Text

301 Draft Simulator Scenarios
	ML102371256
Person / Time
Site:	Watts Bar
Issue date:	08/25/2010
From:	; NRC/RGN-II
To:	; Tennessee Valley Authority
References
	50-390/08-301
	Download: ML102371256 (199)
	v • d • e

i 1

6oe ri Appendix D Scenario Outline Form ES-D-1]

Facility: Watts Bar Scenario No.: 1 Op Test No.: 1 Examiners: Operators:

Initial Conditions: 45% Power BOL.

1A Containment Spray Pump OOS for maintenance.

Turnover: The Plant is stable at 45% power following a forced outage to repair the 1A RCP seal. The plant has been at 45% power for 3 days while the 1A Main Feed Pump outboard motor bearing was being repaired. The 1A MFP has since been tested and has been placed in service. The crew is presently at GO-4 section 5.2 step

23. Plans are to commence a load increase toward 100% power in accordance with the reactivity plan. (Preconditioned power level is 100%).

Event MaIf. No. Event Event No. Type* Description 1 N/A R-RO Begin power ascension to 100%.

N-SRO/BOP 2 RW14A TS-SRO ERCW Pipe Break at IPS. Tech Spec evaluation.

C-BOP 3 NIO8A TS-SRO NIS Power Range instrument Channel I fails high and I-SRO requires RO to take rods to manual due to inadvertent insertion. Requires manual control of SG 1 and 4 levels by I RO BOP. Tech Spec evaluation.

4 THO3C C-ALL Small RCS leak develops inside containment requiring AOl-2% 6 entry. Tech Spec evaluation.

5 THO3C M-ALL RCS leak worsens, requiring a manual Reactor Trip and 50% Safety Injection.

6 RPO1 C R-RO ATWS requires RO to insert rods in manual after AUTO C-SRO/BOP rod speed slows to less than 48 steps per minute.

7 CSO3B C-BOP 1 B Containment Spray pump fails to start automatically.

C-SRO Requires manual start by BOP.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor 1s 1 L

<T Appendix D ce CQL.

J NUREG 1021 Revision 9

I Appendix D Scenario Outline Form ES-D-1 Scenario I Summary

1. Starting at 45% power at BOL, the crew will commence a power increase, by raising turbine load in accordance with GO-4, Normal Power Operation, section 5.2 step 23, and by adding positive reactivity in accordance with the reactivity plan. After small incremental power increases, the operators should verify plant response.

2. An Emergency Raw Cooling Water leak will develop at the Intake Pump Structure, requiring AOl-i 3 Loss of Emergency Raw Cooling Water, entry and actions by the BOP. This failure requires a Tech Spec evaluation by the SRO.

3. PR N41 fails high, requiring AOl-4 Nuclear Instrument Malfunction entry. This failure requires the RO to take control of control rods and the BOP to take control of Main Feedwater to #1 and #4 S/Gs. This failure requires a Tech Spec evaluation by the SRO.

4. A small RCS leak (50 gpm) develops, requiring entry into AOI-6 Small Reactor Coolant System Leak. This failure requires a Tech Spec evaluation by the SRO.

5. As the crew takes actions in AOl-6, the leak progresses to a small break LOCA, which requires a manual reactor trip.

6. When the crew initiates a reactor trip an ATWS occurs, which requires entry into FR-S.i.

Crew performs FR-S.i until a transition to E-0 is allowed.

7. When containment pressure reaches the containment pressure Phase B set point, the I B Containment Spray Pump fails to automatically start, which requires manual action by the BOP.

8. The crew transitions out of FR-S. 1, into E-0, then to E-1, then to ES-i .2.

9. The scenario terminates when the crew commences a plant cooldown toward cold shutdown, per ES-l.2.

Critical Tasks:

Insert negative reactivity using rods or boration prior to completion of FR-S.i Step 4.

Start a Containment Spray Pump prior to containment pressure exceeding 13.5 psig.

Appendix D NUREG 1021 Revision 9

CMit ied

[ Appendix D Scenario Outline Form ES-D-1 Facility: Watts Bar Scenario No.: 2 Op Test No.: 1 Examiners: Operators:

Initial Conditions: 100% Power MOL 1 B Centrifugal Charging Pump OOS for Maintenance.

Turnover: The plant is stable at 100% power, equilibrium Xenon. The plan is to reduce reactor power and turbine load in accordance with the reactivity plan and GO-4, Normal Power Operation, until #4 Governor Valve closes for Turbine Valve Testing. 1 B Centrifugal Charging Pump is OOS for motor bearing replacement. LCO 3.5.2 was entered 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ago.

Event MaIf. No. Event Event No. Type* Deschption 1 N/A R-RO Reduce power from 100%.

N -S RO/BO P 2 CCO7A TS-SRO 1A CCS Pump shaft shears. lB CCS pump fails to auto CCO3B C-BOP start on low pressure. Tech Spec evaluation.

3 ZDL1C68339 C-SRO 1-LIC-68-339 controller fails, resulting in 1-FCV-62-93, C-RO Charging Flow Control Valve, closing.

4 FWO5B TS-SRO MFP B Trip from low bearing oil pressure results in plant FW98 C-BOP runback.

Standby MFP fails to auto start, requiring SOP to manually start pump.

5 FW2O M-AIl FW line leak on common feed line in Turb Bldg progresses to a FW line rupture, requiring entry into the EOP network.

6 FW22B C-SRO/BOP MDAFW Pump 1 B-B becomes airbound. May be restored by venting pump casing.

7 FW65 C-SRO/BOP TD AFW Pump shaft shears and cannot be repaired.

8 EDO6A C-SRO 1A 6.9kv Shutdown Board differential fault 5 mm after Rx C-RO trip results in loss of second charging pump, and loss of MDAFW pump lA-A. Results in loss of all feedwater flow BOP to S/Gs and ultimately RCS feed and bleed due to loss of secondary heat sink with both charging pumps unavailable.

(N )ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Scenario 2 Summary

1. The crew commences a plant load reduction in accordance with GO-4 to support turbine valve testing.

2. 1A Component Cooling System (CCS) pump shaft shears, 1 B CCS pump fails to start on low header pressure. The crew (BOP) enters AOl-i 5 Loss of Component Cooling Water, to restore CCS. This failure requires a Tech Spec evaluation by the SRO.

3. 1-LIC-68-339, PZR Level Master Controller, fails, resulting in 1-FCV-62-93 Charging Flow Control Valve closing. The RO operator takes manual control of charging flow per ARI-1 08A Charging Flow Low and/or AOl-i 1 OA Regen HX LTDN Temp Hi.

4. 1A Main Feed Pump (MFP) trips on lube oil leak to a pressure transmitter (small leak in sensing tubing, not causing any environmental concerns). Standby MFP fails to automatically start, requiring the BOP to manually start the Standby MFP. The crew enters AOl-i 6 Loss of Normal Feedwater in response to the plant runback. This failure requires crew actions to restore Axial Flux Difference (AFD) and an AFD Tech Spec evaluation by the SRO, following the runback.

5. A feedwater line rupture develops on the common line in the turbine building, requiring entry into AOI-38 Main Steam or Feedwater Line Break. The crew diagnoses and initiates a reactor trip.

6. Immediately after Aux Feed Water actuation, the 1 B Motor Driven Aux Feed Water Pump becomes steam bound requiring the BOP to shutdown the pump and request an AUO to vent the pump. Additionally, the Turbine Driven AFW pump shaft shears one minute after it starts, preventing its use. This leaves the crew with only one AFW feed source, the 1A MDAFWP. The crew goes to ES-O.1 at E-O step 4.

7. Five minutes after the reactor trip a differential overcurrent occurs on the 1A 6.9 KV SD Board. This gives the crew a RED path on Heat Sink status tree.

8. The crew enters FR-H.1 Loss of Secondary Heat Sink, and immediately initiates RCS bleed and feed due to the loss of both CCPs (1 B COP OOS from turnover and the 1A COP lost when thelA SD Board trips).

9. Terminate the scenario when crew restarts 1 B MDAFW pump after venting and establishes flow to one selected S/G per FR-H.1, Step 30.

Critical Tasks:

Initiate ROS feed and bleed so that the RCS depressurizes sufficiently for intermediate head injection to occur.

Establish feedwater flow from AFW prior to exiting FR-H.1.

Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Facility: Watts Bar Scenario No.: 3 Op Test No.: 1 Examiners: Operators:

Initial Conditions: Plant is at 97% power MOL, following turbine valve testing.

1A Motor Driven Auxiliary Feedwater Pump OOS for maintenance.

Turnover: Main Turbine valve testing was just completed, and a load escalation is to be conducted, per the reactivity plan back to 100% load. The plant is at MOL with the 1A Motor Driven Auxiliary Feedwater Pump OOS for maintenance.

Event MaIf. No. Event Event No. Type* Description 1 N/A N-BOP/SRO Raise load to 100%.

R-RO 2 RXO2A TS-SRO Loop 1 Cold Leg RTD fails high, resulting in rod insertion.

1-RO Tech Spec evaluation.

3 RM9O1O6A 1-BOP 1-RM-90-106 LWR Comp Rad Monitor instrument TS-SRO malfunction occurs. Tech Spec evaluation.

4 FWO3B TS-SRO #3 HDT lB trips. When BOP runback initiates, auto RPO3 C-BOP runback fails. BOP manually reduces load. Tech Spec evaluation.

5 MSO1C M-ALL Main Steam line leak on #3 SIG inside containment which ramps to 10% over 5 minutes. Requires entry into the EOP network.

6 MS28C C-BOP #3 MSV fails to auto close. Requires manual actuation by BOP.

7 CSO5 1-BOP Failure of Phase B to automatically actuate. Requires I-SRO manual actuation by BOP.

(N)ormal, (R)eactivity, ( l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Scenario 3 Summary

1. The plant is at MOL with the 1A Motor Driven Auxiliary Feedwater Pump OOS for maintenance. Reactor power is approximately 97% and Main Turbine valve testing was just completed. The crew commences a plant load increase in accordance with GO-4 to 100%.

2. Loop 1 Cold leg RTD fails high, requiring entry into AOl-2 Malfunction of the Reactor Control System. The RO takes manual control of control rods and the SRO performs a Tech Spec evaluation.

3. RM-90-106 fails low, requiring entry into ARI-173E Lower CTMTA1r 1-RM-90 -106 Instrument Malfunction. This failure requires Tech Spec evaluation by the SRO.

4. #3 HDT 1 B trips, requiring actions per ARI-49E Main/Stby Feedwater Pump Suction NPSH Low. The crew diagnoses a failure of the automatic turbine runback circuit and the BOP manually reduces turbine load in accordance with AOI-37, Turbine Runback Response. This failure requires a Tech Spec evaluation by the SRO due to AFD post runback.

5. A Main Steam leak develops on the #3 SIG, and progresses to a 10% break inside containment over 5 minutes. Requires a manual reactor trip.

6. When SI actuates, the #3 MSIV fails to automatically close, requiring manual action by the BOP to close.

7. When containment conditions exist for a Phase B, both trains fail to automatically initiate, requiring BOP action.

8. The crew will enter E-0, transition to E-2, and then to ES-I .1. The scenario will be terminated when the SI pumps are secured and placed in automatic in accordance with ES-i .1.

Critical Tasks:

Isolates faulted S/G prior to transition from E-2:

o Isolates AFW flow.

o Ensures MEW isolated.

o Ensures PORV is closed.

o Ensures blowdown isolated.

Manually initiate Phase B prior to containment pressure exceeding 13.5 psig.

Appendix D NUREG 1021 Revision 9

( rii 7 C(in se Appendix D Scenario Outline Form ES-D-1 Facility: Watts Bar Scenario No.: Spare Op Test No.: 1 Examiners: Operators:

Initial Conditions: 2% power at BOL, no equipment OOS. Preparing for power escalation and mode change.

Turnover: The plant is at BOL and a startup from a forced outage is in progress to repair an EHC high pressure piping leak. Power is currently stable at 2%, awaiting the Operations Superintendent to grant approval to proceed to Mode 1. The crew is currently in GO-3 Unit Startup From Less Than 4% Reactor Power to 30% Reactor Power section 5.2 step 14. The crew is then expected to raise reactor power to between 13% and 15%, per GO-3 Section 5.3.

Event MaIf. No. Event Event No. Type* Description 1 N/A R-RO Raise reactor power to between 13% and 15%.

