JPM H 2016 Systems - Control Room JPM H (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 13 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Isolate the Circulating Water System JPM No.: 2016 Systems - Control During Turbine Building Flooding Room JPM H K/A

Reference:

075 A2.02 2.5/2.7 Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom Simulator X Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

Initial Conditions:

• With Unit 1 at 100% power, massive RC System Flooding occurred in the Unit 1 Turbine Building.

• The crew has implemented AP/0/A/5500/44 (Plant Flooding)

Enclosure 1 (Unit 1 Turbine Bldg Flooding), and an operator has just been dispatched to check the flood doors closed.

• The crew has just manually tripped the reactor.

• An operator has locally closed the breaker for 1RC-21.

• The U-1 Turbine Building Rounds AO (Bob) is standing by via radio.

Initiating Cue: The CRS has directed you to isolate the RC System by continuing with Enclosure 1 (Unit 1 Turbine Bldg Flooding) of AP/0/A/5500/44 (Plant Flooding), step 5.d, while the crew continues with EP/1/A/5000/E-0 (Reactor Trip and/or Safety Injection).

Task Standard: The operator will take actions to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 3 of 13 Form ES-C-1 Job Performance Measure Worksheet Required Materials: None General

References:

AP/0/A/5500/44 (Plant Flooding), Rev 18 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection), Rev 34 EP/1/A/5000/ES-0.1 (Reactor Trip Response), Rev 42 Handouts: Handout 1: AP/0/A/5500/44 (Plant Flooding) marked up for place-keeping through Step 3.

Handout 2: Enclosure 1 (Unit 1 Turbine Bldg Flooding) of AP/0/A/5500/44 (Plant Flooding) marked up for place-keeping through Step 5.c RNO c.3.

Time Critical Task: NO Validation Time: 12 minutes 2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 4 of 13 Form ES-C-1 Job Performance Measure Worksheet Critical Step Justification Step 1 This step is critical because depressing the Vacuum Breaker OPEN pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 2 This step is critical because depressing the 1A, 1B, and 1C RC Pump STOP pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 5 This step is critical because depressing the 1RC-5 CLOSE pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 6 This step is critical because depressing the 1RC-21 CLOSE pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 7 This step is critical because depressing the 1RC-79, 80 and 81 CLOSE pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 9 This step is critical because depressing the 1RC-9, 10, 11, 12, 13 and 14 CLOSE pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

Step 11 This step is critical because depressing the 1RC-15, 16, 17, 18, 19 and 20 CLOSE pushbutton is necessary to attempt to isolate the Unit 1 RC System in accordance with Enclosure 1 of AP/0/A/5500/44.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 5 of 13 Form ES-C-1 Job Performance Measure Worksheet SIMULATOR OPERATIONAL GUIDELINES

1. Reset simulator to IC-39, 100% Power

2. Place in RUN and allow time to stabilize

3. Override MCB Annunciator 1AD8/C4, TURB ROOM SUMP UNIT 1 HI-HI LEVEL to ON.

4. Manually trip reactor.

5. Complete EP/1/A/5000/E-0 through Step 6, and EP/1/A/5000/ES-0.1 through Step 16.

6. Close Breaker for RC-21.

7. Acknowledge all alarms.

8. Freeze the Simulator.

OR

1. Reset to Temp IC-249 (October, 2015).

2. Place Simulator in Run and acknowledge alarms/Reset SLIMS.

NOTE: Simulator Instructor will need to silence all alarms associated with the Reactor Trip response.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 6 of 13 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Ensure Handout 1 is placed on CRS Desk.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT Simulator Instructor NOTE: Leave Simulator in FREEZE until operator is ready to begin.

• 1 (Step 5.d) Open Main The operator depresses the condenser "VACUUM Vacuum Breaker OPEN BREAKER". pushbutton and observes the Red status light LIT, and Green status light OFF.

2 (Step 5.e) Stop the The operator depresses the following Unit 1 RC pumps: 1A RC Pump STOP

• 1A RC pump pushbutton and observes

• the Green status light LIT, and Red status light OFF (Amps indicate 0).

The operator depresses the

• 1B RC pump 1B RC Pump STOP

• pushbutton and observes the Green status light LIT, and Red status light OFF (Amps indicate 0).

The operator depresses the 1C RC Pump STOP

• 1C RC pump pushbutton and observes the Green status light LIT, and Red status light OFF (Amps indicate 0).

The operator observes the

• 1D RC pump 1D RC Pump Green status light LIT, and Red status light OFF (Amps indicate 0).

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 7 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 3 (Step 5.f) On Unit 1 OAC The operator calls up the RC graphic, check 1RC22 RC graphic on the OAC.

(U1 RC Crossover To U2 RC Disch Isol) OPEN. The operator observes that 1RC-22 is RED (open) on the RC Graphic.

4 (Step 5.g) Check 1RC-7 The operator observes the (U1 RC Crossover To U2 1RC-7 Red status light LIT, RC Supply Isol) - OPEN. and Green status light OFF (Or uses the RC Graphic on the OAC).

• 5 (Step 5.h) Press CLOSE The operator depresses the pushbutton for 1RC-5 (U1 1RC-5 CLOSE pushbutton RC Crossover Supply Isol). and observes the Green status light LIT, and Red status light OFF.

• 6 (Step 5.i) WHEN breaker for The operator observes the 1RC-21 is closed, THEN 1RC-21 Red status light press CLOSE pushbutton LIT, and Green status light for 1RC-21 (U1 RC OFF.

Crossover Disch Isol)

The operator depresses the 1RC-21 CLOSE pushbutton and observes the Green status light LIT, and Red status light OFF.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 8 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 7 (Step 5.j) Press CLOSE pushbutton on the following Unit 1 RC discharge gates:

• 1RC-79 (1A Main The operator depresses the Condenser Discharge 1RC-79 CLOSE Gate) pushbutton.

• 1RC-80 (1B Main The operator depresses the Condenser Discharge 1RC-80 CLOSE Gate) pushbutton.

The operator depresses the

• 1RC-81 (1C Main 1RC-81 CLOSE Condenser Discharge pushbutton.

Gate) 8 (Step 5.k) Record time. The operator records the time in the space provided.

• 9 (Step 5.l) Press CLOSE pushbutton for the following Examiner Note:

waterbox inlet valves:

The operator may NOT wait for these valves to complete stroking, prior to proceeding (Bulleted Sub-steps), The procedure checks their position later.

The operator depresses the

• 1RC-9 (1A1 Main 1RC-9 CLOSE pushbutton Condenser Waterbox and observes the Green Inlet Isol) status light LIT, and Red status light OFF.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 9 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 9

• 1RC-10 (1A2 Main The operator depresses the Condenser Waterbox 1RC-10 CLOSE pushbutton (Contd)

Inlet Isol) and observes the Green status light LIT, and Red status light OFF.

The operator depresses the

• 1RC-11 (1B1 Main 1RC-11 CLOSE pushbutton Condenser Waterbox and observes the Green Inlet Isol) status light LIT, and Red status light OFF.

• 1RC-12 (1B2 Main The operator depresses the Condenser Waterbox 1RC-12 CLOSE pushbutton Inlet Isol) and observes the Green status light LIT, and Red status light OFF.

• 1RC-13 (1C1 Main The operator depresses the Condenser Waterbox 1RC-13 CLOSE pushbutton Inlet Isol) and observes the Green status light LIT, and Red status light OFF.

• 1RC-14 (1C2 Main The operator depresses the Condenser Waterbox 1RC-14 CLOSE pushbutton Inlet Isol) and observes the Green status light LIT, and Red status light OFF.

10 (Note prior to Step 5.m) The operator reads the Waterbox isolation valves Note and proceeds.

take 1-2 minutes to close.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 10 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 11 (Step 5.m) CLOSE the following waterbox outlet valves:

The operator, after

• WHEN 1RC-9 is closed, observing the associated THEN close 1RC-15 Waterbox Inlet Valve Green (1A1 Main Condenser status light LIT, depresses Waterbox Outlet Isol). the associated Waterbox Outlet Valve CLOSE

• WHEN 1RC-10 is pushbutton and observes closed, THEN close the Green status light LIT, 1RC-16 (1A2 Main and Red status light OFF, Condenser Waterbox for each valve.

Outlet Isol).

• WHEN 1RC-11 is closed, THEN close 1RC-17 (1B1 Main Condenser Waterbox Outlet Isol).

• WHEN 1RC-12 is closed, THEN close 1RC-18 (1B2 Main Condenser Waterbox Outlet Isol).

• WHEN 1RC-13 is closed, THEN close 1RC-19 (1C1 Main Condenser Waterbox Outlet Isol).

• WHEN 1RC-14 is closed, THEN close 1RC-20 (1C2 Main Condenser Waterbox Outlet Isol).

12 (Step 5.n) Check 1RC-5 The operator observes the (U1 RC Crossover Supply 1RC-5 Green status light Isol) - CLOSED. LIT, and Red status light OFF.

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 11 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 13 (Step 5.o) Check 1RC-21 The operator observes the (U1 RC Crossover Disch 1RC-21 Green status light Isol) - CLOSED. LIT, and Red status light OFF.

14 (Step 5.p) Place 1RL-18 The operator places the (Unit 1 LT Coolers Control) 1RL-18 Controller in in manual and CLOSE. MANUAL, and adjusts so that 1RL-18 is CLOSED (Output = 0).

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Page 12 of 13 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - Control Room JPM H Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - Control Room JPM H NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• With Unit 1 at 100% power, massive RC System Flooding occurred in the Unit 1 Turbine Building.

• The crew has implemented AP/0/A/5500/44 (Plant Flooding)

Enclosure 1 (Unit 1 Turbine Bldg Flooding), and an operator has just been dispatched to check the flood doors closed.

• The crew has just manually tripped the reactor.

• An operator has locally closed the breaker for 1RC-21.

• The U-1 Turbine Building Rounds AO (Bob) is standing by via radio.

INITIATING CUE: The CRS has directed you to isolate the RC System by continuing with Enclosure 1 (Unit 1 Turbine Bldg Flooding) of AP/0/A/5500/44 (Plant Flooding), step 5.d, while the crew continues with EP/1/A/5000/E-0 (Reactor Trip and/or Safety Injection).

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet IN-PLANT JPM I 2016 Systems - In-Plant JPM I (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 10 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Transfer of 1EMXA-4 To SSF JPM No.: 2016 Systems - In-During A Loss Of All AC on Unit 1 Plant JPM I K/A

Reference:

055 EA2.03 (3.9/4.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

NOTE: Dispatch is from Aux Bldg side of CAD Door 509 Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• A Station Blackout has occurred at Unit 1.

• The crew is currently in EP/1/A/5000/ECA-0.0 (Loss of All AC Power).

• The CRS has dispatched an operator to the SSF to complete Enclosure 2 (Unit 1 SSF ECA-0.0 Actions).

Initiating Cue: The CRS has directed you to perform Enclosure 3 (Unit 1 ETA and ETB Rooms - ECA-0.0 Actions).

A PORTION OF THIS JPM IS TIME CRITICAL Task Standard: The operator will transfer 1EXMA-4 to its alternate power supply within 3 minutes from dispatch (Start of the JPM), and identify that the 1ETA2 Lockout Relay has tripped.

Required Materials: PPE (Hardhat, Safety Glasses, Hearing Protection, Safety Shoes etc.)

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 3 of 10 Form ES-C-1 Job Performance Measure Worksheet General

References:

EP/1/A/5000/ECA-0.0 (Loss of All AC Power), Rev 37 PT/0/A/4600/113 (Operator Time Critical Task Verification), Rev 20 Handouts: Handout 1: Blank Copy of Enclosure 3 (Unit 1 ETA and ETB Rooms -

ECA-0.0 Actions).

Time Critical Task: Yes - 3 Minutes from time of dispatch (See Enclosure 13.10 of PT/0/A/4600/113)

Seal injection from standby makeup pump can be initiated within 10 minutes of a loss of all AC power event or an App R fire event. This requires completion of actions at SSF to start SBMUP within 7 minutes of dispatch, and completion of actions in ETA room to swap EMXA-4 within 4 minutes of dispatch. To support the local actions, the following dispatches must be initiated: Operator dispatched to ETA room to swap EMXA-4 within 4 minutes of loss of all NCP seal cooling. (This ensures NV valve controls are swapped to SSF prior to operator at SSF aligning SBMUP. After dispatch, it takes 1 minute to get dosimetry and leave control room through side door, and 3 additional minutes from aux bldg door at MG set room to perform local action. Valve control will then be swapped to SSF 2 minutes before the operator at SSF must align and start SBMUP).