N-SRO/BOP 2 ZAIPIC133 C-BOP/SRO 1-PIC-1-33 Steam Pressure Controller fails, closing the 0% steam dumps. Requires manual action by BOP to restore RCS temperature.

3 CCO5D C-SRO/BOP 005 leak inside containment on thermal barrier supply line.

4 ZA1P1C68340 C-RO 1 -PIC-68-340A PZR Master Controller fails, causing full RCRO5 TS-SRO spray and minimum heaters, requiring RO to take manual control of 1 -PIC-68-340A to close spray valves and energize heaters. Tech Spec evaluation, due to RCS pressure going below DNB Spec.

5 THO5A C-ALL S/G tube leak at 25 gpm. Tech Spec evaluation.

5% TS-SRO 6 CVO1A C-SROIRO IA CCP breaker trips on overcurrent. Requires immediate TS-SRO start of 1 B CCP due to the previous loss of CCS to the thermal barriers. Tech Spec evaluation.

7 THO5A M-ALL S/G tube leak progresses to a SIG tube rupture, requiring 35% entry into the EOP network.

8 ZDIRT 1 1-RO Reactor Trip Switch on 1-M-4 fails to initiate a reactor trip.

NEUTRAL RO must operate 1-M-6 trip switch.

9 MSO4A C-BOP/SRO #1 S/G MSIV will not close, requiring contingency actions in E-3 to be performed.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

rAppendix D Scenario Outline Form ES-D-1 Spare Scenario Summary

1. The plant is at BOL with reactor power at approximately 2%. The crew commences a power increase by adding positive reactivity in accordance with the reactivity plan.

2. With the steam dumps in the steam pressure mode, 1-PIC-1-33 Steam Pressure Controller fails, causing the steam dumps to close. Tave rises and eventually alarm window 94A Tave Tref Deviation will annunciate, requiring manual action by SOP to restore RCS temperature.

3. CCS leak occurs in containment on the supply line to the 1 D RCP Thermal Barrier. The crew enters AOl-i 5 Loss of Component Cooling Water. Requires BOP actions to isolate the leak.

This failure requires a Tech Spec evaluation by the SRO.

4. i-PIC-68-340 PZR Master Pressure Controller automatic control signal fails high, resulting in full spray flow and minimum heaters. This failure requires entry into AOl-i 8 Malfunction of the Pressurizer Control System and actions by the RO to take manual control of the 1-PlC-68-340. This failure requires a Tech Spec evaluation by the SRO. Due to the response of the plant, RCS pressure will initially lower to below the DNB specification.

5. #1 SIG tube leak at 25 gpm occurs, requiring AOI-33 Steam Generator Tube Leak entry.

This failure requires a Tech Spec evaluation by the SRO.

6. 1A CCP breaker trips on overcurrent. The crew takes action per alarm window 108A Charging Flow Low, which requires immediate start of 1 B CCP by the RO, due to the previous loss of CCS to the thermal barriers. This failure requires a Tech Spec evaluation by the SRO.

7. #1 SIG tube leak progresses to SIG tube rupture, requiring a reactor trip and safety injection.

8. When a reactor trip is attempted from 1 -M-4 the trip switch fails, requiring the initiation of the trip from 1-M-6 by the RO.

9. The crew enters E-0 and later transitions to E-3. While in E-3, when isolation of the ruptured SIG is attempted, the #1 SIG MSIV will not close, requiring contingency actions in E-3 to be performed.

10. The scenario ends when the crew has stabilized RCS temperature at the target temperature, in accordance with E-3.

Critical Tasks:

Isolate steam flow and feedwater flow to the ruptured SIG prior to initiation of RCS cooldown to the target temperature.

Cooldown RCS to less than or equal to the target temperature prior to RCS depressurization.

Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1 Facility: Watts Bar (2008-B) Scenario No.: 1 Op Test No.: 1 Examiners: 0 erators:

DKAF Initial Conditions: 75% power, 1305 ppm boron (BOL). 1A MD AFW Pump is out of service for pump bearing replacement. LCO 3.7.5.b was entered 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ago. Pump is expected to be returned to service in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months . 1 B MFP tripped 5 days ago, and power has been maintained at 75% while repairs were completed. The 1 B MFP was started late during the last shift. Currently, the 1A MFP, 1 B MFP, and Standby MFPs are in service.

Turnover: Shutdown Standby MFP per SOl-2&3.01. Then, perform power escalation using GO-4, Section 5.2 at 3%/hour.

Event MaIf. No. Event Event No. Type* Description 1 N/A N BOP

- Shutdown Standby MFP.

N SRO 2 N/A R RO- Perform power escalation.

N SRO N - BOP 3 RX2O I - BOP 1-PT-1-33 Main Steam Header Pressure transmitter fails low.

I - SRO BOP takes manual control of the MFP Master Controller. AOl -16 entry.

4 RXO5 I - RO 1-LT-68-339 fails high (charging flow and RCP seal injection I - SRO flows lower). AOl-20 entry. Tech Spec evaluation.

TS- SRO 5 CHO1 D TS - SRO Containment Pressure transmitter PDT-30-45 fails high; Tech Spec evaluation.

6 FWO5B C - BOP 1 B MFP trips. Standby MFP starts, but trips on overcurrent.

FWO6 C SRO BOP runs back the turbine to <800 MWe. AOl -16 entry.

7 RDO9 C RO- Automatic rod control fails. RO inserts control rods manually to c - SRO reduce power during the runback. AOl -2 entry.

8 MSO6B M ALL- SG #2 MSIV fails closed. Reactor trip (manual) or on MSO3F Overpower/delta T. EOP network entry.

MSO3G 9 RP13 C BOP

- Feedwater isolation signal fails. BOP manually isolates C SRO feedwater.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

Appendix D Scenario Outline Form ES-D-1I Scenario I Summary Initial Conditions:

75% power, BOL, 1305 ppm boron. 1 B Main Feedwater Pump tripped 5 days ago, and power has been maintained at 75% while repairs were being completed. 1 B MFP has been restarted and placed in service, minimizing some of the Standby MFP forward flow. The crew is to shutdown Standby MFP per SOI-2&3.01, section 5.11. [41.16]. The crew is then to perform a powerescalation using GO-4, Section 5.2 at 3%/hour. 1A MD AFW Pump is out of service for pump bearing replacement. LCO 3.7.5.b was entered 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months ago. 1A MD AFW Pump is expected to be returned to service in 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months .

1. Shutdown Standby MFP using SOI-2&3.01 starting at step 5.11. [41.16].

2. The crew performs a power escalation using GO-4, Section 5.2 at 3%/hour.

3. 1-PT-1-33 Main Steam Header Pressure transmitter fails low. Affects automatic MFP speed control for Feed Reg Valve P. MFP speed drops, S/G levels lower. BOP takes MANUAL control of the MFP Master Controller and controls speed and Feed Reg Valve P lAW AOl -16, Loss of Normal Feedwater.

4. 1-LT-68-339 fails high, causing charging flow and RCP seal injection flows to drop. RO takes 1-FCV-62-93 to MANUAL and raises charging and RCP seal injection flow. AOl-20, Malfunction of PZR Level Control, is entered. SRO evaluates Tech Specs.

5. Containment Pressure transmitter PDT-30-45 fails high. SRO evaluates Tech Specs.

6. 1 B MFP trips due to low bearing oil pressure. Since the plant load is not >85%, an automatic runback does not occur, requiring the BOP to perform a manual runback. When the Standby MFP automatically starts, it trips on overcurrent. BOP runs back the turbine to <800 MWe. AOl -16, Loss of Normal Feedwater, is entered.

7. During the plant runback and resulting Tave/Tref mismatch, automatic rod control fails. RO takes MANUAL control of rods to reduce reactor power during the runback. Crew enters AOl -2, Malfunction of Reactor Control System.

8. SG #2 MSIV fails closed. The resultant pressure transient lifts S/G safety valves. Two valves on the same S/G stick open. If the reactor is not tripped manually, a reactor trip occurs due to Overpower AT.

The steam leak requires the operators to actuate a safety injection. The crew performs E-0, and transitions to E-2. When termination criteria are met, the crew performs ES-i .1.

9. On the reactor trip, feedwater isolation signal fails. BOP closes valves and stops pumps manually to isolate feedwater.

10. The scenario terminates when the crew secures both SI Pumps and places them in automatic lAW ES-li.

Critical 1 2 Tasks: Identifies failure of Feedwater Isolation: Isolates faulted S/G prior to transition from E-2:

Closes MFW isolation valves.

Align TDAFW steam supply from intact S/G.

Checks MFW bypass isolations closed.

Isolates AFW flow.

Closes MEW reg and bypass reg valves.

Ensures MEW isolated.

Trips MFW pumps.

Ensures PORV is closed.

Trips demin pumps and cond booster

Ensures S/G blowdown isolated.

pumps.

Appendix D NUREG 1021 Revision 9

Page 1 of 4 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #1 Faulted Steam Generator EVENT I IC/MF/RF/OR # I DESCRIPTION/FEEDBACK rst 245, switch check, select RUN Sim. Setup 75% RTP, BOL, Cb- 1305 ppm. This IC contains the verify malfunctions and overrides listed overrides and triggers.

below 0 Turns off audible alarm for the simulator fault so the Disable simulator fault alarm crew cannot hear this alarm.

0 Place A Train week I placard on On entrance side panel.

entrance side panel.

0 Place DANGER Tag on 1A MDAFW 1A MDAFW out of service.

Hand Switch Indicate/Enter in the appropriate blanks Ensure BOL Reactivity Briefing Book is used. Item this information into the reactivity 3: Delta I -0.3 and AUTO rod control.

briefing book, (appendix B TI-7.012) Item 4: Negative, 1-CCP B, 890 0 Item 5: 1305, Boron, BA 10.2, PW 70, BA Pot 24, PW POT 35 Item 6: PW 33 gal Item 7: PW 35 gal 75% RTP, MOL, C 1305 ppm.

Suit Setup ijIC 245 rst , switch check, select run.

does izot work.

IA MDAFW out of service. Prevents start of pump 0 batch OOS AFWP A and turns breaker lamp off.

0 l-PT-1-33 Main Steam Pressure transmitter fails low imfrx20 100 (el) 0 imfrx05a 100 (e2) l-LT-68-339 fails high 0 imfcliold 15 (e3) CNTMT Pressure Transmitter PDT-30-45 fails high ior an:ov:11c052 (e4) alarm ior an:ov:11c035 (e4) alarm br zaopi4639 (e4) 0 1 B MFP trips; STBY MFP starts, but trips imf fw05b (e4 15) on overcurrent I mffw06 imfms06b 0 (e5) 0 imfms03f 100 (e5) #2 S/G MSIV fails closed. 2 S/G safety valves fail imfmso3g 85 open imfrpl3 Failure of FWI imf rdO9 Failure of control rods to move in automatic

Page 2 of 4 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #1 Faulted Steam Generator I EVENT I IC/ME/RE/OR # I DESCRIPTION/FEEDBACK none Stop the STBY lIFP and increase power from Event # 1& 2:

75% to 100%.

Stop the STBY MFP When directed as AUO to close 1-FCV-3-205, wait and increase power as 10 minutes and report valve is closed. imr fw2I 0.

determined by NRC E x a iii ie r.

When directed to reopen I-FCV-3-205, wait 5 minutes and report valve open. imr fw2l 100 Event # 3: imf rx2O 0 (el) 1-PT-1-33 Main Steam Header Pressure Transmitter fails low.

When power increase complete as determined by NRC If notified as work control/maintenance concerning Examiner, Insert this I -PT- 1-33 problems, acknowledge request Malfunction using Trigger 1 Event # 4: imfrx05a 100(e2) 1-LT-68-339 fails high causing 1-FCV-62-93 Charging Flow Control Valve to close vVhen actions associated with AOl-16 are complete as If notified as work control/maintenance concerning determined by NRC I -LT-68-339 Level Transmitter fai lure acknowledge Examiner, Insert this request Malfunction using Trigger 2 Event # 5: CNTMT Pressure Transmitter PDT-30-45 fails inifch0ld 15 (e3) high When actions associated with I -LT- If notified as work control/maintenance concerning 68-339 Transmitter PDT-3 0-45 acknowledge request.

are complete as determined by NRC Examiner, Insert this Malfunction using frigger 3

Page 3 of 4 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #1 Faulted Steam Generator EVENT I IC/ME/RE/OR # I DESCRIPTION/FEEDBACK Event # 6 & 7:

br an:ov:11c052 (e4) alarm lB MFP trips. STBY MFP starts but trips on When actions ior an:ov:11c035 (e4) alarm overcurrent. Plant runback to less than 800 associated with PDT- ior zaopi4639 (e4) 0 MWe.