NOTE: Dispatch is from Aux Bldg side of CAD Door 509 Validation Time: 10 minutes Critical Step Justification Step 2 This step is critical because rotating the 1EMXA41A Breaker counterclockwise is necessary to transfer 1EXMA-4 to its alternate power supply within 4 minutes from dispatch.

Step 3 This step is critical because removing the Kirk Key from the 1EMXA41A Breaker is necessary to transfer 1EXMA-4 to its alternate power supply within 4 minutes from dispatch.

Step 4 This step is critical because inserting the Kirk Key in Breaker 1EMXA43A and rotating the 1EMXA43A Breaker clockwise is necessary to transfer 1EXMA-4 to its alternate power supply within 4 minutes from dispatch.

Step 5 This step is critical because observing the 1ETA2 Breaker and interpreting the meaning of the Breaker Handle is pointing towards 2 Oclock and an ORANGE target is visible at 12 Oclock is necessary to identify that the 1ETA2 Lockout Relay has tripped.

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 4 of 10 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Notes prior to Step 1) The The operator reads the fastest pathway to 1ETA Notes and proceeds.

room from Control Room is:

Exit Fire Door 926A (CAD 507) (Unit 1 Submarine Door to C/R Electrical Pen Rm; Elev. 767).

Emergency egress Fire Door 925E (CAD 509) (C/R Electrical Pen Rm; Elev. 767; Door to Unit 1 aux bldg stairway).

Enter cable room (from stairwell).

Enter 1ETA room through swgr AHU room.

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 5 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 2 (Step 1) At 1EMXA4 (located north wall 1ETA room), swap 1EMXA4 to its alternate power supply (SMXG) as follows:

(Caution prior to Step 1.a) It may be necessary to apply The operator reads the pressure on the breaker Caution, and proceeds.

rotary switch in the counterclockwise direction while opening the kirk key device(s).

The operator rotates the (Step 1.a) Open breaker 1EMXA41A Breaker

• 1EMXA41A (1EMXA4 counterclockwise.

Incoming Bkr (Normal)

From 1EMXA2 MCC).

Cue:

The Breaker is rotated counterclockwise.

• 3 (Step 1.b) Remove kirk key The operator removes the from 1EMXA41A. Kirk Key from the 1EMXA4 1A Breaker.

Cue:

The Kirk Key is removed.

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 6 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 4 (Step 1.c) Use kirk key and The operator inserts the Kirk close breaker 1EMXA43A Key in Breaker 1EMXA43A.

(1EMXA4 Incoming Bkr (Alternate) From SMXG Cue:

MCC).

The Kirk Key is inserted.

The operator rotates the 1EMXA43A Breaker clockwise.

Cue:

The Breaker is rotated clockwise.

Stop Time for Time Critical Step:

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 7 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 5 (Step 2) Check for tripped The operator observes the lockout relays on the 1ETA1 Breaker.

following cabinets in 1ETA Room: Cue:

• 1ETA1 (Normal There is NO Orange Target Incoming Bkr From visible.

1ATC Xfmr (6900/4160v))

The operator observes the

• 1ETA2 (Alternate 1ETA2 Breaker.

Incoming Bkr From SATA Xfmr Cue:

(6900/4160v))

There is an Orange Target visible.

The operator determines that the 1ETA2 Lockout Relay is tripped.

The operator observes the 1ETA15 Breaker.

Cue:

• 1ETA15 (1A Diesel There is NO Orange Target Generator Auxiliary visible.

Instrumentation for 1ETA14)

The operator observes the 1ERNCADGRC1A Breaker.

Cue:

• 1ERNCADGRC1A (D/G There is NO Orange Target Relay Cabinet 1A). visible.

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 8 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 6 (Step 3) Check for tripped The operator proceeds to lockout relays on the the 1ETB Room.

following cabinets in 1ETB Room: Cue:

• 1ETB1 (Normal Another operator has Incoming Bkr From checked the relays in 1ATD Xfmr 1ETB and reports to you (6900/4160v)) that none are tripped.

• 1ETB2 (Alternate Incoming Bkr From SATB Xfmr (6900/4160v))

• 1ETB15 (1B Diesel Generator Auxiliary Instrumentation for 1ETB14)

• 1ERNCADGRC1B (D/G Relay Cabinet 1B).

7 (Step 4) Notify Control The operator uses radio or Room Supervisor status of phone to inform CRS that relays checked above. ONLY the 1ETA2 Lockout Relay (Alternate Incoming Bkr From SATA Xfmr (6900/4160v)) is tripped.

Cue:

CRS acknowledges message and directs you to return to the control room.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Page 9 of 10 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - In-Plant JPM I Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - In-Plant JPM I NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• A Station Blackout has occurred at Unit 1.

• The crew is currently in EP/1/A/5000/ECA-0.0 (Loss of All AC Power).

• The CRS has dispatched an operator to the SSF to complete Enclosure 2 (Unit 1 SSF ECA-0.0 Actions).

INITIATING CUE: The CRS has directed you to perform Enclosure 3 (Unit 1 ETA and ETB Rooms - ECA-0.0 Actions).

A PORTION OF THIS JPM IS TIME CRITICAL NOTE: No plant equipment should be operated during the performance of this JPM. All actions must be SIMULATED.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet IN-PLANT JPM J 2016 Systems - In-Plant JPM J (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 10 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Locally Trip Unit 2 Main Turbine and JPM No.: 2016 Systems - In-Both Unit 2 FWPT's Plant JPM J K/A

Reference:

068 AA1.23 (4.3/4.4)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• A loss of control room has occurred. AP/2/A/5500/17 (Loss Of Control Room) has been implemented and is complete through step 10.b.

• You have been dispatched to standby at the Unit 2 Main Turbine.

• Communications have been established between you and the SRO at the Unit 2 Aux. Shutdown panel.

Initiating Cue: The SRO at the Unit 2 Aux. Shutdown panel has directed you to perform the local actions of Step 10.c.1-3 of AP/1/A/550/17 (Loss of Control Room).

Task Standard: The operator will trip the Unit 2 Main Turbine locally, and trip any of the available "trip" mechanisms on both FWPT's such that 2SP-1 and 2SP-2 are closed.

Required Materials: PPE (Hardhat, Safety Glasses, Hearing Protection, Safety Shoes etc.)

General

References:

AP/2/A/5500/17 (Loss of Control Room), Rev 25 2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 3 of 10 Form ES-C-1 Job Performance Measure Worksheet Handouts: Handout 1: Page 6 of 41 of AP/2/A/5500/17 (Loss of Control Room)

Time Critical Task: NO Validation Time: 10 minutes 2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 4 of 10 Form ES-C-1 Job Performance Measure Worksheet Critical Step Justification Step 2 This step is critical because manipulating the trip lever at front end standard to trip turbine is necessary to trip the Unit 2 Main Turbine locally.

Step 3 This step is critical because depressing the manual trip pushbutton on the supervisory panel, opening 2LP-4 and/or 14 on each FWPT supervisory panel, OR depressing the mechanical Trip Knob located at each FWPT's Governor Pedestal is necessary to trip both Unit 2 both FWPT's.

Step 4 This step is critical because rotating the handwheel for 2SP-1 and 2SP-2 in the clockwise direction is necessary to trip both Unit 2 both FWPT's.

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 5 of 10 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Step 10.c.1) Check all The operator observes the throttle valves - CLOSED. four throttle valves.

Cue:

Springs are contracted; yellow tape is NOT aligned on any of the Throttle Valves.

The operator determines the Turbine is NOT TRIPPED and informs SRO at Aux.

Shutdown panel that turbine is not tripped.

• 2. (Step 10.c.1 RNO) Trip The operator manipulates main turbine. trip lever at front end standard to trip turbine.

Cue:

Throttle Valve springs are expanded, yellow tape is aligned on each Throttle Valve.

The operator informs the SRO at the ASP that the Main Turbine is tripped.

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 6 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 3 (Step 10.c.2) Trip both Unit The operator proceeds to 2 CF pumps. the FWPTs then manually trips both turbines by:

Depressing the manual trip pushbutton on the supervisory panel.

Provide the appropriate Cue:

Pushbutton depressed, reset light is DARK, RPMs are decreasing.

OR Opening 2LP-4 and/or 14 on each FWPT supervisory panel.

Cue:

Handle lever rotated counterclockwise, reset light is DARK, RPMs are decreasing.

OR Depressing the mechanical Trip Knob located at each FWPT's Governor Pedestal.

Cue:

Mechanical Trip Knob at FWPTs Governor Pedestal depressed, reset light is DARK, RPMs are decreasing.

The operator informs the SRO at the ASP that both FWPTs are tripped.

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 7 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 4 (Step 10.c.3) CLOSE the The operator locates both following valves: valves.

2SP1 (Main Steam to 2A NOTE: The valve locations CF Pump Turb Isol) (Unit 2 are contained in the AP. If turbine bldg, 760+14, 2H the operator cannot locate 26, east of CF pump 2A) the valves and indicates that he/she would ask the SRO 2SP2 (Main Steam to 2B for further guidance then CF Pump Turb Isol) (Unit 2 give the location as a cue.

turbine bldg, 760+14, 2H 26, east of CF pump 2A).

Cue: (Only if needed) 2SP-1 (Main Steam to 1A CF Pump Turb Isol) (Unit 2 turbine bldg, 760+14, 2H 26, east of CF pump 2A)

Cue: (Only if needed) 2SP-2 (Main Steam to 2B CF Pump Turb Isol) (Main Steam to 2B CF Pump Turb Isol) (Unit 2 turbine bldg, 760+14, 2H26, east of CF pump 2A).

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 8 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT The operator rotates the handwheel for 2SP-1 in the

• 4 clockwise direction.

(Contd)

Cue:

The handwheel stops moving and the stem is fully in.

The operator rotates the handwheel for 2SP-2 in the clockwise direction.

Cue:

The handwheel stops moving and the stem is fully in.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Page 9 of 10 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - In-Plant JPM J Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - In-Plant JPM J NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• A loss of control room has occurred. AP/2/A/5500/17 (Loss Of Control Room) has been implemented and is complete through step 10.b.

• You have been dispatched to standby at the Unit 2 Main Turbine.

• Communications have been established between you and the SRO at the Unit 2 Aux. Shutdown panel.

INITIATING CUE: The SRO at the Unit 2 Aux. Shutdown panel has directed you to perform the local actions of Step 10.c.1-3 of AP/1/A/550/17 (Loss of Control Room).

NOTE: No plant equipment should be operated during the performance of this JPM. All actions must be SIMULATED.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet IN-PLANT JPM K 2016 Systems - In-Plant JPM K (Rev_031516) NUREG 1021, Revision 10

Appendix C Page 2 of 8 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Emergency Borate the Reactor JPM No.: 2016 Systems - In-Coolant System Locally Using 2NV- Plant JPM K 269 K/A

Reference:

APE 024, AA1.04 (3.6/3.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: X Actual Performance:

Classroom Simulator Plant X READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• Unit 2 was at 100% power when a Boron dilution event occurred.

• AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution) was entered.

• While attempting to open 2NV-265B (Boric Acid To NV Pumps), the RO discovered that 2NV-265B was de-energized.

Initiating Cue: The CRS has directed you to emergency borate the NC System by performing Step 12.d RNO of AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution).

A Portion of this JPM is TIME CRITICAL Task Standard: The operator will attempt to open 2NV-265B, and when this fails open 2NV-269 within ten (10) minutes of dispatch.

Required Materials: PPE (Hardhat, Safety Glasses, Hearing Protection, Safety Shoes etc.)

Dosimetry 2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Page 3 of 8 Form ES-C-1 Job Performance Measure Worksheet General

References:

AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution), Rev 11 PT/0/A/4600/113 (Operator Time Critical Task Verification), Enclosure 13.3 (Stop Dilution and Borate During a Dilution Event), Rev 20 Handouts: Handout 1: Step 12.d RNO (Page 8 of 19) of AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution) marked up for place-keeping.

Time Critical Task: YES - Enclosure 13.3 of PT/0/A/4600/113 Modes 1 and 2: Operators will stop dilution and initiate boration within 15 minutes. This may involve time critical local actions to open NV-265 or NV-269 (10 minutes from dispatch) per AP-38. Time starts when rods reach insertion limit (automatic rod control), or when reactor trips (manual rod control). (If you stop the dilution prior to going below rod insertion limit or reactor trip, emergency boration is not required.)