30-45 are complete as irnffw05b (e4 15) determined by NRC imffw06 (e4)

Examiner, Insert this Malfunction using Trigger 4 As AUO, when dispatched, report the MFPT tripped on low oil pressure caused by an oil line break to the pressure switch. Leak has been isolated with minor oil spill.

As AUO, if asked to to investigate the STBY MFP trip, wait 5 minutes then inform MCR that the STBY MFP tripped on overcurrent.

If notifed as Chemistry of the power change, acknowledge request to sample the RCS.

If notified as work control/maintenance concerning the failure of control rods acknowledge request.

Events # 8 & 9 ms06b 0 (e5) S/C #2 MSIV fails closed. Manual Reactor trip When actions ms03f 100 (e5) with failure of automatic FWI and two (2) stuck associated with AOl- mso3g 85 (e5) open safeties on S/G #2.

16 & AOI-2 are complete as determined by NRC As AUO, when asked to investigate the owering S/G Examiner, Insert this #2 pressure, wait 5 minutes and report that steam is Malfunction using coming from the North Vault room..

Trigger 5 As Security, when asked to investigate the owering S/G #2 pressure, wait 5 minutes and report that steam is coming from the North Vault room.

Page 4 of 4 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #1 Faulted Steam Generator I EVENT I IC/M F/RE/OR # I DESCRIPTION/FEEDBACK As AUO, when asked to perform AUO actions of AOI-17, Turbine Trip acknowledge request.

10 minutes after the Reactor trip break, if the control room has not sent AUOs out to investigate, call the control room as Nuclear Security and inform them that a Security Officer on rounds has reported a lot of noise and steam coming from the North Vault Room.

SHIFT TURNOVER CHECKLIST Page of El SM US/MCR Unit El UO Unit Off-going Name El AUO Station El STA (STA Function) On-coming Name-Part I - Completed by off-going shift/Reviewed by on-coming shift: Ch 1305 ppm

Abnormal equipment lineup/conditions:

IA MD AFW Pump OOS for motor bearing replacement. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule

Major Activities/Procedures in progress/planned:

75% power, BOL, 1305 ppm boron. I B MFP tripped 5 days ago, and power has been maintained at 75% while repairs were completed. The I B MFP was started late during the last shift. Currently the IA, 1B, and Standby MFPs are in service.

Shutdown the Standby MFP and commence power escalation to 100%

Radiological changes in plant during shift:

None Part 2 Performed by on-coming shift El A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs)

El A review of the Rounds sheets/Abnormal readings (AUO5 only)

Review the following programs for changes since last shift turnover:

El Standing Orders El LCO(s) in actions (N/A for AUOs)

El Immediate required reading El TACF (N/A for AUOs Part 3 - Performed by both off-going and on-corning shift El A walkdown of the MCR control boards (N/A for AUO5)

Relief Time: Relief Date:

TVA 40741 [03-2001] Page 1 oft OPDP-t-I [03-14-2001]

SHIFT TURNOVER CHECKLIST Page of LI SM LI US/MCR Unit UO Unit Off-going Name LI AUO Station LI STA (STA Function) On-coming Name Part I - Completed by off-going shift/Reviewed by on-coining shift: Ch= 1305 ppm

Abnormal equipment lineup/conditions:

IA MD AFW Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

75% power, BOL, 1305 ppm boron. 1 B MFP tripped 5 days ago and power was maintained at 75%

while repairs were completed. The I B MFP was started late during the last shift. Currently the 1 A MFP, lB MFP, and Standby MFPs are in service.

Shutdown the Standby MFP and commence power escalation to 100%.

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift LI A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUO5)

LI A review of the Rounds sheets/Abnormal readings (AUO5 only)

Review the following programs for changes since last shift turnover:

LI Standing Orders LI LCO(s) in actions (N/A for AUO5)

LI Immediate required reading LI TACF (N/A for AUOs Part 3 - Performed by both off-going and on-coining shift LI A valkdown of the MCR control boards (N/A for AUO5)

Relief Time: Relief Date:

TVA 40741 [03-2001] Page I of I OPDP-l-l [03-14-200!]

SHIFT TURNOVER CHECKLIST Page of LI srvl LI US/MCR Unit UO Unit Off-going - Name Li AUO Station Li STA (STA Function) On-coming Name Part I - Completed by off-going shift/Reviewed by on-coming shift: Cb 1305 ppm Abnormal equipment lineup/conditions:

IA MD AF\V Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

75% power, BOL, 1305 ppm boron. I B MFP tripped 5 days ago and power was maintained at 75%

while repairs were completed. The I B MFP was started late during the last shift. Currently the IA MFP, I B MFP, and Standby MFPs are in service.

Shutdown the Standby MFP and commence power escalation to 100%.

Radiological changes in plant during shift:

None Part 2 - Perlbrnied by on-coming shift Li A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs)

Li A review of the Rounds sheets/Abnormal readings (AUOs only)

Review the following programs for changes since last shift turnover:

Li Standing Orders Li LCO(s) in actions (N/A for AUOs)

Li Immediate required reading Li TACF (N/A for AUOs Part 3 - Performed by both of1going and on-coming shift Li A walkdown of the MCR control boards (N/A for AUOs)

Relief Time: Relief Date:

TVA 40741 [03-20011 Page I 01 I OPDP-l-I [03-14-2001]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 &2 Page 1 of 29 Event

Description:

Shutdown Standby MFP and Power Escalation Time N Position Applicants Actions or Behavior Booth Instructor: None Indications available: None Direct the BOP to shutdown the Standby MFP in accordance SRO with SOl-2&3.01.

Evaluator Note: Following Step is from SOl-2&3.O1, Condensate and Feedwater System section 5.11.

[41.20] WHEN MFPT has been loaded enough to minimize SMFP forward flow, THEN PERFORM Section BOP 5.12[3], Standby MFP Shutdown and Standby Alignment.

Evaluator Note: Following Steps are from SOl-2&3.O1, Condensate and Feedwater System section 5.12.

Standby MFP Shutdown And Standby Alignment

[1] IF TDMFP to carry load, PERFORM the following:

[1.1] SLOWLY OPEN 1-FCV-3-208, STANDBY MAIN FEEDWATER PUMP MIN FLOW valve using 1-FIC-3-208

[1 -M-3].

[1.2] SLOWLY RAISE TDMFP output to minimize SMFP BOP forward flow USING the following controllers, as desired

[N/A option(s) NOT used]:

1-SIC-46-20A, MFPT A- SPEED CONTROL.

1-SIC-46-20B, MFPT B- SPEED CONTROL.

1-PC-46-20, MFPT A & B MASTER SPEED CONTROL.

[2] ENSURE 1-FCV-3-208, STANDBY MAIN BOP FEEDWATER PUMP MIN FLOW is full open when SMFP flow is reduced below 1500 gpm (minimum required flow).

[3] ENSURE 1-PIC-3-40 set at 1200 psia, and 1-PCV BOP 40 CLOSED.(May be N/Ad if 1-HS-3-45 is in Normal).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 &2 Page 2 of 29 Event

Description:

Shutdown Standby MFP and Power Escalation Time Position Applicants Actions or Behavior

[4] WHEN MFP(s) have stabilized, THEN

[4.1] MONITOR MFP(s) picking up additional load,

[4.2] CLOSE SBMFP Discharge Valve 1-FCV-3-205, BOP [4.3] PLACE 1-HS-3-200A in STOP/PULL TO LOCK,

[4.4] OPEN SBMFP Discharge Valve 1-FCV-3-205

[4.5] PLACE 1-HS-3-200A in P-AUTO.

[5] ENSURE 1-FIC-3-208, STANDBY MFWP RECIRC BOP CONTROL, in AUTO at 90% (1500 gpm)[l-M-3],

and 1-FCV-3208 CLOSED [T1J/729].

[6] RETURN controller used in Step 5.12[1.2] to the as BOP found position or as required for current operating conditions.

[7] IF in LONG CYCLE RECIRC and TDMFPs to remain BOP in service, THEN SET 1-PIC-3-40 as desired (900 1200 -

psia), and ENSURE 1-PCV-3-40 OPEN..

[8] IF SMFP is to be placed in AUTO Standby, THEN

[8.1] ENSURE 1-HCV-3-208 is THROTTLED OPEN as required to maintain SMFP warmed and ready for AUTO START.

BOP [8.2] ENSURE 1-THV-24-948, STANDBY MFW PMP OIL CLR RCW OUTLET THROTTLE, is THROTTLED as necessary to maintain lube oil temperature greater than 75°F..

[9] STOP one of the SMFP AUX OIL PUMPS using the following handswitches and then return to AUTO. (N/A switch NOT used)

BOP A. 1-HS-3-210, STANDBY MAIN FEED WATER PUMP AUX OIL PUMP A. [T1J/729]

B. 1-HS-3-211, STANDBY MAIN FEEDWATER PUMP AUX OIL PUMP B. [T1J/729]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 &2 Page 3 of 29 Event

Description:

Shutdown Standby MFP and Power Escalation Time Position Applicants Actions or Behavior Raise load in accordance with Reactivity Briefing book and SRO GO-4 Normal Power Operations, Section 5.2 starting at step 23 and skipping to step 40.

Evaluator Note: Following Steps are from SOI-62.02 Boron Concentration Control, Section 6.6 starting with step 2 (Dilution)

[2] ADJUST 1-FQ-62-142, PW BATCH COUNTER, for RO required quantity.

RO [3] PLACE 1-HS-62-140B, VCT MAKEUP MODE in DIL.

[4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

RO

[4.1] CHECK_Red_light_is_LIT.

[5] MONITOR the following parameters:

Instrument Location Parameters 1-M-6 VCT PRESS 1-Pl-62-122 1-M-6 VCT LEVEL 1-Ll-62-129A 1-M-6 PW TO BLENDER FLOW 1-Fl-62-142 1-M-6 PW BATCH COUNTER 1-FQ-62-142 1-M6 BA BATCH COUNTER 1-FQ-62-139

[6] WHEN dilution is COMPLETE, AND 1-FCV-62-128 is RO closed, THEN PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO.

Appendix D Required Operator Actions Form ES-D2 Op Test No.: NRC Scenario # 1 Event # 1 &2 Page 4 of 29 Event

Description:

Shutdown Standby MFP and Power Escalation Time Position j Applicants Actions or Behavior

[7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

RO

[7.1] CHECK Red light is LIT.

Evaluator Note: Following Steps are from GO-4, Normal Power Operation, Section 5.2 Step 23 and then skipping to step 40 thru 41.

SRO Direct the crew to increase reactor power to 100%.

RCS should be maintaining Tavg!Tref when Turbine load is RO raised. Control rods will be used along with dilution to maintain Al and, temperature.

[23] CONTINUE ascension to 90% power by performing the following:

[23.1] IF during any of the following steps the REFERENCE changes in an undesired manner, THEN ADJUST VPL to stop turbine load rise.

OR PUSH TURBINE MANUAL to place the turbine control mode in manual mode and PROCEED to section 5.6

[23.2] ADJUST VALVE POSITION LIMIT to 90% or to 5%

above the Gov Control Indication

[23.3] SET LOAD RATE at predetermined value.

BOP [23.4] PUSH REFERENCE CONTROL (raise) button to set desired load in SETTER display.

[23.5] PUSH GO button.

[23.6] MONITOR Generator Megawatts RISING.

[23.7] CHECK that load rise has STOPPED when reference display equals setter OR IF desired to stop the load change THEN STOP the load change by DEPRESSING the HOLD pushbutton.

[23.8] WHEN desired to resume the load change, THEN PRESS the GO push button and continue to monitor load.

[40] BEFORE raising above 80% power, THEN ENSURE the following:

[40.1] 1 -LCV-6-1 06A controlling properly.

[40.2] 1-LCV-6-105A and 105B are NOT open.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 1 &2 Page 5 of 29 Event

Description:

Shutdown Standby MFP and Power Escalation Time Position JI Aoolicants Actions or Behavior When a power Increase has been initiated or at the Lead Examners discretion, proceed to the next event.