Only securing dilution within times above is required by the safety analysis, but UFSAR 15.4.6 states that operators can also initiate boration in these stated times. Operators will therefore be required to meet times for both securing dilution and initiating boration. The stated times are long enough for operators to perform actions. Note that UFSAR Section 15.4.6 states that operators have "at least 15 minutes" (Modes 1 and 2). The actual limiting times per UFSAR Table 15-19 are 16.6 minutes when rods are in manual (after trip), and 25.9 minutes when rods are in auto (after reaching rod insertion limit).

Validation Time: 8 minutes NOTE: Start this JPM from the hallway outside of the Ops kitchen area.

Record the Time Critical Completion Time (in JPM step number 2) when 2NV-269 is open.

Critical Step Justification Step 1 This step is critical because locating 2NV-265B, pressing downward on the Motor handwheel clutch, and rotating the handwheel in the counter-clockwise direction is necessary to attempt to open 2NV-265B.

Step 2 This step is critical because locating 2NV-269, removing the locking device, and rotating the handwheel in the counter-clockwise direction is necessary to manually open 2NV-269.

2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Page 4 of 8 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 1 (Step 12.d RNO) Perform The operator locates 2NV-the following: 265B, presses downward on the Motor handwheel clutch, (Step 12.d RNO 1) Dispatch and rotates the handwheel operator to OPEN 2NV- in the counter-clockwise 265B (aux bldg, 733+3, JJ- direction.

57, near chemical addition tank). Cue:

Handwheel clutch engaged Force applied in the counter clockwise direction Handwheel is NOT moving The operator recognizes that valve cannot be opened and continues.

2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Page 5 of 8 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 2 (Step 12.d RNO 2) IF 2NV- The operator locates 2NV-265B cannot be opened, 269, removes the locking THEN: device, and rotates the handwheel in the counter-

• (Step 12.d RNO 2.a) clockwise direction within Dispatch operator to unlock ten minutes of dispatch.

and open 2NV-269 (Unit 2 NV Pump Boric Acid Supply Isol) (aux bldg, 733+4, JJ- Cue:

58, near chemical addition tank). Lock removed, Handwheel rotated fully counter-clockwise.

Stop Time for Time Critical Task:

3 (Step 12.d RNO 2.b) OPEN The operator calls the 2NV-267A (Boric Acid To Control Room to report 2NV-Blender Control). 269 Open and requests that the BOP Open 2NV-267A.

Cue:

The Control Room operator acknowledges that 2NV-269 and 2NV-267A is open.

2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Page 6 of 8 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Step 12.d RNO 3) Do not The operator recognizes that continue until 2NV-265B or 2NV-269 is OPEN, and 2NV-269 flowpath above is indicates that the task is aligned. complete.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Page 7 of 8 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Systems - In-Plant JPM K Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Systems - In-Plant JPM K NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 2 was at 100% power when a Boron dilution event occurred.

• AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution) was entered.

• While attempting to open 2NV-265B (Boric Acid To NV Pumps), the RO discovered that 2NV-265B was de-energized.

INITIATING CUE: The CRS has directed you to emergency borate the NC System by performing Step 12.d RNO of AP/2/A/5500/38 (Emergency Boration and Response to Inadvertent Dilution).

A Portion of this JPM is TIME CRITICAL NOTE: No plant equipment should be operated during the performance of this JPM. All actions must be SIMULATED.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A1a RO 2016 Admin - JPM A1a RO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 10 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Complete a Surveillance for Mode JPM No.: 2016 Admin - JPM A1a Change RO K/A

Reference:

2.1.20 (4.6)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

Initial Conditions:

• Unit 1 is in Mode 4 during a plant startup.

• Current EFPD is 248.

• NC System pressure has stabilized at 1600 psig.

• Chemistry has reported that the CLA Boron Concentrations are as follows:

• CLA 1A - 2485 ppm

• CLA 1B - 2482 ppm

• CLA 1C - 2491 ppm

• CLA 1D - 2349 ppm

• It has become necessary to perform Enclosure 13.4, NC Boron Concentration Checklist, of PT/1/A/4600/003D, Monthly Surveillance Items, in order to continue with the plant startup.

Initiating Cue:

• The CRS has directed you to complete Enclosure 13.4, NC Boron Concentration Checklist, of PT/1/A/4600/003D, Monthly Surveillance Items.

• Identify any Flex Strategy Administrative Limits and/or Technical Specification LCOs that are not met.

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 3 of 10 Form ES-C-1 Job Performance Measure Worksheet Task Standard: The operator will complete Enclosure 13.4 of PT/1/A/4600/003D in accordance with the attached KEY, determine that all Flex Strategy Administrative Limits are met, and determine that LCO 3.5.1 is not currently met.

Required Materials: Calculator General

References:

PT/1/A/4600/003D (Monthly Surveillance Items), Rev 89 MCEI-0400-304 (McGuire Unit 1 Cycle 24 Core Operating Limits Report), Rev 0 McGuire Technical Specification LCO 3.5.1 (Accumulators), Amendment 218/200 Handouts: Handout 1: Blank copy of the body of PT/1/A/4600/003D, Monthly Surveillance Items and Enclosure 13.4, NC Boron Concentration Checklist.

Handout 2: McGuire Cycle 24 Core Operating Limits Report.

Time Critical Task: NO Validation Time: 15 minutes 2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 4 of 10 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Step 1, Bullet 1) Perform The operator recognizes the following: that the Surveillance is NOT being performed for the IF performing routine Monthly Surveillance and monthly surveillances, proceeds.

THEN 2 (Note prior to Step 1, Bullet The operator reads the

2) IF performing this Note and proceeds.

procedure in preparation for mode change, Enclosure 13.4 may be performed prior to Mode 3 however, this surveillance shall be met in Mode 3 prior to NC System pressure increasing to greater than 1000 psig.

• 3 (Step 1, Bullet 2) IF The operator records Mode performing this procedure 3 and Today (or prior to Mode 3 OR Unit in Equivalent), and proceeds.

Mode 3 prior to NC System pressure increasing greater than 1000 psig, THEN NOTE: The Date recorded record the following: is NOT critical.

Mode to be entered: _____

Date: _____

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 5 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Step 2) Check Boron Concentration of Cold Leg Accumulators within limits specified in COLR (Step 2.1) Record the following: The operator records 2485 in the 1A CLA space Cold Leg Accumulator 1A provided.

Cold Leg Accumulator 1B The operator records 2482 Cold Leg Accumulator 1C in the 1B CLA space Cold Leg Accumulator 1D provided.

The operator records 2491 in the 1C CLA space provided.

The operator records 2349 in the 1D CLA space provided.

• 5 (Step 2.2) Record Cold Leg The operator reviews the Accumulator limits as procedure and Section specified in COLR: 2.11.1 of the Unit 1 COLR and determines that based on a current EFPD of 248, (Min) ____________ ppmB the minimum required (Max) ____________ ppmB Accumulator Boron Concentration is 2475 ppm, and records this in the space provided.

The operator recognizes that the 1D CLA is less than that required by Tech Spec LCO 3.5.1.

The operator reviews the procedure and Section 2.11.1 of the Unit 1 COLR and determines that the maximum allowable Accumulator Boron Concentration is 2875 ppm, and records this in the space provided.

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 6 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 6 (Notes prior to Step 3) The The operator reads the FLEX Strategy CLA Notes and proceeds.

minimum Boron Concentration limit is a Beyond Design Basis External Event administrative limit and does NOT affect Tech Spec operability.

The FLEX Strategy Boron Concentration administrative limit for Cold Leg Accumulators is greater than 2400 ppmB.

7 (Step 3) Check FLEX CLA The operator recognizes Boron Concentration that the 1D CLA Boron administrative limit met Concentration is NOT greater than 2400 ppm, and (Step 3.1) IF all Cold Leg proceeds.

Accumulators Boron Concentration greater than 2400 ppmB, THEN.

• 8 (Step 3.2) IF only one Cold The operator records 1D in Leg Accumulator below the space provided.

2400 ppmB, THEN perform the following:

(Step 3.2.1) Record affected CLA: __________

• 9 (Step 3.2.2) Record The operator records 2349 affected CLA Boron in the space provided.

Concentration: __________

ppmB 2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 7 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 10 (Step 3.2.3) Determine The operator records 2485 average Boron in one space provided.

Concentration of the The operator records 2482 other three CLAs: in a second space provided.

[(__________ ppmB [1st The operator records 2491 CLA]) + (__________ in the third space provided.

ppmB [2nd CLA]) + The operator performs the

(__________ ppmB [3rd calculation and determines CLA])] ÷ 3 = ____ that the Average of the

[Avg of other CLAs] Other CLAs is 2486 ppm, and this value is recorded.

• 11 (Step 3.2.4) Determine The operator records 2349 average CLA Boron in the space provided for Concentration: the Affected CLA.

(_____________ ppmB The operator records 2486

[Affected CLA] + in the space provided for

______________ ppmB the Average of the Other

[Average of other CLAs]) ÷ 2 = CLAs.

_____________ ppmB The operator performs the

[Average CLA Boron Conc] calculation and determines that the Average CLA Boron Concentration is 2417.5 ppm, and this value is recorded.

• 12 (Step 3.2.5) IF Average The operator recognizes CLA Boron Concentration is that the Average CLA Boron greater than 2400 ppmB, Concentration is greater THEN this surveillance is than 2400 ppm, and met. concludes that the Surveillance (i.e. All Flex Strategy Administrative Limits) is met, and proceeds.

13 (Step 3.2.6) IF above The operator recognizes calculation is less than 2400 that this step is NOT ppmB, THEN. applicable, and proceeds.

14 (Note prior to Step 3.3) The operator reads the Steps 3.3.1 and 3.3.2 may Note and proceeds.

be performed concurrently.

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 8 of 10 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 15 (Step 3.3) IF more than one The operator recognizes CLA is less than 2400 that CLA 1A, 1B and 1C are ppmB, THEN. all greater than 2400 ppm, that this step is NOT applicable, and proceeds.

16 (Step 4) Initial one of the The operator leaves both following: bullets unsigned and hands off the Enclosure to the

• No Discrepancy CRS.

• Discrepancy Sheet Attached (IF any Acceptance Criteria NOT met, THEN it is identified as a discrepancy, evaluated per Tech Spec/SLC and appropriate corrective action taken.)

• 17 (Directed Action) Complete The operator recognizes Enclosure 13.4, NC Boron that the 1D CLA is less than Concentration Checklist, of that required by Tech Spec PT/1/A/4600/003D, Monthly LCO 3.5.1.

Surveillance Items.

Identify any Flex Strategy The operator recognizes Administrative Limits and/or that all Flex Strategy Technical Specification Administrative Limits are LCOs that are not met. met.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Page 9 of 10 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A1a RO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A1a RO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 is in Mode 4 during a plant startup.

• Current EFPD is 248.

• NC System pressure has stabilized at 1600 psig.

• Chemistry has reported that the CLA Boron Concentrations are as follows:

• CLA 1A - 2485 ppm

• CLA 1B - 2482 ppm

• CLA 1C - 2491 ppm

• CLA 1D - 2349 ppm

• It has become necessary to perform Enclosure 13.4, NC Boron Concentration Checklist, of PT/1/A/4600/003D, Monthly Surveillance Items, in order to continue with the plant startup.

INITIATING CUE:

• The CRS has directed you to complete Enclosure 13.4, NC Boron Concentration Checklist, of PT/1/A/4600/003D, Monthly Surveillance Items.

• Identify any Flex Strategy Administrative Limits and/or Technical Specification LCOs that are not met.

Are ALL Flex Strategy Administrative Limits and/or Technical Specification LCOs met?

If NOT, identify requirements NOT met:

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A1a SRO 2016 Admin - JPM A1a SRO (Rev_040616) NUREG 1021, Revision 10

Appendix C Page 2 of 9 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Determine Reportability JPM No.: 2016 Admin - JPM A1a Requirements SRO K/A

Reference:

2.1.18 (3.8)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• With Unit 1 at 100% power, the following occurred at 0800 today:

• The 1A1 KC Pump was declared inoperable due to a hot bearing.

• The crew entered the appropriate Technical Specification ACTION.

• At 1100 maintenance personnel determined that the pump could not be repaired within the required Completion Time.

• Just-In-Time training was held for the operating crew, and a Pre-Job Brief was conducted.

• A plant downpower was initiated at 1400 per OP/1/A/6100/003 (Controlling Procedure for Unit Operation)

• The SM has verified that this event has NOT exceeded an Emergency Action Level (EAL).