[41] WHEN power is at or above 95%, THEN PERFORM the foil owing

[41.1] ADJUST PR NIS per 1-Sl-92-1, NIS Daily Comparison.

[41 .2] IF evaluation of Hot Channel Factors is required, THEN ENSURE 1-Sl-0-20, COMPLETE.

[41.3] NOTIFY MIG to perform 1-Sl-68-30 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after BOP power stabilizes at 90% or above (N/A if NOT applicable).

[41 .4] ENSURE the following level controllers maintaining levels within normal ranges:

A. Feedwater heaters.

B. MSR drain tanks

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 3 Page 6 of 29 Event

Description:

1-PT-1-33, Main Steam Pressure Transmitter, fails low Time N Position Applicants Actions or Behavior Booth Instructor:

Insert Event 3 Trigger I Indications available:

Alarm 63E S!G Level Deviation All S!G Levels lowering Feedwater flow lowering ICS alarm FW Pump Suction Pressure Hi Respond to annunciators and recognize 1-PT-i -33 failure.

BOP Informs crew.

Direct crew actions lAW AOl-16 LOSS OF NORMAL SRO FEE D WATER.

Determines that MFPT speed control is NOT normal and takes Prudent Operator Action lAW TI-12.04 to place MEW pump BOP master controller in Manual, and raise MFP speed.

Evaluator Note: Following Steps are from IAWAOI-16 LOSS OF NORMAL FEEDWATER., section 3.7.

CHECK MFWPT speed controller(s) NORMAL.

Performs RNO:

CONTROL MFP speed using MANUAL control of master controller or individual controller(s) as required.

BOP IF MANUAL control of individual MFWPT controller is ineffective, THEN TRIP affected MFWPT, and GO TO Section 3.4 or 3.5 as applicable.

RO Place control rods in MANUAL.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event# 3 Page 7 of 29 Event

Description:

1-PT-i -33, Main Steam Pressure Transmitter, fails low Time Position Applicants Actions or Behavior RO CHECK MFW pumps recirc valves NORMAL.

RO Ensures T-avg and T-ref within 30 Adjusts pump speed to maintain MFW pump discharge BOP pressure normal.

Restore SG levels to program.

BOP Checks steam dump mode in T-AVG position SRO Notify Work Control to have instrument repaired.

May direct/request control rods be returned to Auto.

SRO/RO

ENSURE Tavg and Tref within 1°

PLACE control rods to auto.

When the plant has been stabilized or at the Lead Examiners discretion, proceed to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 4 Page 8 of 29 Event

Description:

1-LT-68-339 fails high Time Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 4 (Trigger 2)

Indications available:

Alarm 92B PZR LEVEL HI DEVIATION Alarm IOIE RCP SEAL SUPPLY FLOW LO Alarm 108A CHARGING FLOW HI/LO Crew Diagnose a failure of the controlling PZR Level channel.

May take PRUDENT Operator action lAW TI-12.04 to take RO manual control of 1-FCV-62-93 to lower charging flow to normal.

Direct crew actions lAW AOl-20 MALFUNCTION OF SRO PRESSURIZER LEVEL CONTROL SYSTEM Evaluator Note: Following Steps are from AOI-20 MALFUNCTION OF PRESSURIZER LEVEL CONTROL SYSTEM section 3.6

1. CHECK pzr level program signal NORMAL:

RO

. LR-68--339

2. CHECK if 1-XS-68-339E is selected to FAILED channel,(control or backup):

. LI-68-339, RO

LI-68-320,

LI-68-335.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event# 4 Page 9 of 29 Event

Description:

1-LT-68-339 fails high Time Position Applicants Actions or Behavior

3. CHECK failure HIGH.

RO

4. IF controlling channel failed,THEN PLACE charging valve controller 1-HIC-62-93A in MAN, and RESTORE level to RO program.

5. SELECT operable pzr level channels for control and indication [1-M-5]:

a. SELECT operable channels for control and backup with 1-XS-68-339E.

RO

b. ENSURE operable channel selected recording with 1-XS-68-339 B.

6. CHECK letdown IN SERVICE:

. FCV-62-69 OPEN.

. FCV-62-70 OPEN.

RO

FCV-62-77 OPEN.

Letdown orifice OPEN.

7. RESTORE pzr level control to normal:

a. MAINTAIN regen hx letdown temp < 380 °F.

b. CONTROL charging and letdown to return pzr level to program.

c. ENSURE pzr control heater bank D red light LIT.

d. Momentarily PLACE 1-HS-68-341H, pzr backup RO heater bank C, to OFF.

e. CHECK pzr program level NORMAL. 1-LR-68-339 (green pen)

f. RETURN charging valve controller 1-HIC-62-93A to AUTO.

8. NOTIFY Work Control to remove failed channel from service.

SRO

Aj5pendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 4 Page 10 of 29 Event

Description:

1-LT-68-339 fails high Time Position Applicants Actions or Behavior

9. REFER TO the following Tech Specs:

3.3.1, Reactor Trip System (RTS) Instrumentation.

3.3.3, Post Accident Monitoring Refer to Tech Specs and enters:

SRO a LCO 3.3.1, Table 3.3.1-1, item 9 condition X

LCO 3.3.3, Table 3.3.3-1, item 14, condition F.

(Action A)

10. INITIATE repairs to failed instrument/circuitry.

SRO When Tech Specs have been addressed or at the lead examiners discretion, proceed to the next event.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 5 Page 11 of 29 Event

Description:

PDT-30-45, Containment Pressure Transmitter, fails high Time Position Applicants Actions or Behavior Booth Instructor:

Insert Event 5 Trigger 3 Indications available:

Alarm 125A Cntmt Hi-Hi- Press Steamline Isolation Containment Pressure Indicator 1-PDT-30-45 fails High SRO Refers to Technical Specification 3.3.2, Action E for required actions n,-,-THn -o:nt inund

ONDITIGN REQUIRED A7TIC:H CQTlILETI7ftJ TINE E. Qnn *::ntainnvnnt E.1 NOTE Iun,nnlr-n cIu,nn1 onn adIjt i)nal inopnra1.1 . channnl na in bypan.nnd fr up 7.

4 1icur.n laL s,trnillancn 7-nnlin:7.

Placn channn 1 in 7 haurn hpa OR E.2. 1 En- in MOrE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND E.2.2 En in [lODE $ . 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months SRO Notify Work Control to initiate repairs.

When the SRO has referred to Tech Specs or at the Lead Examiners discretion, proceed to the next event.

rAppendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 12 of 29 Event

Description:

1 B MFP Trip & STBY MFP trip on overcurrent Time Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event (Trigger 4)

Indications available:

Alarm 50B MFPT lB Abnormal Alarm 51A Tripped Alarm 52A Bearing Oil Press Lo White Breaker Disagreement light on STBY MFP Feed Flow lowering Lube Oil Pressure (1 -P1-46-39) reading 0 Should diagnose a loss of the lB MFP and the SRO should go Crew toAOl-16 Evaluator Note: The following are steps in A 01-16 starting in section 3.5 step 2.

2. CHECK turbine load less than or equal to 1000 MWe (85%).

BOP

3. PLACE tripped MFP recirc valve controller in MANUAL, and BOP CLOSE recirc valve.

Evaluator Note: The BOP should recognize that the Standby MFWP has tripped.

4. CHECK turbine load less than 800 MWe (67%),

Perform RNO:

ENSURE Standby MFWP running.

BOP IF Standby MFWP NOT available, THEN REDUCE turbine load to less than 800 MWe with valve position limiter.

5. ENSURE MFWP speed rising to control S!G AP and levels BOP on program.

Appendix D Required Operator Actions Form ES-D-21 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 13 of 29 Event

Description:

1 B MFP Trip & STBY MFP trip on overcurrent Time Position Applicants Actions or Behavior

6. ENSURE adequate feed flow for existing conditions:

BOP

Feed flow greater than or equal to steam flow.

. SIG levels returning to program.

Note: To prevent Rods from excessive insertion, the SRO may direct a Minor Boration in an amount as described in the Reactivity Briefing Book, lAW 62.02 Boron Concentration Control section 6.7.

7. ENSURE T-avg and T-ref within 30 RO recognizes that automatic rod insertion is not occurring.

RO RNO:

INSERT control rods to match reactor power with turbine load.

8. REFER TO Tech Specs:

3.2.3 AFD SRO Crew should also be prompted to review this Tech Spec from ARI-83 D PLANT COMPUTER GENERATED ALARM, if it is in alarm.

9. IF feed flow greater than 40%, THEN ENSURE tripped BOP MFWP turbine condenser valves CLOSED:

__Pump_A,_1-FCV-2-205_and_-210 BOP 10. MONITOR reg valves controlling S/G levels on program.

11. IF C-7 LOSS OF LOAD STM DUMP INTERLOCK annunciator LIT [66E], THEN

a. ENSURE steam dump valves have zero demand.

BOP

b. RESET loss-of-load interlock with steam dump mode switch.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 6&7 Page 14 of 29 Event

Description:

1 B MFP Trip & STBY MFP trip on overcurrent Time Position Applicants Actions or Behavior

12. ENSURE Condensate System Pumps in service as necessary:

REFER TO GO-4, Normal Power Operation.

SRO No Action necessary

13. IF reactor power dropped by greater than or equal to 15%

in one hour, THEN NOTIFY Chemistry to initiate power change SRO sampling requirements.

14. CHECK VALVE POS LIMIT LIT.

BOP

15. REDUCE turbine load setpoint using REFERENCE CONTROL V (lower) AND GO button until VALVE POS BOP LIMIT LIGHT not LIT, THEN SET valve position limiter to 95%.

16, INITIATE repairs on failed pump.

SRO

17. RETURN TO Instruction in effect.

SRO Evaluator Note: The following are steps in AR1-87-B ROD INSERTION LIMIT LO-LO (The following actions are dependent upon how far control rods are manually inserted.)

[1] IF low-low rod insertion limit has been exceeded, THEN

[a] STOP all dilutions of RCS.

[b] SELECT manual rod control, and RESTORE Tavg to Tref, if necessary.

RO [c] INITIATE SDM determination.

[d] RESTORE rods to within limits within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

[e] GO TO AOI-34, IMMEDIATE BORATION.

[Zpendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 1 Event# 6&7 Page 15 of 29 Event

Description:

1 B MFP Trip & STBY MFP trip on overcurrent Time N Position Applicants Actions or Behavior Evaluator Note: The following are steps in AOl-34 IMMEDIATE BORATION, starting in section 3.2 step 1. Crew should reference Reactivity Briefing book to estimate amount of boric acid to add.

1. INITIATE normal boration to change CB as necessary:

a. PLACE BA flow controller, 1-FC-62-139, to desired flow rate.

b. ADJUST BA batch counter 1-FQ-62-139 to ensure boration continues.

RO

c. PLACE mode selector 1-HS-62-140B to BOR.

d. PLACE VCT makeup control 1-HS-62-140A, to START.

e. VERIFY boric acid flow indicated on 1-Fl-62-139.

2. ENSURE PW to blender isol 1-FCV-62-143, CLOSED.

RO

3. CHECK PW to blender flow 1-Fl-62-142, indicating ZERO.

RO

4. MONITOR for negative reactivity Insertion:

. Neutron flux dropping.

. TAVG dropping.

RO

Control rod bank position rising (if in AUTO).

If Rods have been placed in Manual, RO shall withdraw control rods as necessary to maintain Tavg/Tref.

When the plant is stable or when determined by the NRC, Lead Examiner may cue the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 8&9 Page 16 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-i .1 Time Position N Applicants Actions or Behavior Booth Instructor: NONE Indications Reactor Tripped Directs RO perform E-O.

SRO Evaluator Note: The following are steps from E-O.

NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

NOTE 2 Status Trees I SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RPIs at bottom of scale.

RO

Neutron flux DROPPING.

2. ENSURE Turbine Trip:

All turbine stop valves CLOSED.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 8&9 Page 17 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-i .1 Time Position N Applicants Actions or Behavior

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:CSST (offsite), OR DIG RO (blackout).

4. CHECK SI actuated:

a. Any SI annunciator LIT.

b. Both trains SI ACTUATED.

RO

1 -XX-55-6C

1-XX-55-6D BOP Evaluator Note: Appendix A (E-O), SI Support Systems, and Appendix B, Phase B Pipe Break Contingencies are contained at the end of this document.

BOP EVALUATE support systems:

REFER TO Appendixes A and B (E-O), Equipment Verification pages 1 5-28.

6. ANNOUNCE reactor trip and BOP safety injection over PA system.

7. ENSURE secondary heat sink RO available with either:

Total AFW flow greater than 410 gpm, OR

At least one S/G NR level greater than 29%

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8& 9 Page 18 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-1.1 Time N Position N Applicants Actions or Behavior

8. MONITOR RCS temp stable at or trending to 557°F:

IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 557°F.

Perform RNO:

IF temp less than 557°F, THEN ENSURE steam dumps and SIG PORVs CLOSED.

RO IF cooldown continues, THEN:

PLACE steam dump controls OFF.

CONTROL totalAFW flow to maintain greater than 410 gpm UNTIL NR level in at least one S/G greater than 29%

IF cooldown continues after AFW flow is controlled, THEN CLOSE MSIVs.

ENSURE MSIV bypasses CLOSED.

9. ENSURE excess letdown valves CLOSED:

BOP

1-FCV-62-54

1 -FCV-62-55

10. CHECK pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

RO

b. At least one block valve OPEN.

1 1. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic RO monitors.

12. CHECK pzr sprays CLOSED.

RO

13. CHECK if RCPs should remain in service:

RO a. Phase B signals DARK [MISSP}.

b._RCS_pressure_greater than_1500_psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 1 Event# 8&9 Page 19 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-i .1 Time N Position N Applicants Actions or Behavior

14. CHECK S/G pressures:

All S/G pressures controlled or rising.

All S/G pressures greater than 120 psig.

RO Perform RNO:

IF SIG pressure low OR dropping uncontrolled, THEN GO TO E-2, Faulted Steam Generator Isolation.

Evaluator Note: SRO should direct the crew to GO TO E-2 at this point. The following steps are from E-2.

CRITICAL BOP Task 2 ENSURE all MSIVs and MSIV bypasses CLOSED.

Part I PLACE steam dump controls OFF:

BOP

1-HS-1-103A, STEAM DUMP FSV A.

1-HS-1-103B, STEAM DUMP FSV B.

CHECK for at least one Intact S!G:

Any S!G pressure controlled or rising, BOP OR

Any S!G pressure greater than P-sat for RCS incore temperature Evaluator Note: the crew should identify # 2 S/G as the faulted S/G.

IDENTIFY Faulted S!G based on ANY of the following:

Any S!G pressure dropping in an uncontrolled manner, BOP OR

Any S!G pressure less than 120 psig, OR

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8&9 Page 20 of 29 Event

Description:

E-0 with failure of FWI to E-2, to ES-1.1 Time N Position Applicants Actions or Behavior

S!G enclosure temps high:

1) TlOO2Afor2and3,

2) Ti 003A for 1 and 4.

OR

Local indication of break in any of the following:

1) Main steam lines,

2) Main feedwater lines,

3) Other secondary piping.

CRITICAL ISOLATE Faulted S/G:

Task 2 Part 2

a. ISOLATE AFW flow to Faulted SIG.

b. ENSURE MEW ISOLATED to Faulted S!G:

MEW isolation valves CLOSED.

BOP

MEW bypass isolations CLOSED.

MEW reg and bypass reg valves CLOSED.

MEW pumps TRIPPED.

c. ENSURE Faulted S/G PORV CLOSED.

b. ENSURE Faulted S/G blowdown ISOLATED.

BOP ENSURE TD AEW pump being supplied from Intact SIG..

BOP MONITOR CST volume greater than 200,000 gal.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8& 9 Page 21 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-I .1 Time N Position U Applicants Actions or Behavior WHEN RCS temperature is stable or rising following Faulted SIG blowdown, BOP THEN ADJUST Intact S!G PORV controllers in AUTO to P-sat for the hottest RCS temp.

CHECK secondary side radiation:

. S!G discharge monitors NORMAL.

BOP

Condenser vacuum exhaust rad monitors NORMAL.

S/G blowdown rad monitor recorders

NORMAL trend prior to isolation.

S!G sample results by Chemistry.

MONITOR SI termination criteria:

a. MONITOR RCS subcooling greater than 65°F ADV.

b. MONITOR secondary heat sink available with either:

Total feed flow to Intact S!Gs greater than 410 gpm, RO OR

At least one Intact SIC NR level greater than 29% ADV.

c. MONITOR RCS pressure stable or rising.

d. MONITOR pzr level greater than 15% ADV.

c. GO TO ES-i .1 ,Sl Termination.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # 8& 9 Page 22 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-1.1 F Time .

Position N Applicants Actions or Behavior Evaluator Note: SRO should direct the crew to GO TO ES-1.1 at this point.

The following steps are from ES-ti.

RESET SI, and CHECK the following:

RO

SI ACTUATED permissive DARK.

AUTO SI BLOCKED permissive LIT.

RO RESET Phase A and Phase B.

ENSURE cntmt air in service:

a. Aux air press greater than 75 psig [M-15].

BOP b. Cntmt air supply valves OPEN {M-15]:

1-FCV-32-80.

1-FCV-32-102.

1-FCV-32-11O.

ENSURE ONLY one Charging Pump running:

RO

STOP all but one CCP and PLACE in A-AUTO.

RO CHECK RCS press stable or rising.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event# 8&9 Page 23 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-1.1 Time N Position Applicants Actions or Behavior ALIGN charging:

a. CLOSE RCP seal flow control 1-FCV-62-89.

b. OPEN charging isolation valves 1-FCV-62-90 and 1-FCV-62-91.

RO c. ENSURE charging valve 1 -FCV-62-85 OR 1-FCV-62-86 OPEN.

d. CHECK RHR Suction aligned from RWST.

e. OPEN seal return valves 1-FCV-62-61 and 1-FCV-62-63.

CLOSE BIT outlet valves 1-FCV-63-25 and 1-FCV-63-26.

RO ADJUST 1-FCV-62-89 and 1-FCV-62-93 to maintain:

Seal injection flow between 8 and 13 gpm for each RO RCP.

Pzr level stable or rising.

CONTROL charging flow to maintain pzr level:

a. IF any S!G Faulted, RO THEN DO NOT CONTINUE this Instruction UNTIL Faulted SIG depressurization stops.

b.__CHECK_pzr_level_stable_or_rising.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # i Event # 8& 9 Page 24 of 29 Event

Description:

E-O with failure of FWI to E-2, to ES-i .1 Time Position N Applicants Actions or Behavior DETERMINE if SI pumps should be stopped:

a. CHECK RCS pressure:

Stable or rising.

Greater than 1350 psig.

RO b. CHECK RHR Suction aligned from RWST.

c. CHECK RCS pressure:

Stable or rising.

Greater than 1650 psig.

11. STOP SI pumps, AND PLACE in A-AUTO.

RO Evaluator Note: Scenario may be terminated when crew has stopped and placed both SI Pumps in P-Auto, or at the discretion of the Lead Evaluator. Remainder of ES-1.1 procedure not included.

The following pages are pages from E-O Appendix A & B, which were given to the BOP to perform.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # Page 25 of 29 Event

Description:

E-O Appendix A Time Position N Applicants Actions or Behavior E I Booth Instructor: NONE Indications Directs BOP to perform E-0 STEP 5:

5. EVALUATE support systems:

SRO

REFER TO Appendixes A and B (E-0), Equipment Verification pages 15-28.

Evaluator Note: The following are E-0 Appendix A steps.

Evaluator Note: The SRO may at times interrupt the BOP, during the performance of Appendixes A and B, to perform other higher priority task.

1. ENSURE PCBs OPEN:

PCB 5044.

BOP

PCB 5088.

2 ENSURE AFW pump operation:

Both MD AFW pumps RUNNING.

TD AFW pump RUNNING.

BOP

LCVs in AUTO, or controlled in MANUAL.

Evaluator Note: The BOP or the RO may have already taken PRUDENT operator action lAW TI-I 204 to perform the next step.

. . 3. ENSURE MEW isolation:

Critical .

MEW isolation and bypass isolation valves CLOSED.

Task #1

MEW reg and bypass reg valves CLOSED.

MEP A and B TRIPPED.

BOP

Standby MFP STOPPED.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # Page 26 of 29 Event

Description:

E-O Appendix A Time Position N Applicants Actions or Behavior

4. MONITOR EGGS operation:

a. Charging pumps RUNNING.

b. Charging pump alignment:

RWST outlets 1-LCV-62-135 and 1-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1-LCV-62-133 CLOSED.

Charging 1-FCV-62-90 and 1-FCV-62-91 CLOSED.

c. RHR pumps RUNNING.

d. SI pumps RUNNING.

e. BIT alignment:

BOP

Outlets 1-FCV-63-25 and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater than 1650 psig.

RNO if not >l65Opsig:

f. ENSURE SI pump flow. IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

5 CHECK cntmt isolation:

a. Phase A isolation:

Train A GREEN.

Train B GREEN.

BOP b. Cntmt vent isolation:

Train A GREEN.

Train B GREEN.

6. CHECK cntmt pressure:

Phase B DARK [MISSP].

Cntmt Spray DARK [MISSP].

BOP

Cntmt press less than 2.8 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # Page 27 of 29 Event

Description:

E-O Appendix A Time Position Applicants Actions or Behavior

7. CHECK plant radiation NORMAL:

S!G blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation {M-12j.

Condenser vacuum exhaust rad recorder 1-RR 119 NORMAL prior to trip [M-12].

1-RR-90-106 and 1-RR-90-112 radiation recorders NORMAL prior to isolation [M-12].

BOP

S!G main steamline discharge monitors NORMAL [M 30].

Upper and Lower containment high range monitors NORMAL [M-30].

NOTIFY Unit Supervisor conditions NORMAL.

8 ENSURE all DIGs RUNNING.

BOP

9. ENSURE ABGTS operation:

a. ABGTS fans RUNNING.

b. ABGTS dampers OPEN:

FCO-30-146A.

BOP

FCO-30-146B.

FCO-30-157A.

FCO-30-157B.

10. ENSURE at least four ERCW pumps RUNNING, one on each shutdown board preferred.

BOP 1 1. ENSURE ERCW supply valves OPEN to running D/Gs.

BOP

12. ENSURE CCS HX C ALT DISCH TO HDR B, 0-FCV BOP 152, is open to position A.

13. CLOSE CCS HX C DISCH TO HDR A, 0-FCV-67-144.

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event# Page 28 of 29 Event

Description:

E-O Appendix A Time N Position I Applicants Actions or Behavior

14. MONITOR EGTS operation:

EGTS fans RUNNING.

ENSURE dampers OPEN VERIFY filter bank dp BOP between 5 and 9 inches of water.

15. ENSURE CCS pumps RUNNING:

lA-A CCS pump.

lB-B CCS pump.

BOP

C-S OR 2B-B CCS pump.

16. CHECK CNTMT PURGE fans STOPPED:

BOP

17. CHECK FUEL HANDLING EXH fans STOPPED, Fuel and Cask loading dampers CLOSED:

BOP

18. ENSURE AB GEN SUPPLY and EXH fans STOPPED.

BOP

19. ENSURE AB GEN SUP & EXH dampers CLOSED.

BOP

20. ENSURE MCR & SPREAD RM FRESH AIR dampers CLOSED:

DCD *FCV-31-3.

FCV-31-4.

21. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, OR Fan B-B BOP RUNNING.

FCO-31-8, OPEN OR FCO-31-7, OPEN.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 1 Event # Page 29 of 29 Event

Description:

E-O Appendix A Time Position 1 Aoolicants Actions or Behavior

22. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

GB EMERG PRESS FAN A-A, OR FAN B-B RUNNING.

BOP

FCO-31-6, OPEN. OR FCO-31-5, OPEN.

23. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY and EXH FANS AND BOP dampers.

TOILET & LKR RM EXHAUST FAN AND dampers.

24. INITIATE Appendix B.

BOP Evaluator Note: Only step I of E-O Appendix B is listed below

1. CHECK PHASE B actuated BOP WHEN PHASE B actuation occurs; THEN GO TO step 2.

Appendix D Scenario Outline Form ES-D-1 Facility: Watts Bar (2008-B) Scenario No.: 2 Op Test No.: 1 Examiners:

Initial Conditions: 100% power, MOL, 877 ppm boron. 1A MD AFW Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Turnover: The plant is stable at 100% power, equilibrium Xenon. The crew is to reduce reactor power and turbine load in accordance with the reactivity plan and GO-4, Normal Power Operation, until #4 Governor Valve closes for turbine valve testing.