• No external persons and/or agencies have been notified of this event, nor have any actions other than those identified been taken.

Initiating Cue: The SM directs you to determine reportability requirements, including completion of any necessary paperwork.

2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 3 of 9 Form ES-C-1 Job Performance Measure Worksheet Task Standard: The operator will identify that this condition requires a 4-hour notification to the NRC in accordance with RP/0/A/5700/010 (NRC Immediate Notification Requirements), and to complete Enclosure 4.2 (NRC Event Notification Worksheet) in accordance with the attached Key.

Required Materials: None General

References:

RP/0/A/5700/010 (NRC Immediate Notification Requirements), Rev. 28 RP/0/A/5700/014 (Emergency Telephone Directory), Rev. 35 AD-LS-ALL-0006 (Notification/Reportability Evaluation), Rev 0 Job Aid of Reporting Regulation (Associated with AD-LS-ALL-0006)

Job Aid on Reportability Guidance and Operating Experience (Associated with AD-LS-ALL-0006)

Job Aid on Templates, Pre-Job Briefs and Guidance (Associated with AD-LS-ALL-0006)

Technical Specification 3.7.6 (Component Cooling Water (CCW)

System), Amendment 184/166 OP/1/A/6100/003 (Controlling Procedure for Unit Operation), Rev 197 Handouts: Handout 1: RP/0/A/5700/010 (NRC Immediate Notification Requirements).

Time Critical Task: NO Validation Time: 25 minutes NOTE: An Answer KEY is provided on Page 8 of this document.

2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 4 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Step 3.2) The Operations The operator reads the Step Shift Manager shall assure and proceeds.

the Notification requirements of this procedure are met for the reportable events provided in Enclosure 4.1.

• 2 (Step 3.3) Determine the The operator addresses appropriate notification Enclosure 4.1.

requirement and the reporting time requirement The operator recognizes using Enclosure 4.1, Events that Event Condition 4.1.3.1 Requiring NRC Notification. is applicable and that this event must be reported as soon as practical and within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of the occurrence.

2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 3 (Notes prior to Step 3.4) The operator reads the Security Reports should be Notes and proceeds.

reported per Nuclear Security Manual Directive 4.0 (Reporting and Trending of Safeguards and Security Events). The Security Shift Supervisor will provide all information to the Operations Shift Manager for the NRC Notification.

AD-LS-ALL-0006 and NUREG 1022 Revision 3, contain additional information and detail pertaining to reportability requirements of selected events.

MNS Regulatory Affairs Group, the Fleet Regulatory Affairs Organization AND the Community Relations Organization can provide support for completing Enclosure 4.2 (NRC Event Notification Work Sheet).

Sections of Enclosure 4.2 that are not applicable should be marked (N/A) 2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Step 3.4) Complete the The operator completes applicable portions of Enclosure 4.2 in

• Enclosure 4.2 as identified accordance with the (As by Enclosure 4.1. If being Attached Key.

shown completed for a drill write:

on KEY) "This is a Drill" on the first line of the event description. Cue:

Then transmit to the NRC Operations Center using After the Enclosure 4.2 is RP/0/A/5700/014, presented for transmittal, Enclosure 4.2. indicate that another operator will complete the required actions.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 7 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A1a SRO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION KEY: .2 NRC Event Notification Worksheet Page 1 of 2 All blocks left blank except as follows:

Notification Time/Date: (Left Blank)

Unit 1 Callers Name Operators Name Event Time and Zone 1400 (time)

Event Date Present Date Power/Mode Before 1 Power/Mode After 1 4-Hr Non-Emergency Check Mark in 4-Hr Non-Emergency (50.72(b)(2)(i) T/S Required S/D Event Description A plant shutdown required by Technical Specifications was initiated (or equivalent).

Notifications: NRC Resident NO or Will Be is checked Notifications: State NO or Will Be is checked Notifications: Local NO or Will Be is checked Notifications: Other Gov NO or Will Be is checked Agencies Notifications: Media/Press NO or Will Be is checked Release Anything Unusual or NOT NO is checked understood?

Did all Systems Function as YES is checked required Approved By: Leave Blank Time/Date: Leave Blank .2 NRC Event Notification Worksheet Page 2 of 2 All blocks left blank except as follows:

Event Description Continued from Page 1 ONLY IF NEEDED:

A plant shutdown required by Technical Specifications was initiated (or equivalent).

CRITICAL Information is in BOLD 2016 Admin - JPM A1a SRO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• With Unit 1 at 100% power, the following occurred at 0800 today:

• The 1A1 KC Pump was declared inoperable due to a hot bearing.

• The crew entered the appropriate Technical Specification ACTION.

• At 1100 maintenance personnel determined that the pump could not be repaired within the required Completion Time.

• Just-In-Time training was held for the operating crew, and a Pre-Job Brief was conducted.

• A plant downpower was initiated at 1400 per OP/1/A/6100/003 (Controlling Procedure for Unit Operation)

• The SM has verified that this event has NOT exceeded an Emergency Action Level (EAL).

• No external persons and/or agencies have been notified of this event, nor have any actions other than those identified been taken.

INITIATING CUE: The SM directs you to determine reportability requirements, including completion of any necessary paperwork.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A1b RO 2016 Admin - JPM A1b RO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 8 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Calculate the Boric Acid Addition for JPM No.: 2016 Admin - JPM A1b a specified Rod Change RO K/A

Reference:

2.1.25 (3.9)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-3.

Initial Conditions:

• Unit #1 Reactor Power is at 50%, Steady State.

• Core burnup is 125 EFPD.

• NC Boron Concentration = 950 PPM.

• Present Control Rod Height is Bank D at 165 steps.

• Desired Control Rod Height is Bank D at 210 steps.

Initiating Cue: The CRS has directed you to determine the amount of boric acid needed to obtain the desired Control Rod Height using the McGuire Unit 1 Data Book.

Task Standard: Boric Acid Addition of approximately 255.6 gallons is calculated in accordance with the attached KEY.

Required Materials: Calculator 2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Page 3 of 8 Form ES-C-1 Job Performance Measure Worksheet General

References:

OP/0/A/6100/006 (Reactivity Balance Calculation), Rev 77 OP/1/A/6100/022 (Unit 1 Data Book), Rev 481 MCEI-0400-304 (Unit 1 Cycle 24 Core Operating Limits Report), Rev 0 Handouts: Handout 1: OP/1/A/6100/022 (Unit 1 Data Book) Cycle 24, Enclosure 4.3 - Section 5.1 Boration and Dilution Tables Handout 2: OP/1/A/6100/022 (Unit 1 Data Book) Cycle 24, Enclosure 4.3 - Table 6.3.3 Integral Rod Worth in Overlap HFP, Equilibrium Xenon Handout 3: OP/1/A/6100/022 (Unit 1 Data Book) Cycle 24, Enclosure 4.3 - Graph 6.11 Differential Boron Worth (HFP, ARO, Eq Xe, Eq Sm)

Time Critical Task: NO Validation Time: 15 minutes 2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Page 4 of 8 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-3.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 1 Operator determines 165 Initial inserted reactivity steps integral rod worth worth =

using the 51-150 EFPD column of OP/1/A/6100/22, 153 pcm Enclosure 4.3, Table 6.3.3, IRW in Overlap, HFP, Equilibrium Xe.

• 2 Operator determines 210 Desired Rod height steps integral rod worth inserted reactivity worth =

using the 51-150 EFPD 15 pcm column of OP/1/A/6100/22, Enclosure 4.3, Table 6.3.3, IRW in Overlap, HFP, Equilibrium Xe.

• 3 Operator determines the Change in reactivity to be change in reactivity required compensated due to rod for the rod insertion insertion =

15 pcm

-153 pcm

-138 pcm

• 4 Using OP/1/A/6100/22, Operator determines the Enclosure 4.3, Graph 6.11 Differential Boron Worth Differential Boron Worth from the graph to be =

(HFP, ARO, Eq Xe, Eq Sm, -6.02 pcm/ppm (-5.95 to Unit 1 Cycle 24) determines -6.05 is acceptable) the Differential Boron Worth for present conditions (125 EFPD) 2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Page 5 of 8 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 5 Using the Differential Boron Operator determines the Worth and the Change in change in Boron reactivity, determines the Concentration to be =

change in Boron -138 /-6.02 pcm/ppm Concentration

22.9 ppm (22.8 to 23.2 is acceptable) 6 Operator determines Boron Change in Boron

Concentration required 950 + 22.9 ppm

= 972.9 ppm (972.8 to 973.2 is acceptable)

• 7 Using OP/1/A/6100/22, Using Present Boron Enclosure 4.3 Section 5.1 Concentration 950 ppm and Boron and Dilution Tables, the Desired Boron determines the Boric Acid Concentration of 972.9 addition ppm, determines from Table that change from 950-972.9 ppm will require the addition of 255.48 gallons of Boric Acid.

OR Calculation:

67388 x Ln(6050/6027.3) =

255.6 gallons.

(254.36 to 258.84 is acceptable)

See Attached Key Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Page 6 of 8 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A1b RO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Page 7 of 8 Form ES-C-1 VERIFICATION OF COMPLETION KEY:

Tables:

Page 12 of 20 Intersect Present Cb of 950 ppm with Desired Cb 970 ppm and determine 223 gallons.

Intersect Present Cb of 950 ppm with Desired Cb 980 ppm and determine 335 gallons.

335 gallons - 223 gallons = 112 gallons/10ppm = 11.2 gallons/ppm 223 gallons (at 970) + [11.2 gallons/ppm x 2.9 ppm] = 255.48 Calculation:

G = V x Ln [(C-Bi)/(C-Bf)]

Where:

G Volume of boric acid required for boration V Equivalent System Volume = 67388 Gallons (Constant)

C Concentration of Boric Acid being added = 7000 ppm (Constant)

Bi Present NCS Boron Concentration (ppm B)

Bf Desired NCS Boron Concentration (ppm B)

G = 67388 gallons x Ln [(7000 ppmB - 950 ppmB)/(7000-972.9 ppmB)]

G = 67388 gallons x Ln [(6050 ppmB)/(6027.1 ppmB)]

G = 67388 gallons x Ln [1.003766] = 255.55 gallons (254.36 to 258.84 is acceptable)

NOTE: The acceptable range is based on the operators ability to interpret OP/1/A/6100/22, Enclosure 4.3, Graph 6.11 Differential Boron Worth (HFP, ARO, Eq Xe, Eq Sm, Unit 1 Cycle 24). See JPM Step 4.

2016 Admin - JPM A1b RO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit #1 Reactor Power is at 50%, Steady State.

• Core burnup is 125 EFPD.

• NC Boron Concentration = 950 PPM.

• Present Control Rod Height is Bank D at 165 steps.

• Desired Control Rod Height is Bank D at 210 steps.

INITIATING CUE: The CRS has directed you to determine the amount of boric acid needed to obtain the desired Control Rod Height using the McGuire Unit 1 Data Book.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A1b SRO 2016 Admin - JPM A1b SRO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 13 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Calculate QPTR JPM No.: 2016 Admin - JPM A1b SRO K/A

Reference:

2.1.7 (4.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue and Current Power Range Detector Currents (Last Two Pages of this JPM), and Handouts 1-2.

Initial Conditions:

• The Unit 1 OAC failed and is not operating.

• The vendor is being consulted concerning repairs.

• It is estimated it will take approximately 15 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br /> to complete repairs.

• The crew has implemented PT/1/A/4600/021A (Loss of Operator Aid Computer while in Mode 1) and completed through step 12.15.

• Unit 1 is at 99% power and all Power Range Instruments are OPERABLE.

Initiating Cue:

• The CRS has directed you to calculate QPTR in accordance with Step 12.16 of PT/1/A/4600/21A (Loss of Operator Aid Computer while in Mode 1).

• Identify any required TS ACTION(s).

NOTE: Round all calculations to two (2) decimal places.

2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 3 of 13 Form ES-C-1 Job Performance Measure Worksheet Task Standard: The operator will calculate the QPTR (See Attached Key) and determine that the QPTR Technical Specification has been exceeded; Then identify the required TS ACTION (i.e. Power must be reduced to at least 94% within two hours, and ACTIONS A.2 through A.7 must be taken).

Required Materials: Calculator General

References:

PT/1/A/4600/021A (Loss of Operator Aid Computer while in Mode 1),

Rev 41 OP/1/A/6100/022 (Unit 1 Data Book - Cycle 24), Rev 481 McGuire Technical Specifications LCO 3.2.4 (Quadrant Power Tilt Ratio), Amendment 261/241 Handouts: Handout 1: PT/1/A/4600/021A (Loss of Operator Aid Computer while in Mode 1) marked up through step 12.15.

Handout 2: OP/1/A/6100/022 (MNS Unit #1 Data Book), Enclosure 4.3, Table 2.2 (Excore Currents and Voltages Correlated to 100% Full Power at Various Axial Offsets)

Time Critical Task: NO Validation Time: 25 minutes 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 4 of 13 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue and Current Power Range Detector Currents (Last Two Pages of this JPM), and Handouts 1-2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Step 12.16) The operator determines IF QPTR Alarm inoperable from initial conditions QPTR AND greater than 50% Alarm is inoperable, Unit 1 RTP, perform the following: is at 100% power and all PR channels are operable.

(Step 12.16.1)

IF all Power Range (PR) channel inputs to QPTR Operator proceeds to operable, calculate QPTR Enclosure 13.5 (Calculation on Enclosure13.5 Sheet for Quadrant Power (Calculation Sheet for Tilt) Part A.

Quadrant Power Tilt) Part A within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter until QPTR Alarm operable.

2 (Enclosure 13.5 Part A) The operator enters the Complete the Form current Date and Time at the top of the form.

2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 5 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 3 (Enclosure 13.5 Part A) The operator records the Measured Current - From correct amperage reading NI cabinets current meter for each detector (From the (located on respective PRB Handout provided) in the Drawers). Ensure Detector Measured Current row for Milliamp Range Switches each of the eight (8) are in 0.5 position and detectors as follows:

read 0-500 microamp scale. PR-41A = 295 PR-41B = 304 PR-42A = 299 PR-42B = 327 PR-43A = 299 PR-43B = 315 PR-44A = 285 PR-44B = 304

• 4 (Enclosure 13.5 Part A) The operator locates Calibration Current - From OP/1/A/6100/022, most recent calibration data Enclosure 4.3, Table 2.2, using 0 Incore Axial Offset Excore Currents and Current in Data Book, Table Voltages Correlated to 2.2 (IT for detector A, 100% Full Power at Various IB for detector B). Axial Offsets.

The operator records the correct amperage reading for each detector (Table 2.2) in the Calibration Current row for each of the eight (8) detectors as follows:

PR-41A = 133.0 PR-41B = 145.5 PR-42A = 125.2 PR-42B = 135.0 PR-43A = 131.3 PR-43B = 147.3 PR-44A = 129.8 PR-44B = 147.7 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 6 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 5 (Enclosure 13.5 Part A) The operator correctly Relative Flux (RF) - Divide calculates the average RF line 1 by line 2 to calculate and records the in the Relative Flux (RF) for each Relative Flux (RF) row for upper (A) and lower (B) each of the eight (8) detector. detectors as follows:

PR-41A = 295/133.0 = 2.22 PR-41B = 304/145.5 = 2.09 PR-42A = 299/125.2 = 2.39 PR-42B = 327/135.0 = 2.42 PR-43A = 299/131.3 = 2.28 PR-43B = 315/147.3 = 2.14 PR-44A = 285/129.8 = 2.20 PR-44B = 304/147.7 = 2.06

• 6 (Enclosure 13.5 Part A) The operator records the Quadrant Power Tilts: RF of each of the four (4) A Calculate by dividing each detectors and calculates the upper relative flux by the Avg RF of A Detectors as average upper relative flux follows:

and dividing each lower (2.22+2.39+2.28+2.20)/4 =

relative flux by the average 2.27 lower relative flux.

Avg RF of A Detectors

• 7 (Enclosure 13.5 Part A) The operator records the Quadrant Power Tilts: RF of each of the four (4) B Calculate by dividing each detectors and calculates the upper relative flux by the Avg RF of B Detectors as average upper relative flux follows:

and dividing each lower (2.09+2.42+2.14+2.06)/4 =

relative flux by the average 2.18 lower relative flux.

Avg RF of B Detectors 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 7 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 8 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-41A Tilt as follows:

Calculate by dividing each 2.22/2.27 = 0.98 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-41A Tilt

• 9 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-41B Tilt as follows:

Calculate by dividing each 2.09/2.18 = 0.96 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-41B Tilt

• 10 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-42A Tilt as follows:

Calculate by dividing each 2.39/2.27 = 1.05 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-42A Tilt

• 11 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-42B Tilt as follows:

Calculate by dividing each 2.42/2.18 = 1.11 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-42B Tilt 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 8 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 12 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-43A Tilt as follows:

Calculate by dividing each 2.28/2.27 = 1.00 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-43A Tilt

• 13 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-43B Tilt as follows:

Calculate by dividing each 2.14/2.18 = 0.98 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-43B Tilt

• 14 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-44A Tilt as follows:

Calculate by dividing each 2.20/2.27 = 0.97 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-44A Tilt

• 15 (Enclosure 13.5 Part A) The operator calculates the Quadrant Power Tilts: PR-44B Tilt as follows:

Calculate by dividing each 2.06/2.18 = 0.94 + .01 upper relative flux by the average upper relative flux And records this value.

and dividing each lower relative flux by the average lower relative flux.

PR-44B Tilt 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 9 of 13 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 16 (Technical Specification The operator refers to LCO 3.2.4) The QPTR shall be 3.2.4 and determines that

< 1.02. QPTR is NOT met.

The operator determines that power must be reduced (ACTION A.1) to at least 73% within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.

NOTE: (Highest QPTR is 1.11 on PR-42B; Reduce 3% from RTP (100%) for each 1% of QPTR > 1.02 (1.11-1.02 = 0.09 x 3% RTP x100%

QPTR/RTP))

The operator determines that ACTION A.2, A.3, A.4, A.5, A.6 and A.7 must be completed within the required COMPLETION TIME.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 10 of 13 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A1b SRO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Page 11 of 13 Form ES-C-1 VERIFICATION OF COMPLETION KEY:

Part A Page 1 of 4 PR-41 PR-42 PR-43 PR-44 A B A B A B A B Measured Current 295 304 299 327 299 315 285 304 Calibration Current 133.0 145.5 125.2 135.0 131.3 147.3 129.8 147.7 Relative Flux (RF) 2.22 2.09 2.39 2.42 2.28 2.14 2.20 2.06 Part A Page 2 of 4 Avg RF of A Detectors = 2.22 + 2.39 + 2.28 + 2.20 = 2.27 Avg RF of B Detectors = 2.09 + 2.42 + 2.14 + 2.06 = 2.18 PR-41A Tilt PR-41B Tilt RFA = RF of PR-41A = 2.22 0.98* RFB = RF of PR-41B = 2.09 0.96*

2.27 2.18 PR-42A Tilt PR-42B Tilt RFA = RF of PR-42A = 2.39 1.05* RFB = RF of PR-42B = 2.42 1.11*

2.27 2.18 PR-43A Tilt PR-43B Tilt RFA = RF of PR-43A = 2.28 1.00* RFB = RF of PR-43B = 2.14 0.98*

2.27 2.18 PR-44A Tilt PR-44B Tilt RFA = RF of PR-44A = 2.20 0.97* RFB = RF of PR-44B = 2.06 0.94*

2.27 2.18

• + .01 2016 Admin - JPM A1b SRO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET The following Detector Currents are observed on the NI cabinet current meters:

NI-41 detector:

A (left) 295 microamps B (right) 304 microamps NI-42 detector:

A (left) 299 microamps B (right) 327 microamps NI-43 detector:

A (left) 299 microamps B (right) 315 microamps NI-44 detector:

A (left) 285 microamps B (right) 304 microamps NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• The Unit 1 OAC failed and is not operating.

• The vendor is being consulted concerning repairs.

• It is estimated it will take approximately 15 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br /> to complete repairs.

• The crew has implemented PT/1/A/4600/021A (Loss of Operator Aid Computer while in Mode 1) and completed through step 12.15.

• Unit 1 is at 99% power and all Power Range Instruments are OPERABLE.

INITIATING CUE:

• The CRS has directed you to calculate QPTR in accordance with Step 12.16 of PT/1/A/4600/21A (Loss of Operator Aid Computer while in Mode 1).

• Identify any required TS ACTION(s).

NOTE: Round all calculations to two (2) decimal places.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A2 RO 2016 Admin - JPM A2 RO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 9 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Determine Leak Isolation JPM No.: 2016 Admin - JPM A2 Boundaries RO K/A

Reference:

2.2.41 (3.5)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

Initial Conditions:

• Unit 1 is operating at 100% power.

• Suspecting a leak in the Aux Building the crew entered Case II of AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps.

• An AO has just reported that there is a large packing leak on 1NV-151A (NV Pumps Recirculation Valve).

Initiating Cue: The CRS has directed you to:

• Identify the closest leak isolation boundary valves for this leak.

• Identify which, if any, of these valves need to be re-positioned from their current position.

• Identify the Breaker for any electrically operated leak isolation boundary valve that may need to be operated.

2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 3 of 9 Form ES-C-1 Job Performance Measure Worksheet Task Standard: The operator will review the Flow Diagram of Chemical and Volume Control System (NV) and determine the closest leak isolation boundary valves for this leak, review OP/1/A/6200/001E and determine the boundary valves that need to be re-positioned, and review OP/1/A/6200/001E and identify the Breaker for 1NV-150A in accordance with the Attached KEY.

Required Materials: None General

References:

AP/1/A/5500/10 (NC System Leakage Within the Capacity of Both NV Pumps), Rev 23 OP/1/A/6200/001 B (Chemical and Volume Control System Charging),

Rev 63 OP/1/A/6200/001 E (Chemical and Volume Control System Valve Checklists), Rev 34 MNS Drawing MCFD-1554-01.00 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 11 MNS Drawing MCFD-1554-01.01 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 11 MNS Drawing MCFD-1554-01.02 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 13 MNS Drawing MCFD-1554-01.03 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 4 MNS Drawing MCFD-1554-02.00 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 18 MNS Drawing MCFD-1554-02.01 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 6 MNS Drawing MCFD-1554-03.00 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 20 MNS Drawing MCFD-1554-03.01 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 24 MNS Drawing MCFD-1554-04.00 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 12 MNS Drawing MCFD-1554-05.00 (Flow Diagram of Chemical and Volume Control System (NV)), Rev 22 Handouts: Handout 1: Series of MNS Drawings - Flow Diagram of Chemical and Volume Control System (NV)

Handout 2: OP/1/A/6200/001 E (Chemical and Volume Control System Valve Checklists)

Time Critical Task: NO 2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 4 of 9 Form ES-C-1 Job Performance Measure Worksheet Validation Time: 30 minutes 2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 5 of 9 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 1 (Directed Action) Identify The operator will review the the closest leak isolation Flow Diagram of Chemical boundary valves for this and Volume Control System leak. (NV) and determine the closest leak isolation boundary valves for this leak are:

• 1NV-150B, NV Pumps Recirculation

• 1NV-148, Seal Wtr Filt

1. 1 Outlet Isol

• 1NV-152, SW Hx #1 Tube Inlet Isol

• 1NV-149, Seal Wtr Filter Byp

• 1NV-154, SW Hx #1 Byp See attached KEY 2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 6 of 9 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 2 (Directed Action) Identify The operator will review the which, if any, of these Flow Diagram of Chemical valves need to be re- and Volume Control System positioned from their current (NV) and/or position. OP/1/A/6200/001 E and determine that of these leak isolation boundary valves only the following valves must be re-positioned:

• 1NV-150B, NV Pumps Recirculation

• 1NV-148, Seal Wtr Filt

1. 1 Outlet Isol

• 1NV-152, SW Hx #1 Tube Inlet Isol See attached KEY

• 3 (Directed Action) Identify The operator will review the Breaker for any OP/1/A/6200/001 E and electrically operated leak determine that the Breaker isolation boundary valve for 1NV-150B, NV Pumps that may need to be Recirculation, is 1EMXB2-operated. F2C.

See attached KEY Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 7 of 9 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A2 RO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Page 8 of 9 Form ES-C-1 VERIFICATION OF COMPLETION KEY:

Closest leak isolation

• 1NV-150B, NV Pumps Recirculation boundary valves for this leak.

• 1NV-148, Seal Wtr Filt #1 Outlet Isol

• 1NV-152, SW Hx #1 Tube Inlet Isol

• 1NV-149, Seal Wtr Filter Byp

• 1NV-154, SW Hx #1 Byp Which, if any, leak

• 1NV-150B, NV Pumps Recirculation isolation boundary valves need to be re-

• 1NV-148, Seal Wtr Filt #1 Outlet Isol positioned from their

• 1NV-152, SW Hx #1 Tube Inlet Isol current position.