Event Maif. No. Event Event No. Type* Description 1 N/A I - BOP Reduce power to begin turbine valve testing.

TC19 I - SRO EHC control circuit generates a spurious signal to start closing governor valves. BOP manual action to terminate.

2 RWO1A C BOP

- A-A ERCW Pump trips. BOP starts redundant ERCW pump.

c SRO AOl-13 entry. Tech Spec evaluation.

TS SRO-3 RX11A I - SRO Turbine Impulse pressure 1-PT-1-73 fails low. RO manually I RO controls rods. AOl-2 entry. Tech Spec evaluation.

TS SRO-4 CV17B C ALL

- No. 2 RCP #1 seal fails (6.0 gpm leak). AOI-24 entry for seal failure. Requires plant shutdown.

5 N/A N - BOP AOl-39 entry, Ramp offline at 2%/mm. RO and BOP manual R - RO actions.

6 RCO7A C - RO PZR PORV 1-PCV-68-334 fails 100% open. RO manual action.

c - SRO AOI-18 entry. Tech Spec evaluation.

TS SRO-7 CV18B M All

- Small Break LOCA develops from No. 2 RCP seal package. AOl THO3B 6 entry. Requires reactor trip and safety Injection.

8 SIO8C C RO- Both SI pumps fail to start on the Safety Injection signal. RO SIO8D C SRO manually starts SI pumps.

9 CSO5 I - BOP Containment Phase B fails to automatically actuate. BOP I - SRO manually actuates.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9, Supplement 1

Appendix D Scenario Outline Form ES-D-i Scenario 2 Summary Initial Conditions:

The plant is stable at 100% power, MOL, 877 ppm boron. The crew is to reduce reactor power and turbine load in accordance with the reactivity plan and GO-4, Normal Power Operation, until #4 Governor Valve closes for Turbine Valve Testing. The 1A MD AFW Pump is OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

1. Commence a load reduction in accordance with GO-4 to support turbine valve testing. After the load reduction is commenced an EHC control circuit failure causes the governor valves to continue to close.

BOP places turbine in TURBINE MANUAL to stop the load drop, and operates the turbine using GO-4, Section 5.6 Operating with Turbine Controls in Manual Mode.

2. A-A ERCW Pump trips. BOP starts redundant ERCW pump and deselects the failed pump from emergency start, lAW AOl-i 3, Loss of Essential Raw Cooling Water. SRO evaluates Tech Specs.

3. Turbine Impulse Pressure transmiffer 1-PT-i -73 fails low, causing a large apparent Tavg-Tref mismatch resulting in a continuous rod insertion. RO manually controls rods to stabilize the plant.

AOl-2 Malfunction of Reactor Control is entered. Rod control remains in MANUAL mode until the impulse pressure transmitter is repaired. SRO evaluates Tech Specs associated with Permissive P 13, Turbine Impulse Pressure.

4. The #1 seal on the No. 2 RCP fails. AOI-24 Reactor Coolant Pump Malfunctions is entered. The Operations Management directs a shutdown of the plant, as soon as possible, requiring the use of AOl-39, Rapid Plant Shutdown.

5. PZR PORV 1 -PCV-68-334 fails partially open, causing a rapid drop in RCS pressure. The RO tries to close the PORV, and then closes the associated block valve to terminate the depressurization. AOl-18, Malfunction of Pressurizer Pressure Control is entered. SRO evaluates Tech Specs associated with DNB parameters and PORV operability.

6. AOI-39 ramp offline due to failing RCP seal.

7. The RCP seal problem degrades, resulting in a small break LOCA. A reactor trip and safety injection are required, with entry into E-0 Reactor Trip or Safety Injection and a transition to E-1 Loss of Reactor or Secondary Coolant, and then performance of ES-i .2 Post LOCA Cooldown and Depressurization.

8. Both SI pumps fail to start on the Safety Injection signal. RO manually starts SI pumps.

9. Containment Phase B fails to automatically, actuate. BOP manually actuates.

10. Terminate scenario when crew commences a plant cooldown lAW ES-i .2.

Critical 1 2 Tasks: Establish flow from at Manually initiate Phase B least one intermediate prior to completing E-1, head ECCS pump step 1.

before transition out of E-0.

Appendix D NUREG 1021 Revision 9, Supplement 1

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 &2 Page 1 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time I Position Applicants Actions or Behavior Booth Instructor: When directed initiate Event 1 (trigger 1)

Indications available: EHC reference value lowers.

Direct a load reduction in accordance with GO-4 Normal Power SRO Operations, Section 5.3, and SOl-62.02 Boron Concentration Control, Section 6.4.

Evaluator Note (1): GO-4, Normal Power Operation, Section 5.3 steps 1 thru 9 may be performed concurrently with SOl-62.02 actions to inject boric acid. GO-4 steps are listed at the end of the SOI 62.02 steps in this document.

Evaluator Note (2): Following Steps are from S0I-62.02 Boron Concentration Control, Section 6.4 starting with step 4 (steps 1,2, & 3 are N/A).

IF reactor is critical AND Reactor power is to be changed by>

5%, THEN RO USE an approved Reactivity Control Plan.

Evaluator Note: The Reactivity plan calls for an initial addition of 55 gal of Boric Acid, and then use Control Rod insertion for the remainder of the power decrease.

[4] ADJUST 1-FC-62-139, BATO BLENDER [1-M-6j, for RO desired flow rate.

[5] ADJUST 1-FQ-62-139, BA BATCH COUNTER [1-M-6], for RO required_quantity.

[6] PLACE 1-HS-62-140B, VCT MAKEUP MODE [1-M-6],

RD in_BOR.

[7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL [1-M-6], to START.

RO

[7.1] CHECK_Red_light_is_LIT.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 &2 Page 2 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time I Position Applicants Actions or Behavior

[8] ENSURE 1-HS-68-341H, BACKUP HEATER C [1-M-4], is ON, RO to equalize RCS-Pzr CB.

[9] MONITOR the following parameters:

Instrument Location Parameters 1-Pl-62-122 1-M-6 VCT PRESS 1-Ll-82-129A 1-M-6 VCT LEVEL 1-Fl-432-139 1-M-6 BA TO BLENDER FLOW RO l-M-6 1-FQ-62-139 BA BATCH COUNTER i-Fl-62.-i42 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 PW BATCH COUNTER 1-Ll-62-238 1 -M6 BAT A LEVEL 1-Ll-62-242 1 -M-6 BAT C LEVEL

[10] MONITOR NIS and Rod movement to verify expected RO response.

[11] IF 1-Ll-62-129A, VCT LEVEL, rises to 63% THEN ENSURE RO 1 -FCV-62-1 1 8A, LETDOWN DIVERT TO HUT, diverts to the HUT.

[12] WHEN Boration is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

[12.1] ENSURE 1-FC-62-142, PW TO BLENDER, on 35%

(7ogpm) and Manual-Auto toggle in AUTO.

[12.2] ADJUST 1-FC-62-139, BA TO BLENDER, to new RO RCSCB.

[12.3] PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO.

[12.4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

A. CHECK Red light is LIT.

[13] IF required to flush affected piping, THEN GO TO Section 6.3.

RO

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 &2 Page 3 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time I Position Applicants Actions or Behavior Evaluator Note: Following Steps are from 801-62.02 Boron Concentration Control, Section 6.3 starting with step 3 (steps 1 & 2 are N/A)

[3] ENSURE 1-FC-62-142, PW TO BLENDER dial [1-M-6], set to RO 35% (70 gpm), or other setting as specified in approved instruction, and Manual-Auto toggle in AUTO.

[4] ADJUST 1-FQ-62-142, PW BATCH COUNTER [1-M-6], for RO required quantity.

[5] PLACE 1-HS-62-140B, VCT MAKEUP MODE [1-M-6], in R

ALT DIL.

RO [6] PLACE 1-FCV-62-128, MAKEUP TO VCT INLET, in CLOSE.

[7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL [1-M-6], to RO START.

[7.1] CHECK Red light is UT.

[8] ENSURE 1-HS-68-341H, BACKUP HEATER C [1-M-4], is RO ON to equalize RCS-Pzr CB.

[9] MONITOR the following parameters:

Instrument Location Parameters 1-PI-62-122 1-M-6 VCT PRESS 1-U-62-129A 1-M-6 VCT LEVEL RO 1-Fl-62-142 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 1-M-6 PW BATCH COUNTER 1-FQ-62-139 1-M-6 BA BATCH COUNTER

[10] MONITOR NIS and Rod movement to verify expected RO response.

[11] IF 1-Ll-62-129A, VCT LEVEL [1-M-6], rises to 63%, THEN RO ENSURE 1-FCV-62-118A, LETDOWN DIVERT TO HUT

[1-M-6], diverts to HUT.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario# 2 Event# 1 &2 Page 4 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time Position Applicants Actions or Behavior

[12] WHEN alternate dilution is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

[12.1] ENSURE 1-FC-62-142, PW TO BLENDER, on 35% (7ogpm) and Manual-Auto toggle in AUTO.

[12.2] ADJUST 1-FC-62-139, BA TO BLENDER, to new RCS CB.

[12.3] PLACE 1-HS-62-140B, VCT MAKEUP MODE, in RO AUTO.

[12.4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

A. CHECK Red light is LIT.

[12.5] ENSURE 1-HS-62-128, MAKEUP to VCT INLET, in P-AUTO.

Evaluator Note: Following Steps are from GO-4, Normal Power Operation, Section 5.3 Beginning at step 1.

. [1] Operations Superintendent has authorized load reduction.

SRO

[2] REVIEW of Precautions and Limitations Section 3.0 CREW COMPLETE.

[3] IF reducing power for compliance to LCO 3.7.1, SRO Step is N/A

[4] NOTIFY RADIATION PROTECTION of impending load SRO reduction.

[5] REQUEST Chemistry evaluate status and flowrate of the following for the impending load reduction:

SRO

Steam Generator Blowdown.

Condensate Polishers.

[6] NOTIFY COND Dl Operator of load reduction and to remove BOP beds as needed.

SRO [7] NOTIFY Load Coordinator of impending load reduction.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 &2 Page 5 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time U Position Applicants Actions or Behavior RO [8] ENSURE letdown flow is maximized.

Evaluator Note:

Letdown may not be maximized due to the unit not being shutdown for an outage.

[9] DETERMINE the CPL and Rate of power reduction restrictions from Tl-45, Determination of Preconditioned SRO Reactor Power, AND RECORD in narrative log and below:

Rate of power reduction.

[10] INITIATE load reduction by PERFORMING the following on the Turbine EHC panel:

[10.1] IF during any of the following steps the REFERENCE changes in an undesired manner, THEN

PUSH TURBINE MANUAL to place the turbine control mode in manual mode and proceed to section 5.6.

[10.2] PUSH REFERENCE CONTROL V (lower) button to set desired load in SETTER display.

[10.3] SET LOAD RATE as required.

[10.4] PUSH GO button.

[10.5] MONITOR Generator Megawatts DROPPING.

BOP [10.6] CHECK that load change has STOPPED when reference display equals setter.

OR IF desired to stop the load change, THEN STOP the load change by DEPRESSING the HOLD pushbutton.

[10.7] WHEN desired to resume the load change, THEN PRESS the GO push button and continue to monitor load.

[10.8] ADJUST VALVE POSITION LIMIT to 5% above the Gov Control Indication or as needed.

[10.9] REPEAT Steps 5.3[10.2] to 5.3[10.5] to achieve desired load.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 1 &2 Page 6 of 47 Event

Description:

Reduce Plant Load 100% to 97% for Turbine Valve Testing Time D Position I Applicants Actions or Behavior

[11] MONITOR the following during the load reduction:

[11.1] TAVG following TREE program.

RO [1 1.2] All RPIs, Step Counters, Loop AT, and NIS for correct power distribution, quadrant power tilts, rod insertion, rod misalignment, inoperable RPIs, and inoperable rods.

RO Insert Control Rods as necessary to maintain Tavg Tref.

EVALUATOR Lead Examiner, at his discretion, may cue the console operator to NOTE: implement TRIGGER 1 to fail EHC.

THE FOLLOWING ARE EXPECTED ACTIONS FOR THE BOP TO MITIGATE THE FAILURE.