Breaker for any The Breaker for 1NV-150B, NV Pumps Recirculation, is electrically operated leak 1EMXB2-F2C.

isolation boundary valve that may need to be operated.

2016 Admin - JPM A2 RO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 is operating at 100% power.

• Suspecting a leak in the Aux Building the crew entered Case II of AP/1/A/5500/10, NC System Leakage Within the Capacity of Both NV Pumps.

• An AO has just reported that there is a large packing leak on 1NV-151A (NV Pumps Recirculation Valve).

INITIATING CUE: The CRS has directed you to:

• Identify the closest leak isolation boundary valves for this leak.

• Identify which, if any, of these valves need to be re-positioned from their current position.

• Identify the Breaker for any electrically operated leak isolation boundary valve that may need to be operated.

Closest leak isolation boundary valves for this leak.

Which, if any, leak isolation boundary valves need to be re-positioned from their current position.

Breaker for any electrically operated leak isolation boundary valve that may need to be operated.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A2 SRO 2016 Admin - JPM A2 SRO (Rev_031016) NUREG 1021, Revision 10

Appendix C Page 2 of 7 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Respond to a Fire Detection System JPM No.: 2016 Admin - JPM A2 Trouble Alarm SRO K/A

Reference:

2.2.40 (4.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

Initial Conditions:

• Unit 1 is in Mode 3 at normal operating temperature and pressure.

• Annunciator 1AD-13 E3, FIRE DET SYS ALERT, has alarmed.

• The crew has entered OP/0/A/6400/002F (Fireworks Fire Detection System), and is performing Enclosure 4.1 (Fire Detection System Alarm/Trouble).

• A check of Fire Alarm Control Panel (FACP) 1 shows that Zone 150 has a TROUBLE condition.

• It is subsequently determined that 3 non-adjacent detectors within Zone 150 are not FUNCTIONAL.

• Enclosure 4.1 of OP/0/A/6400/002F has been completed through Step 3.12.1.2.

Initiating Cue:

• Complete Step 3.12.1.3, and if necessary 3.12.1.4, of Enclosure 4.1 of OP/0/A/6400/002F.

• Identify any Technical Specification LCO/SLC required actions.

Task Standard: The operator will identify that SLC 16.9.6 ACTION is required, that Remedial Action Condition B is met, that the required ACTION must be performed in accordance with the attached KEY.

2016 Admin - JPM A2 SRO NUREG 1021, Revision 10

Appendix C Page 3 of 7 Form ES-C-1 Job Performance Measure Worksheet Required Materials: None General

References:

OP/1/A/6100/010 N (Annunciator Response for Panel 1AD-13), Rev. 78 OP/0/A/6400/002F (Fireworks Fire Detection System), Rev. 23 MNS SLC 16.9.6 (Fire Detection Instrumentation), Rev. 138 MNS Technical Specification LCO 3.6.5 (Containment Air Temperature),

Amendment 184/166 NSD 316 (Fire Protection Impairment and Surveillance), Rev. 17 OMP 5-16 (Electronic Fire Impairment Log), Rev. 7 Handouts: Handout 1: Full copy of OP/0/A/6400/002F with Enclosure 4.1 marked up through Step 3.12.1.2 Time Critical Task: YES. The SLC Action must be identified within 60 minutes.

Validation Time: 14 minutes 2016 Admin - JPM A2 SRO NUREG 1021, Revision 10

Appendix C Page 4 of 7 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 1 (Step 3.12.1.3) Determine if The operator proceeds to any zone in alarm or trouble Enclosure 4.2, Page 6 of 9, is SLC related. (Refer to and determines that Zone Encl. 4.2, Fire Detection 150 is SLC related.

System - Fire Zone Data.)

The operator proceeds to Step 3.12.1.4.

• 2 (Step 3.12.1.4) IF any zone The operator addresses in alarm is SLC related, SLC 16.9.6, Fire Detection notify CRS to evaluate SLC Instrumentation.

as appropriate.

The operator evaluates SLC Table 16.9.6-1 and determines that Zone 150 has five (5) Heat Detectors.

The operator evaluates SLC Table 16.9.6-1 and determines that Zone 150 detectors are Function A (early warning/notification) detectors.

The operator recognizes that 3 of the 5 detectors in Zone 150 are not FUNCTIONAL, and that Condition B is applicable.

2016 Admin - JPM A2 SRO NUREG 1021, Revision 10

Appendix C Page 5 of 7 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 3 (Directed Action) Identify The operator identifies the any Technical Specification following required ACTION:

LCO/SLC required actions.

B.1 Establish fire watch patrol to inspect zones outside containment with non-functional instruments, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND once per hour thereafter.

AND B.2.1 Establish a fire watch patrol to inspect zones inside containment with non-functional instruments, within 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 /> thereafter.

OR B.2.2 Monitor containment air temperature at the locations given in ITS 3.6.5.1 or 3.6.5.2, once per hour.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A2 SRO NUREG 1021, Revision 10

Appendix C Page 6 of 7 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A2 SRO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A2 SRO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Unit 1 is in Mode 3 at normal operating temperature and pressure.

• Annunciator 1AD-13 E3, FIRE DET SYS ALERT, has alarmed.

• The crew has entered OP/0/A/6400/002F (Fireworks Fire Detection System), and is performing Enclosure 4.1 (Fire Detection System Alarm/Trouble).

• A check of Fire Alarm Control Panel (FACP) 1 shows that Zone 150 has a TROUBLE condition.

• It is subsequently determined that 3 non-adjacent detectors within Zone 150 are not FUNCTIONAL.

• Enclosure 4.1 of OP/0/A/6400/002F has been completed through Step 3.12.1.2.

INITIATING CUE:

• Complete Step 3.12.1.3, and if necessary 3.12.1.4, of Enclosure 4.1 of OP/0/A/6400/002F.

• Identify any Technical Specification LCO/SLC required actions.

Technical Specification LCO/SLC required actions (If Any):

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A3 RO 2016 Admin - JPM A3 RO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 11 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Perform a Unit Vent Flow JPM No.: 2016 Admin - JPM A3 Calculation of a Containment Air RO Release K/A

Reference:

2.3.11 (3.8)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-3.

Initial Conditions:

• GWR Package # 2016013 for Unit 1 Containment Air Release is currently in use to conduct a series of Containment air releases.

• Three releases have been made.

• During the first release, conducted using Enclosure 4.2 (Air Release Mode With VQ Flow Monitor Operable) of OP/1/A/6450/017 (Containment Air Addition and Release), the Unit 1 VQ Monitor became inoperable.

• The crew stopped the release and continued the air release using Enclosure 4.3 (Air Release Mode with VQ Flow Monitor Inoperable) of OP/1/A/6450/017 (Containment Air Addition and Release), and recorded the release volume on the GWR paperwork.

• At 1743 on 4/4/16, containment pressure was 0.18 PSIG and another (4th) VQ release was initiated to reduce pressure to 0.12 PSIG per Step 3.9 of Enclosure 4.3.

• This release was secured at 1839 on 4/4/16 and the procedure was completed through step 3.9.1 for this 4th release.

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 3 of 11 Form ES-C-1 Job Performance Measure Worksheet Initiating Cue:

• You have been directed to calculate the volume released for the 4th release and complete all required paperwork starting with Step 3.9.2, AND, since this is the last release for GWR package 2016013, perform Steps 3.11.4 through 3.11.9 of Enclosure 4.3 to determine the total volume released from the Containment.

• The CRS notified RP (Mike Cline) at 1840 on 4/4/16 that the release has been terminated.

Task Standard: The operator will calculate the volume of air released from the Containment during the final release, and determine the total volume of air released in the series of four releases in accordance with the provided KEY.

Required Materials: Calculator General

References:

OP/1/A/6450/017 (Containment Air Release and Addition System), Rev 42 Handouts: Handout 1: Enclosure 4.2 (Air Release Mode With VQ Flow Monitor Operable) of OP/1/A/6450/017 (Containment Air Addition and Release) marked up as follows:

Step 2.1 - Initialed.

Step 2.2 - Initialed.

Step 2.3 - Initialed.

Step 2.4 - Initialed, GWR# 2016013 recorded.

Step 3.1 - Checkbox is checked.

Step 3.2 - Initialed.

Step 3.2.1 - Initialed and CV initialed.

Step 3.2.2 - Initialed and CV initialed.

Step 3.2.3-- Checkbox is checked Step 3.2.4 - Initialed and Mike Cline/Date/Time Recorded consistent with first release Date/Time (4/4/16 0903).

Step 3.3 - N/A and Initialed.

Step 3.4 -Initialed.

Step 3.5 - Initialed and CV initialed.

Step 3.6 - Initialed.

Step 3.7 - Initialed.

Step 3.8 - Initialed.

Step 3.8.1 - Checkbox is checked.

Step 3.8.2 - Checkbox is checked.

Step 3.8.3 - Initialed and CV initialed, VQ Monitor flow is recorded as 1236, and Actual Volume Released is recorded as 12,360.

Step 3.8.4 - All three Checkbox are checked.

Step 3.8.5 - Initialed.

Step 3.8.6 - Checkbox is checked.

Step 3.9.1 - Checkbox is checked.

Step 3.9.2 - Checkbox is checked.

Step 3.9.3 - Checkbox is checked.

Step 3.9.4 - Checkbox is checked.

Step 3.9.5 - Both Checkbox are checked.

Step 3.9.6 - Checkbox is checked.

Step 3.9.7-- Initialed.

Step 3.10 - Initialed.

Page 5 of 5 (Attachment 1) is marked up as follows: Sheet 1 of 1 2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 4 of 11 Form ES-C-1 Job Performance Measure Worksheet 1VQ-2B Open 1VQ-2B Closed Doer CV VQ Flow VQ Flow Date/Time Doer CV Date/Time Monitor Less Counting Than 300

() cfm ()

Initial Initial 4/4/16 0903 Initial Initial 4/4/16 1016 Handout 2: Enclosure 4.3 (Air Release Mode With VQ Flow Monitor Inoperable) of OP/1/A/6450/017 (Containment Air Addition and Release) marked up as follows:

Step 2.1 - Initialed.

Step 2.2 - Initialed.

Step 2.3 - Initialed.

Step 2.4 - Initialed, GWR# 2016013 recorded.

Step 3.1 - Checkbox is checked.

Step 3.2 - Initialed.

Step 3.2.1 - Initialed and CV initialed.

Step 3.2.2 - Initialed and CV initialed.

Step 3.2.3 -- Checkbox is checked.

Step 3.2.4 - Initialed and Person Notified/Date/Time Recorded consistent with first release Date/Time on Page 6 of 6.

Step 3.3 - NA and Initialed.

Step 3.4 - Initialed.

Step 3.5 - Initialed.

Step 3.6 - Initialed and CV initialed.

Step 3.7.1 - Checkbox is checked.

Step 3.7.2 - Checkbox is checked.

Step 3.7.3 - Checkbox is checked.

Step 3.7.4 - Both Checkbox are checked.

Step 3.7.5 - Initialed.

Step 3.7.6 - Initialed.

Step 3.8 - NA and Initialed.

Step 3.9 - Initialed.

Step 3.9.1 - Checkbox is triple-checked.

Step 3.9.2 - Checkbox is double-checked.

Step 3.9.3 - Double Initialed, and double CV initialed.

Step 3.10 - Initialed.

Page 6 of 6 (Attachment 1) is marked as follows: Sheet 1 of 1 1VQ-2B Open 1VQ-2B Closed Doer CV Date/Time Start Doer CV Date/Time Stop Ft3 Total Ft3 Pressure Pressure Released Released (psig) (psig)

Initial Initial 4/4/16 1117 0.22 Initial Initial 4/4/16 1258 0.12 21,740.17 21,740.17 Initial Initial 4/4/16 1432 0.20 Initial Initial 4/4/16 1547 0.12 15,747.32 37,487.49 Initial Initial 4/4/16 1743 0.18 Initial Initial 0.12 Handout 3: GWR Paperwork with 12360ft3 release volume from Enclosure 4.2 recorded.

Time Critical Task: NO Validation Time: 24 minutes 2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-3.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Enclosure 4.3, Step 3.9.2) The operator records 4/4/16 Record stop date/time on 1839 in the 1VQ-2B Closed Attachment 1 Date/Time Block of Attachment 1.

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 2 (Step 3.9.3) Calculate The operator uses Table volume released using the 4.3-1 of Enclosure 4.3 and following and record on determines X to be 17.31 Attachment 1. (Start Pressure of 0.18).

(Documentation of The operator uses Table calculation NOT required) 4.3-1 of Enclosure 4.3 and Cu. Ft. Released = X + determines Y to be 203.99 (YxZ) (Start Pressure of 0.18).

Where: The operator uses X and Y are from Table Attachment 1 of Enclosure 4.3-1 4.3 and determines Z to be 56 (Stop Time of 1839 -

Z is actual release duration Start Time of 1743).

in minutes from Attachment

1. The operator calculates volume released as follows:

• 17.31 + (203.99 x 56) =

11,440.75+/-0.5% (See KEY), and records this value in the 1VQ-2B Closed Cubic Ft Released Block of Attachment 1.

Examiner Cue:

If the operator is concerned about the completion of Steps 3.11.1-3, indicate that valves 1VQ-1A, 1VQ-2B and 1VQ-4 are CLOSED.

3 (Step 3.11.4) Ensure The operator ensures release stop date/time 4/4/16 1839 recorded in the recorded on Attachment 1. 1VQ-2B Closed Date/Time Block of Attachment 1.

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (Step 3.11.5) Notify RP that The operator recognizes release has been from the initial conditions terminated that RP has been notified.

5 (Step 3.11.6) Determine The operator adds the Total Cu. Ft Released on volume of this most recent Attachment 1. release (11,440.75) to the total previously released on Attachment 1 (37,487.49)

• and determines that the total volume released is 48,928.24 ft3 (See KEY).

The operator records this value in the 1VQ-2B Closed Total Cubic Ft Released Block of Attachment 1.

6 (Step 3.11.7) Record Total The operator records Cu. Ft Released from 48,928.24 (See KEY) in the Attachment 1:________ft3 1VQ-2B Closed Cubic Ft Released Block of Attachment 1.

• 7 (Step 3.11.8) IF any VQ The operator observes Totalizer readings recorded GWR paperwork and on GWR paperwork, determines that 12,360 ft3 perform the following: had been released when (Step 3.11.8.1) Determine the VQ Monitor was Total Volume Released as operable, and records this recorded on GWR value on Enclosure 4.3, paperwork. Step 3.11.8.2.

(Step 3.11.8.2) Record Total Volume Released from GWR: ____________

ft3.

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 8 (Step 3.11.9) Calculate The operator adds the total Total Volume Released for volume released recorded GWR as follows: in Step 3.11.7 (48,928.24) and the total volume released recorded in Step

____ ft3 + ____ ft3 = ____ ft3 3.11.8.1 (12,360), and Step 3.11.7 Step 3.11.8.2 Total Vol Rel determines the Total Volume Released for this series of Containment Air Releases is 61,288.24 ft3 (See KEY).

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 9 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A3 RO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION KEY: .3, Attachment 1:

RED = filled in at start of JPM.

GREEN = filled in during JPM performance 1VQ-2B Open 1VQ-2B Closed Doer CV Date/Time Start Doer CV Date/Time Stop Ft3 Total Ft3 Pressure Pressure Released Released (psig) (psig)

Initial Initial 4/4/16 1117 0.22 Initial Initial 4/4/16 1258 0.12 21,740.17 21,740.17 Initial Initial 4/4/16 1432 0.20 Initial Initial 4/4/16 1547 0.12 15,747.32 37,487.49 Initial Initial 4/4/16 1743 0.18 Initial Initial 4/4/16 1839 0.12 11,440.75 48,928.24 .3, Step 3.9.3 (JPM Step 2): Volume released, current release:

17.31 ft3 + (203.99 ft3/min x 56 min ) = 11,440.75 ft3 (11,383.55 - 11,497.95) .3, Step 3.11.6 (JPM Step 5): Total Volume released, during performance of .3:

11,440.75 ft3 + 37,487.49 ft3 = 48,928.24 ft3 (48,871.04 - 48985.44) .3, Step 3.11.9 (JPM Step 8): Total Volume released, during performance of GW Permit:

48,928.24 ft3 + 12360 ft3 = 61,288.24 ft3 (61,231.04 - 61,345.44) 2016 Admin - JPM A3 RO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• GWR Package # 2016013 for Unit 1 Containment Air Release is currently in use to conduct a series of Containment air releases.

• Three releases have been made.

• During the first release, conducted using Enclosure 4.2 (Air Release Mode With VQ Flow Monitor Operable) of OP/1/A/6450/017 (Containment Air Addition and Release), the Unit 1 VQ Monitor became inoperable.

• The crew stopped the release and continued the air release using Enclosure 4.3 (Air Release Mode with VQ Flow Monitor Inoperable) of OP/1/A/6450/017 (Containment Air Addition and Release), and recorded the release volume on the GWR paperwork.

• At 1743 on 4/4/16, containment pressure was 0.18 PSIG and another (4th) VQ release was initiated to reduce pressure to 0.12 PSIG per Step 3.9 of Enclosure 4.3.

• This release was secured at 1839 on 4/4/16 and the procedure was completed through step 3.9.1 for this 4th release.

INITIATING CUE:

• You have been directed to calculate the volume released for the 4th release and complete all required paperwork starting with Step 3.9.2, AND, since this is the last release for GWR package 2016013, perform Steps 3.11.4 through 3.11.9 of Enclosure 4.3 to determine the total volume released from the Containment.

• The CRS notified RP (Mike Cline) at 1840 on 4/4/16 that the release has been terminated.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A3 SRO 2016 Admin - JPM A3 SRO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 8 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Take On-Site Protective Actions JPM No.: 2016 Admin - JPM A3 During a General Emergency SRO K/A

Reference:

2.3.4 (3.7)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue and the List of Available Rescuers (Last two (2) Pages of this JPM), and Handout 1.

Initial Conditions:

• With Unit 1 shutting down due to failed fuel causing high NC System Activity, a LOCA Outside of Containment occurred.

• A Site Assembly is in progress in accordance with Enclosure 4.3 of RP/0/A/5700/011 (Conducting a Site Assembly, Site Evacuation or Containment Evacuation), and all personnel have NOT been accounted for.

• An RP Technician reports that an operator working with him in the 695 pipe chase has fallen and is severely injured. He has moved the injured person to an area that is somewhat shielded. Due to rapidly increasing dose rates, the RP Technician leaves to get help. He believes the injuries are life threatening. He also stated that the individual could be retrieved but it would take two people to do so.

• RP has been contacted and estimates it will take at least ten minutes to retrieve the victim.

• Dose rates at the area needing access are greater than 500 Rem/Hr.

• RP/0/A/5700/004 (General Emergency) is complete through Step 3.8.2.

2016 Admin - JPM A3 SRO NUREG 1021, Revision 10

Appendix C Page 3 of 8 Form ES-C-1 Job Performance Measure Worksheet Initiating Cue:

• As the Emergency Coordinator, perform Step 3.8.3 of RP/0/A/5700/004 (General Emergency) using the List of Available Rescuers in the Control Room.

• Complete Enclosure 4.4 up to the point that the rescuers are identified.

Task Standard: Select and dispatch two rescuers (Smith and Shelly) by completing Enclosure 4.4 of RP/0/A/5700/004 (General Emergency).

Required Materials: Calculator General

References:

RP/0/A/5700/004 (General Emergency), Rev 31 RP/0/A/5700/011 (Conducting a Site Assembly, Site Evacuation or Containment Evacuation), Rev 20 RP/0/A/5700/29, RP/0/A/5700/29 (Notification of Off-Site Agencies From the Control Room), Rev 17 AD-OP-ALL-1000 (Conduct of Operations), Rev 4 Handouts: Handout 1: Full copy of RP/0/A/5700/004, General Emergency, marked up as follows:

• Section 2 immediate actions are complete.

• Enclosure 4.1 and 4.2 actions are complete.

• Section 3 subsequent actions complete through Step 3.8.1 and 3.8.2.

Time Critical Task: NO Validation Time: 15 minutes 2016 Admin - JPM A3 SRO NUREG 1021, Revision 10

Appendix C Page 4 of 8 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue and the List of Available Rescuers (Last two (2) Pages of this JPM), and Handout 1.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (Step 3.8.3) Complete The operator reviews List of Enclosure 4.4 (Request for Available Rescuers in Emergency Exposure), prior Control Room and to dispatch of emergency determines qualification of workers if emergency potential rescuers.

situation precludes documentation.

• 2 (Enclosure 4.4.a) The operator determines Request for Emergency that Casey cannot be Exposure dispatched as a rescuer (Declared pregnancy)

• 3 (Enclosure 4.4.c) Only on a Operator determines that volunteer basis to persons Blade cannot be dispatched fully aware of the risks as a rescuer (Does NOT involved. All factors being Volunteer).

equal, select volunteers above the age of 45 and Operator determines that those who normally receive Mack cannot be dispatched little exposure. as a rescuer (Has too much Lifetime Exposure).

Operator determines that Leavy cannot be dispatched as a rescuer (Only STA - AD-OP-ALL-1000 Section 4.5.3 requires her in Control Room).

Operator determines that Baylor cannot be dispatched as a rescuer

(< 45 years Old).

2016 Admin - JPM A3 SRO NUREG 1021, Revision 10

Appendix C Page 5 of 8 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 4 (Enclosure 4.4) Request for The operator selects Smith Emergency Exposure and Shelly as rescuers, and completes Enclosure 4.4.

The operator enters the following information on Enclosure 4.4 for Smith:

• RP Badge # - 12579

• Name - Smith

• Age - 52

• Employer - Duke The operator enters the following information on Enclosure 4.4 for Shelly:

• RP Badge # - 12456

• Name - Shelly

• Age - 48

• Employer - Duke The operator requests Smith and Shelly to Read and Sign Enclosure 4.4.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

2016 Admin - JPM A3 SRO NUREG 1021, Revision 10

Appendix C Page 6 of 8 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A3 SRO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A3 SRO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET List of Available Rescuers in Control Room:

RP Name Gender/ Job Employer Current Lifetime Special Status Badge Age Assignment Exposure Exposure

1. (yr)

Would prefer not to 12345 Blade Male/ Maintenance Duke 1800 mR 5.2 R go/ Reports good 49 physical health 12456 Shelly Female/ Engineer Duke 45 mR 400 mR Volunteers/ Reports 48 good physical health 12567 Mack Male AO Duke 125 mR 35.4 R Volunteers/ Reports

/45 good physical health 12579 Smith Male/ Training Duke 6 mR 1.4R Volunteers/Reports 52 Supervisor good physical health 12110 Casey Female/ Security Duke 10 mR 65 mR Declared 32 Supervisor Pregnant/Volunteers/

Reports good physical health 12238 Leavy Female/ STA Duke 4 mR 120 mR Volunteers/Reports 46 (Only good physical Qualified health.

STA on Site) 12198 Baylor Male/ U2 BOP Duke 78 mR 1.7 R Volunteers/ Reports 34 good physical health NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• With Unit 1 shutting down due to failed fuel causing high NC System Activity, a LOCA Outside of Containment occurred.

• A Site Assembly is in progress in accordance with Enclosure 4.3 of RP/0/A/5700/011 (Conducting a Site Assembly, Site Evacuation or Containment Evacuation), and all personnel have NOT been accounted for.

• An RP Technician reports that an operator working with him in the 695 pipe chase has fallen and is severely injured. He has moved the injured person to an area that is somewhat shielded. Due to rapidly increasing dose rates, the RP Technician leaves to get help. He believes the injuries are life threatening. He also stated that the individual could be retrieved but it would take two people to do so.

• RP has been contacted and estimates it will take at least ten minutes to retrieve the victim.

• Dose rates at the area needing access are greater than 500 Rem/Hr.

• RP/0/A/5700/004 (General Emergency) is complete through Step 3.8.2.

INITIATING CUE:

• As the Emergency Coordinator, perform Step 3.8.3 of RP/0/A/5700/004 (General Emergency) using the List of Available Rescuers in the Control Room.

• Complete Enclosure 4.4 up to the point that the rescuers are identified.

NUREG 1021, Revision 10

Appendix C Job Performance Measure Form ES-C-1 Worksheet JPM A4 SRO 2016 Admin - JPM A4 SRO (Rev_031616) NUREG 1021, Revision 10

Appendix C Page 2 of 11 Form ES-C-1 Job Performance Measure Worksheet Facility: McGuire Task No.:

Task

Title:

Classify an Emergency Event JPM No.: 2016 Admin - JPM A4 SRO K/A

Reference:

2.4.41 (4.6)

Examinee: NRC Examiner:

Facility Evaluator: Date:

Method of testing:

Simulated Performance: Actual Performance: X Classroom X Simulator Plant READ TO THE EXAMINEE I will explain the initial conditions, which steps to simulate or discuss, and provide initiating cues. When you complete the task successfully, the objective for this Job Performance Measure will be satisfied.