Diagnoses that the Main Turbine load reduction does not stop as desired and takes action lAW GO-4 Section 5.3 step (10.1):

[10.1] IF during any of the following steps the REFERENCE BOP changes in an undesired manner, THEN PUSH TURBINE MANUAL to place the turbine control mode in manual mode and proceed to section 5.6.

Evaluator Note: If further load reduction is required, the SRO will direct the BOP to utilize GO-4 Section 5.6. Steps listed below:

[1] IF turbine controls are NOT in TURBINE MANUAL mode AND TURBINE MANUAL mode is desired, THEN BOP

PRESS TURBINE MANUAL button in TURBINE MODES_group.

[2] INITIATE load reduction by PERFORMING the following on the Turbine EHC panel;

[2.1] MOMENTARILY PRESS the lower button (GV) in the BOP TURBINE MANUAL group.

[2.2] MONITOR REFERENCE DROP.

[2.3] REPEAT Steps 5.6[2.1] to 5.6[2.2] achieve desired load.

Lead Examiner may direct initiation of the next event at his discretion

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Page 7 of 47 Event

Description:

A-A ERCW Pump Trip Time Position ft Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 2 (Trigger 2)

Indications available:

Alarm 223A ERCW Hdr A Sup Press Lo Alarm 226E ERCWICCS Motor Tripout.

Alarm 144A Ice Cond Inlet Door Open A ERCW Sup Hdr Press O-PI-67-18A reading 0 psig Crew Diagnose A-A ERCW Pump trip.

May take PRUDENT Operator action lAW TI-12.04 to start a BOP A train ERCW Pump (B-A, E-A, or F-A).

Direct crew actions lAW AOl-13 LOSS OF ESSENTIAL RAW SRO COOLING WATER.

Evaluator Note: Following Steps are from AOl- 13 LOSS OF ESSENTIAL RAW COOLING WATER, section 3.2.

1. START redundant ERCW Pump.

BOP

2. ENSURE header pressures and flows return to expected BOP values for existing plant conditions.

3. ENSURE pump amps NORMAL.

BOP

4. PLACE failed pump HS in PULL TO LOCK.

BOP

5. DISPATCH personnel to determine reason for pump failure.

BOP

6. Locally CLOSE discharge valve on failed pump.

BOP

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Page 8 of 47 Event

Description:

A-A ERCW Pump Trip Time Position Applicants Actions or Behavior

7. ENSURE applicable emergency power selector switch selected away from failed pump.

BOP

8. INITIATE repair.

RO

9. REFER TO Tech Spec 3.7.8, Essential Raw Cooling Water System (ERCW).

LCO 3.7.8 Two ERCW trains shall be OPERABLE.

APPLICABILITY: MODES 1,2,3, and 4.

SRO SRO determines that two trains of ERCW are still operable

18. INITIATE repairs to failed equipment.

SRO When Tech Specs have been addressed, or at Lead Examiners discretion, proceed to the next event.

N N N

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 9 of 47 Event

Description:

Turbine Impulse pressure 1-PT-i -73 fails low Time I Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 3 (Trigger 3)

Indications available:

Alarm 66A C-5 Lo Turb Impulse Press Rod Block Alarm 94A Tavg-Tref Deviation

% HP Turbine Power Tr A 1-Pl-1-73 reads 0%

Rods insert if in Auto.

Should immediately diagnose that Control Rods are inserting and there is not either a Turbine Runback or an OPAT or OTAT RO Runback in progress and then take manual control of Control Rods to stop the rod insertion.

Direct crew actions lAW AOI-2 MALFUNCTION OF SRO REACTOR CONTROL SYSTEM.

Evaluator Note: Following Steps are from AOI-2 MALFUNCTION OF REACTOR CONTROL SYSTEM , section 3.2.

1. PLACE control rods in MAN.

RO

2. CHECK control rod movement STOPPED.

RO Evaluator Note: SRO should eventually direct withdrawal of control rods out to their origi I al position is maintaining T-ref IT-avg.

3. MAINTAIN T-avg on PROGRAM. Reference Attachment 1

USE control rods.

RO OR

ADJUST turbine load.

4. CHECK loop T-avg channels NORMAL.

RO RO 5. CHECK Auct Tavg NORMAL on 1 -TR-68-2B.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page 10 of 47 Event

Description:

Turbine Impulse pressure 1-PT-1-73 fails low Time Position Applicants Actions or Behavior

6. CHECK NIS power range channels NORMAL.

RO

7. CHECK the following:

. Turbine impulse pressure channel 1-PI-1-73, NORMAL.

. Tref and Auct Tavg NORMALon 1-TR-68-2B (Reference Attachment 1).

PLACE steam dumps in pressure mode as follows:

BOP a. PLACE steam dumps to OFF.

b. PLACE mode selector HS to STEAM PRESS.

c. ADJUST steam dump demand to zero.

d. PLACE steam dumps to ON.

e. ENSURE controller set at 84% (1092 psig).

f. WHEN conditions allow, THEN REFER TO SOI-1 .02 and PLACE steam dumps in TAVG Mode.

8. MONITOR core power distribution parameters:

. Power range channels.

. A Flux Indicators.

. T-avg.

RO

LoopT.

Incore TCs.

Feed flow/Steam flow.

9. INITIATE repairs to failed equipment.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 3 Page ii of 47 Event

Description:

Turbine Impulse pressure 1-PT-i -73 fails low Time Position Applicants Actions or Behavior

10. REFER TO Tech Specs:

SRO enters LCO 3.3.1.16. f Condition S.

Lead Evaluator Note: When Tech Specs are addressed or at the Lead Evaluators discretion go to the next event.

Evaluator Note: Steps 11 to 14 of AOI-2 have been omitted due to being N/A

15. RETURN TO Instruction in effect.

SRO

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 4&5 Page 12 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Events 4 & 5 (Trigger 4)

Indications available:

Alarm 100D RCP Seal Leakoff Flow Hi.

Review ARI-100D:

[1] VERIFY high leakoff flow condition of affected RCP(s) with the following instruments:

RCP RECORDER PEN ICS POINT 1 1-FR-62-24 Red F1O18A 2 1-FR-62-24 Green F1O2OA 3 1-FR-62-50 Red F1022A RO 4 1-FR-62-50 Green F1024A

[2] IF high leakoff is confirmed. THEN GO TO AOI-24, RCP Seal Abnormalities During Pump Operation High leakoff should be confirmed on #2 RCP Direct crew actions lAW AOI-24 RCP MALFUNCTIONS SRO DURING PUMP OPERATION.

Evaluator Note: Following Steps are from A 01-24 RCP MALFUNCTIONS DURING PUMP OPERATION section 33.

NOTES:

Anytime #1 seal leakoff flow exceeds the values shown on Attachment 1, system engineering should be requested to perform an evaluation of the #1 seal condition.

During plant startup after seal maintenance, the #1 seal may require 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months of run time before the seal seats fully and operates normally.

The #1 seal return should be isolated between 3 and 5 minutes after tripping an RCP to allow for pump coastdown.

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 4&5 Page 13 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time I Position Applicants Actions or Behavior

1. MONITOR #1 seal leakoff equal to or greater than 6.0 gpm.

RO

2. MONITOR RCPs lower bearing and #1 seal outlet temp RO STABLE or DROPPING.

Evaluator Note: When Operations Management is notified, the direction will be to perform a rapid load reduction at 2%/mm.

AOl-39, Rapid Load Reduction steps are listed below after step 8 of AOl-24.

3. REFER TO appropriate instruction to initiate a controlled shutdown to Mode 3 while continuing with this instruction:

. AOI-39, Rapid Load Reduction.

. GO-4, Normal Power Operation.

GO-5, Unit Shutdown From 30% Reactor Power to Hot Standby.

4. REMOVE RCP from service:

. Within 8 hrs, OR

. As directed by Plant Management.

Evaluator Note: ATTACHMENT2, RCP Immediate Shutdown Criteria are at the end of this events documents.

5. MONITOR RCP immediate shutdown required:

. REFER TO ATTACHMENT 2, RCP Immediate Shutdown Criteria.

If criteria exceeded:

GO TO Subsection 3.2, Step 2.

6. ADJUST seal injection flow to exceed total #1 seal leakoff rate.

7. CONTACT System Engineer for further guidance WHILE continuing this Instruction:

. Recommendations for continued RCP operation.

. Installation of alternate flow measuring equipment (flows_greater_than_6_gpm).

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 4&5 Page 14 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time I Position Applicants Actions or Behavior

8. CHECK seal injection flow between 8 and 13 gpmIRCP.

Evaluator Note: Below is the first step in A 01-39 to commence a load reduction. The Turbine is presently in Manual due to the previous EHC control problem. G0-4 section 5.6 Operating the Turbine Controls in Manual Mode are listed in the next step.

1. ESTABLISH a turbine load reduction rate less than or equal to 5%/mm:

a. SET a desired load in the SETTER with the REFERENCE CONTROL.

b. SET the LOAD RATE at less than or equal to 5%/mi n.

c. DEPRESS GO pushbutton.

Since the Turbine controls are in Manual, the SRO should direct the following G0-4 actions:

BOP 5.6 Operating with Turbine Controls in Manual Mode NOTES

1) This section should only be used when the OPERATOR AUTO mode is malfunctioning and the turbine is online.

2) When the turbine controls are in MANUAL mode the active Turbine Manual buttons will be illuminated.

3) Turbine load changes immediately when a raise or lower button is pressed.

4) Brief momentary button presses are best for making small load changes.

5) Raising and Lowering load contained in steps 5.6121 and 5.6[3] below may be used alternatively to achieve desired load.

[1] IF turbine controls are NOT in TURBINE MANUAL mode AND TURBINE MANUAL mode is desired, THEN PRESS TURBINE MANUAL button in TURBINE MODES group.

BOP Step is N/A

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4&5 Page 15 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time Position Applicants Actions or Behavior

[2] INITIATE load reduction by PERFORMING the following on the Turbine EHC panel

[2.1] MOMENTARILY PRESS the lower button (GV) in the TURBINE MANUAL group.

BOP

[2.2] MONITOR REFERENCE DROP.

[2.3] REPEAT Steps 5.6[2.1] to 5.6[2.2] achieve desired load.

Evaluator Note: Remainder of AOI-39 Rapid Load Reduction steps are listed below, starting in section 3.2.

2. INITIATE a manual boration:

a. DETERMINE recommended boration flowrate and volume from table below.

TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER

(%/min) (gallmin) FROM 100% TO 20%

2% 2OGPM 3% 30 GPM 800 GALs 4% 40 GPM TOTAL

b. INITIATE boration to maintain control rods above low-low insertion limit:

1) ADJUST BA flow controller, 1-FC-62-139, to desired flow rate.

2) ADJUST BA batch counter 1-FQ-62-139 to required quantity.

3) PLACE mode selector 1-HS-62-140B to BOR.

4) PLACE VCT makeup control 1-HS-62-140A, to START.

5) VERIFY desired boric acid flow indicated on 1-FI 139.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4&5 Page 16 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time I Position Applicants Actions or Behavior

3. REFER TO EPIP-1, Emergency Plan Classification Flowchart.

4. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.

NOTE IF reactor power is stabilized at a lower level a drop in Tavg will occur due to Xenon build up. Dilution may be required to maintain power level.

5. MONITOR Tavg and Tref:

. Tavg trending to Tref.

Mismatch less than 5°F.

Perform RNO since Rods are in Manual:

CONTROL Tavg with Control Rods in manuaL

6. CHECK rate of power reduction is rapid enough for existing plant conditions.

7. NOTIFY Cnds Demin AUO of impending pmp shutdowns.

8. WHEN rated thermal power change exceeds 15% in one hour, NOTIFY Chemistry to initiate 1-SI-68-28.

Lead Evaluator Note: Cue console operator to implement the next event at your_discretion.

9. WHEN between 70 and 75% power, THEN REMOVE one Cnds Bstr Pmp and one Cnds Demin Pmp from service:

. PLACE selected Cnds Bstr Pmp handswitch to STOP.

. PLACE selected Cnds Demin Pmp handswitch to STOP, and CLOSE the suction valve.

Evaluator Note: No more AOI-39 steps are included.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 4&5 Page 17 of 47 Event

Description:

RCP Seal degradation and Rapid Load Reduction Time Position Applicants Actions or Behavior AOI-24 WBN RCP MALFUNCTIONS DURING Revision 28 PUMP OPERATION Page 28 of 29 ATTACHMENT 2 RCP IMMEDIATE SHUTDOWN CRITERIA Page 1 of 1 NOTE Exceeding any of the following setpoints will require an immediate pump shutdown. Operating limits can be found in SOI-68.02. This list is immediate shutdown criteria only.