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

Initial Conditions:

• Both Units were operating at 100% power.

• Due to severe weather several of the Unit 1 Control Room Annunciator Panels failed.

• The crew entered PT/1/A4600/033 (Loss of Control Room Annunciators), and has completed Enclosure 13.2 (Partial Loss of Annunciator Panels) through Step 3.5.

• Two additional off-shift operators have been assigned to observe annunciators associated with Time Critical Actions.

• The OAC became unavailable at the time of the Annunciator Panel loss.

• IAE has reported that it will take at least one hour to determine the extent of the damage.

• Computer Services has not responded yet.

• Unit 1 has tripped for reasons unknown.

• The crew entered EP/1/A/5000/E-0, Reactor Trip and/or Safety Injection, and verified that the immediate actions were completed as expected.

• The crew transitioned to EP/1/A/5000/ES-0.1, Reactor Trip Response, after verifying that all Critical Safety Functions were either GREEN or YELLOW.

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 3 of 11 Form ES-C-1 Job Performance Measure Worksheet Initiating Cue:

• Classify the Event in accordance with RP/0/A/5700/000 (Classification of Emergency).

• If more than one Emergency Action Level (EAL) has been exceeded, identify the EAL resulting in the Highest Emergency Classification.

• Then, prepare a Nuclear Power Plant Emergency Notification Form for the event, and present to the Emergency Coordinator for approval.

THIS IS A TIME CRITICAL JPM Task Standard: The operator will declare an ALERT based on 4.2.A.1, Unplanned Loss of Most or All Safety System Annunciation or Indication in Control Room With Either (1) a Significant Transient in Progress, or (2) Compensatory Non-Alarming Indicators Unavailable; and complete the pre-printed ENF 4.2.A.1 in accordance with the attached KEY.

Required Materials: Calculator General

References:

PT/1/A4600/033 (Loss of Control Room Annunciators), Rev 7 RP/0/A/5700/000 (Classification of Emergency), Rev 23 RP/0/B/5700/029 (Notifications to Offsite Agencies From the Control Room), Rev 17 OMP 4-3 (Use of Emergency And Abnormal Procedures and FLEX Support Guidelines), Rev 42 RP/0/A/5700/001 (Notification of Unusual Event), Rev 32 RP/0/A/5700/002 (Alert), Rev 32 RP/0/A/5700/003 (Site Area Emergency), Rev 33 RP/0/A/5700/004 (General Emergency), Rev 31 Handouts: Handout 1: PT/1/A4600/033 (Loss of Control Room Annunciators) marked up for this JPM.

Handout 2: RP/0/A/5700/000 (Classification of Emergency)

Handout 3: RP/0/B/5700/029 (Notifications to Offsite Agencies From the Control Room)

Handout 4: Blank copies of preprinted Nuclear Power Plant Emergency Notification Forms (Multiple Copies is needed)

Time Critical Task: YES - 15 minute to make classification, and THEN 15 minutes to complete ENF.

Validation Time: 18 minutes 2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 4 of 11 Form ES-C-1 PERFORMANCE INFORMATION (Denote Critical Steps with an asterisk*)

Provide Candidate with Initial Conditions/Cue (Last Page of this JPM), and Handouts 1-2.

START TIME:

STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 1 (OMP 4-3, Steps The operator enters 7.21.1/7.21.1.1) OSM RP/0/A/5700/000, Step 2.1.

Responsibilities Assume role of Emergency Coordinator upon activation of the Emergency Plan until properly relieved by the Station Manager.

2 (RP/0/A/5700/000, Note The operator reads the prior to Step 2.1) Note and proceeds.

Assessment, classification and declaration of any The operator refers to applicable emergency Enclosure 4.9 as needed.

condition should be completed within 15 minutes after the availability to indications or information to cognizant facility staff that an EAL threshold has been exceeded. (Refer to enclosure 4.9, Emergency Declaration Guidelines, as needed.)

3 (RP/0/A/5700/000, Step The operator enters 2.1) Determine operating determines that the plant mode that existed at the was in Mode 1 at the start time the event occurred of the event.

prior to any protection system or operator action initiated in response of the event.

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 5 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 4 (RP/0/A/5700/000, Step The operator recognizes 2.2) IF valid Security that this is NOT a valid Event,.. Security Event, that this Step is Not Applicable, and proceeds.

5 (RP/0/A/5700/000, Step The operator reviews 2.3) IF the plant was in Enclosure 4.1, and Mode 1-4 and a valid determines that no Loss or condition affects fission Potential Loss of a Fission product barriers, THEN ... Product Barrier exists per Enclosure 1, and proceeds.

6 (RP/0/A/5700/000, Step The operator reviews 2.4) IF a General Enclosure 4.2 through 4.7, Emergency is NOT and determines the declared in Step 2.3, OR following:

the condition does not affect fission product barriers, The operator reviews THEN review the listing of Enclosure 4.2 and enclosures to determine if determines that an ALERT the event is applicable to exists, based on 4.2.A.1, one of the categories Unplanned Loss of Most or shown. All Safety System Annunciation or Indication in Control Room With Either (1) a Significant Transient in Progress, or (2)

Compensatory Non-Alarming Indicators Unavailable.

[4.2.A.1-1 The following conditions exist:

Unplanned loss of most

(>50%) annunciators associated with safety systems for greater than 15 minutes.

AND In the opinion of the Operations Shift Manager/Emergency 2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 6 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 6 Coordinator/EOF Director, the loss of the annunciators (Contd) or indicators requires additional personnel (beyond normal shift compliment) to safely operate the unit.

AND EITHER of the following:

A significant plant transient is in progress.

OR Loss of the OAC.].

• 7 (RP/0/A/5700/000, Step The operator determines 2.5) IF Emergency Action that an ALERT exists, Level threshold has been based on 4.2.A.1, exceeded, THEN declare Unplanned Loss of Most or the appropriate Emergency All Safety System Classification. Annunciation or Indication in Control Room With Either (1) a Significant Transient in Progress, or (2)

Compensatory Non-Alarming Indicators Unavailable.

The operator records the event declaration time in Step 2.6.1.

Examiner Note: Record Time Critical Stop Time __________

NOTE that this time is also the Start Time for the 2nd Time Critical action of completing the pre-printed ENF 4.2.A.1.

Provide the operator with Handout 3 and Handout 4 (Pre-printed ENFs for EALs).

NOTE: A pre-printed form for the requested EAL must be provided (i.e. The operator may request an incorrect EAL form).

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 7 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT 8 (RP/0/A/5700/000, Step The operator proceeds to 2.6) Implement the RP/0/A/5700/002, applicable Emergency Immediate Actions.

Response Procedure (RP) for that classification and continue with subsequent steps of this procedure.

• Notification of Unusual Event RP/0/A/5700/001

• Alert RP/0/A/5700/002

• Site Area Emergency RP/0/A/5700/003

• General Emergency RP/0/A/5700/004.

9 (RP/0/A/5700/002, Note The operator proceeds to and IA Steps 2.1-2.2) The RP/0/A/5700/029, Immediate Actions and part Immediate Actions.

of the Subsequent Actions have been separated into position specific enclosures to enhance timely completion and consistent execution.

The following Enclosures should be given to the appropriate personnel:

The OSM should execute Enclosure 4.1 (OSM Immediate and Subsequent Actions) in a timely manner.

The STA should execute Enclosure 4.2 (STA Immediate and Subsequent Actions) in a timely manner.

Have an SRO make offsite notifications PER RP/0/B/5700/029 (Notifications to Offsite Agencies from the Control Room).

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 8 of 11 Form ES-C-1 PERFORMANCE INFORMATION STEPS ELEMENTS STANDARD S/U COMMENTS REQUIRED FOR UNSAT

• 10 (RP/0/A/5700/029, IA Step The operator proceeds to 2.1) For Initial Notifications, Enclosure 4.1 Step 1.

perform Enclosure 4.1 (Completion and The operator completes the Transmission of an Initial ALERT ENF by performing Notification Message). Steps 1-2.13 of Enclosure 4.1 in accordance with the attached KEY (See Page 10 of this JPM).

The operator presents the completed ENF Form to the Emergency Coordinator.

NOTE: The critical nature of this action is that the form is completed within 15 minutes.

Terminating Cue: Evaluation on this JPM is complete.

STOP TIME:

Critical TIME 1:

Critical TIME 2:

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 9 of 11 Form ES-C-1 VERIFICATION OF COMPLETION Job Performance Measure No.: 2016 Admin - JPM A4 SRO Examinees Name:

Date Performed:

Facility Evaluator:

Number of Attempts:

Time to Complete:

Question Documentation:

Result: SAT UNSAT Examiners Signature: Date:

2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Page 10 of 11 Form ES-C-1 VERIFICATION OF COMPLETION KEY:

Enclosure 4.1 Block How Completed Step #

2.1.1 Drill/Actual Event Operator checks A (Drill) is already shaded in.

2.1.2 Message # The operator enters 01 (or equivalent)

Note prior to Notification Time The operator leaves Blank Step 2.2 Note prior to Notification Date The operator leaves Blank Step 2.2 Note prior to Authentication # The operator leaves Blank Step 2.2 2.2 Initial/Follow-Up The operator checks A (Initial).

2.3.1 Site McGuire Nuclear Site is pre-recorded 2.3.2 Confirmation Phone # (704) 875-6044 is pre-recorded 2.4.1 Emergency Classification Operator checks B (ALERT) is already shaded in.

2.4.2 EAL # Operator checks 4.2.A.1 is already written in.

2.4.3 EAL Description Operator checks that the following statement is written in: Unplanned Loss of Most or All Safety System Annunciation or Indication in Control Room With Either (1) a Significant Transient in Progress, or (2)

Compensatory Non-Alarming Indicators Unavailable.

2.5.1 Protective Action Operator checks None is shaded in.

Recommendations 2.6.1 Emergency Release The operator checks A (None) 2.7.3 Release Significance The operator checks A (Not Applicable).

2.8 Event Prognosis The operator checks A (Improving) or B (Stable).

2.9.1 Wind Direction The operator leaves Blank 2.9.2 Wind Speed The operator leaves Blank 2.9.3 Precipitation The operator leaves Blank 2.9.4 Stability Class The operator leaves Blank 2.10.1 Declaration/Termination Operator checks A (Declaration) is shaded in.

2.10.2 Time/Date The operator records the Time recorded in JPM Step 7, and todays date.

2.11 Affected Unit(s) The operator checks U1 ONLY.

2.12 Unit Status The operator records that Unit 1 is at 0%

power, and shutdown within last 15 minutes, Today. The operator records that Unit 2 is at 100% power.

2.13 Remarks Left Blank or None recorded Critical Steps are identified in RED 2016 Admin - JPM A4 SRO NUREG 1021, Revision 10

Appendix C Form ES-C-1 JPM CUE SHEET INITIAL CONDITIONS:

• Both Units were operating at 100% power.

• Due to severe weather several of the Unit 1 Control Room Annunciator Panels failed.

• The crew entered PT/1/A4600/033 (Loss of Control Room Annunciators), and has completed Enclosure 13.2 (Partial Loss of Annunciator Panels) through Step 3.5.

• Two additional off-shift operators have been assigned to observe annunciators associated with Time Critical Actions.

• The OAC became unavailable at the time of the Annunciator Panel loss.

• IAE has reported that it will take at least one hour to determine the extent of the damage.

• Computer Services has not responded yet.

• Unit 1 has tripped for reasons unknown.

• The crew entered EP/1/A/5000/E-0, Reactor Trip and/or Safety Injection, and verified that the immediate actions were completed as expected.

• The crew transitioned to EP/1/A/5000/ES-0.1, Reactor Trip Response, after verifying that all Critical Safety Functions were either GREEN or YELLOW.

INITIATING CUE:

• Classify the Event in accordance with RP/0/A/5700/000 (Classification of Emergency).

• If more than one Emergency Action Level (EAL) has been exceeded, identify the EAL resulting in the Highest Emergency Classification.

• Then, prepare a Nuclear Power Plant Emergency Notification Form for the event, and present to the Emergency Coordinator for approval.

THIS IS A TIME CRITICAL JPM Emergency Classification:

NUREG 1021, Revision 10