A. Shaft vibration greater than 20 mils or 15 mils with a rate of rise equal to 1 mil/hr (alarm at 15 mils). [Indicators located on 0-PNL-52-R139, Aux Inst Rm.]

B. Frame vibration greater than 5 mils or 3 mils with a rate of rise of 0.2 mil/hr. [Readings taken by Maint. at Aux Bldg L-Panels, el.737.j C. Motor windings temp greater than 302°F.

D. Motor bearing temp greater than 195°F.

E. Pump bearing temp greater than 225°F.

F. Loss of CCS to oil coolers for greater than 10 minutes.

G. No. I seal outlet temp greater than 225°F.

H. No. I seal flow HIGH with rising pump bearing or #1 seal leakoff temperatures.

I. No. 1 seal AP less than or equal to 200 psid.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 6 Page 18 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time , Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 6 (Trigger 5)

Indications available:

Alarm 90B PZR PRESS LO-DEVN BACKUP HTRS ON.

Alarm 91 A PZR PORV/SAFETY OPEN.

RCS Pressure Lowering.

PZR PORV 1-PCV-68-334 indicates open.

Crew Diagnose PZR PORV 1-PCV-68-334 fails open.

Should take PRUDENT Operator action lAW Tl-12.04 to take control of 1-PCV-68-334 and place 1 HS-68-334A to CLOSE.

RO Since the PORV has failed, the RO will CLOSE the Block valve for PORV 334.

Evaluator Note: The crew may go to AOl-i 8, AOl-6 or they may take action lAW ARI-91A. The following steps are from ARI-91A:

[1] CHECK PZR pressure to determine if PZR PORV/Safety should be open.

[2] CHECK other indications to determine if PZR PORV or Safety is open:

Windows 89-A and 89-B

Tl-68-330 {1-M-41 Safety

TI-68-329 [1-M-4] Safety

Tl-68-328 [1-M-4] Safety

Tl-68-331 [1-M-4] - PORV

[3] ENSURE PZR PORV and Safeties CLOSED when PZR pressure is below lift setpoint.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 2 Event# 6 Page 19 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time . Position Applicants Actions or Behavior

[4] IF PZR PORV is NOT closed when PZR pressure is below lift setpoint, THEN

[a] CLOSE associated PZR PORV block valve.

[b] NOTIFY SRO.

[c] REFER TO Tech Specs.

Evaluator Note: Following Steps are from AOI-18 MALFUNCTION OF PRESSURIZER PRESSURE CONTROL SYSTEM , section 3.0.

1. CHECK pressurizer pressure stable or trending to desired pressure:

PI-68-340A, RO

P1-68-334,

P1-68-323,

P1-68-322.

2. CHECK 1-XS-68-340D selected to a failed, controlling or backup channel.

RO Perform RNO:

IF pzr press is abnormally low, THEN GO TO Step 6.

6. CHECK pzr spray valves CLOSED:

Green indicating lights LIT.

RO

Pzr spray demand meters, 1-PIC-68-340B and 1-PlC-68-340D indicating ZERO [1-M-4].

7. CHECK pzr PORVs CLOSED:

EVALUATE tailpipe temperatures and acoustic monitor.

RO Perform RNO:

CLOSE associated block valve.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 6 Page 20 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time Position Applicants Actions or Behavior

8. CHECK pzr Safeties CLOSED:

EVALUATE tailpipe temperatures and acoustic RO monitor.

9. ENSURE pzr heaters on as required:

Control Group on at 2220 psig.

RO

. Backup Groups on at 2210 psig.

10. CHECK aux spray, 1-FCV-62-84, CLOSED.

SRO

11. CHECK pzr press STABLE or RISING.

SRO

12. GO TO Step 16.

16. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:

RO

Pzr Master controller,

Pzr spray controllers,

. All heater groups.

17. REFER TO the following Tech Specs:

3.4.1 1, Pressurizer Power Operated Relief Valves.

B. One PORV inoperable B.1 Close associated block valve. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being SRO manually cycled. AND B.2 Remove power from associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months block valve.

AND B.3 Restore PORV to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 6 Page 21 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time I Position H Applicants Actions or Behavior

18. INITIATE repairs to failed equipment.

SRO Evaluator Note: Following Steps are from AOI-6.

Note:

During performance of this instruction the need for a rapid load reduction or Unit trip should be continuously evaluated.

1 CHECK pzr level DROPPING.

RO NOTE:

VCT makeup may have to be manually initiated or makeup rate raised to maintain VCT level.

Pzr level must be allowed time to change following changes in charging flow.

2 CHECK COP in service.

RO 3 MAXIMIZE charging flow:

a. Fully OPEN 1-FCV-62-93.

b. Fully OPEN 1-FCV-62-89.

c. IF letdown at 120 gpm THEN RO PLACE 1-HIC-62-81A, in MANUAL, AND CLOSE 1-FCV-62-72, (45 gpm).

d. ADJUST 1-HlC-6281A as required AND PLACE in AUTO.

4. IF RHR Shutdown Cooling mode in service, THEN US GO TO AOl-14, Loss of RHR Shutdown Cooling.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event# 6 Page 22 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time Position Applicants Actions or Behavior

5. MAKE plant announcement via PA:

Attention plant personnel. A primary system leak has developed. Any personnel located either inside containment US or in the Auxiliary Building should exit the area immediately.

(Repeat)

6. MONITOR pzr level STABLE or RISING.

RO Caution:

Attempts to quantify leak rate should not delay performance of the remaining steps.

7. IF pzr level STABLE or RISING and time permits, THEN STABILIZE the plant to quantify the leak rate:

RO

STOP pzr heater/spray operation.

STOP any heatup/cooldown in progress.

8. CHECK secondary plant radiation normal:

Condenser exhaust monitors.

BOP

S/G blowdown monitors.

Main steam line monitors.

9. CHECK safety valves CLOSED:

RO

EVALUATE tailpipe temp and acoustic monitors.

10. CHECK PORVs CLOSED:

EVALUATE tailpipe temp and acoustic monitors.

RO Perform RNO:

CLOSE leaking PORV block valve.

REFER TO Tech Spec 3.4.1 1, Pressurizer Power Operated Relief Valves.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 6 Page 23 of 47 Event

Description:

PZR PORV 1 -PCV-68-334 fails open Time Position Applicants Actions or Behavior Goes to Step 20.

20. MAINTAIN pzr level on program.

RO

21. (Directs SM to) REFER TO EPIP-1, Emergency Plan Classification Flowchart:

US a. DETERMINE classification of event, and

b. INITIATE manning the TSC. (if necessary)

Evaluator Note: Steps 22-31 of AOI-6 are not applicable.

32. EVALUATE continued operation:

Cntmt conditions.

RCP status.

US

Leakage within Tech Spec 3.4.13, RCS Operational Leakage limits.

S/G and secondary plant leakage.

33. RETURN TO Instruction in effect.

US When Tech Specs have been addressed, or at Lead Examiners discretion, proceed to the next event.

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 24 of 47 Event

Description:

AOl-6 E-O SBLOCA Time I Position I Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 7 (Trigger 6)

Indications available:

Alarm 96C RCP 2 Stand Pipe Hi Level.

PZR Level Lowering.

VCT Level Lowering.

The crew should diagnose that the RCP seal leak has Crew worsened to the point that AOI-6 SMALL REACTOR COOLANT SYSTEM LEAK procedure should be implemented.

May take PRUDENT Operator action lAW Tl-12.04 to take RO manual control charging and raise charging flow.

SRO Direct crew actions lAW AOI-6 SMALL REACTOR COOLANT SYSTEM LEAK.

Evaluator Note: Following Steps are from AOl-6 SMALL REACTOR COOLANT SYSTEM LEAK, section 3.0. Steps 1 thru 13 are included, however, it is not expected that the crew will progress to step 13 prior to performing a manual reactor trip due to PZR Level trend.

1. CHECK pzr level DROPPING.

2. CHECK CCP in service.

3. MAXIMIZE charging flow:

a. Fully OPEN 1-FCV-62-93.

b. Fully OPEN 1-FCV-62-89.

c. IF letdown at 120 gpm THEN PLACE 1-HIC-62-81A, in MANUAL, AND CLOSE 1FCV-62-72, (45 gpm).

d. ADJUST 1-HIC-62-81A as required AND PLACE in AUTO.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 25 of 47 Event

Description:

AOl-6 E-O SBLOCA Time Position A Applicants Actions or Behavior

4. IF RHR Shutdown Cooling mode in service, THEN GO TO AOl-14, Loss of RHR Shutdown Cooling.

5. MAKE plant announcement via PA:

Attention plant personnel. A primary system leak has developed. Any personnel located either inside containment or in the Auxiliary Building should exit the area immediately. (Repeat)

Evaluator Note: The crew should perform AOl-6 Step 6 RNO when the RCS leak worsens to the point that loss of PZR Level is imminent. When the crew manually trips the reactor, E-O steps are located past step 13 of AOI-6.

6. MONITOR pzr level STABLE or RISING.

Perform RNO (when required)

IF loss of pzr level is IMMINENT, THEN:

a. TRIP Rx.

b. INITIATE SI.

c. ** GO TO E-O, Rx Trip Safety Injection.

7. IF pzr level STABLE or RISING and time permits, THEN STABILIZE the plant to quantify the leak rate:

STOP pzr heater/spray operation.

STOP any heatup/cooldown in progress.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 7 Page 26 of 47 Event

Description:

AOl-6 E-0 SBLOCA Time - Position Applicants Actions or Behavior

8. CHECK secondary plant radiation normal:

Condenser exhaust monitors.

S/G blowdown monitors.

Main steam line monitors.

9. CHECK safety valves CLOSED:

EVALUATE tailpipe temp and acoustic monitors.

10. CHECK PORVs CLOSED:

EVALUATE tailpipe temp and acoustic monitors.

11. MONITOR PRT conditions NORMAL:

Level.

Temperature.

Press.

12. ISOLATE letdown:

CLOSE 1-FCV-62-72, (45 gpm).

CLOSE 1-FCV-62-73, (75 gpm).

CLOSE 1-FCV-62-74, (75 gpm).

CLOSE 1FCV..62-76, (5 gpm).

CLOSE 1-FCV-62-69.

CLOSE 1-FCV-62-70.

13. ISOLATE charging:

CLOSE 1-FCV-62-85.

CLOSE 1-FCV-62-86.

CLOSE 1-FCV-62-90.

CLOSE 1 -FCV-62-91.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 27 of 47 Event

Description:

AOl-6 E-O SBLOCA Time Position Applicants Actions or Behavior Evaluator Note: The following are steps from E-O:

lAW AOI-6 Step 6, SRO directs RO to manual trip the Reactor, VERIFY that the Reactor Trips, then manually SRO actuate Safety Injection.

Manual trip the Reactor, VERIFY that the Reactor Trips.

RO Manually actuate Safety Injection.

RO Evaluator Note: The following are steps from E-O.

NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

NOTE 2 Status Trees I SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RO

RPIs at bottom of scale.

Neutron flux DROPPING.

2. ENSURE Turbine Trip:

RO

All turbine stop valves CLOSED.

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:

RO CSST (offsite), OR D/G (blackout).

4. CHECK SI actuated:

a. Any SI annunciator LIT.

b. Both trains SI ACTUATED.

RO

1 -XX-55-6C

1 -XX-55-6D

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 28 of 47 Event

Description:

AOI-6 E-O SBLOCA Time Position Applicants Actions or Behavior US and RO Evaluator Note:

After the immediate operator actions of E-0 are complete the crew should realize that the #2 RCP should be secured via AOl-24 section 3.2 step 5 & 6 RNO direction since its seal leakoff is exceeding limits. Its associated Pzr spray valve should be closed. Three to five minutes after securing the #2 RCP seal return valve 1-FCV 22 should be isolated.

BOP Evaluator Note: Appendix A (E-0), SI Support Systems, and Appendix B, Phase B Pipe Break Contingencies are contained at the end of this document.

Appendix A contains the procedure steps which direct actions associated with both Critical Steps for this scenario. It is expected however, that prior to performing Appendix A, the crew will recognize the malfunctioning equipment and take PRUDENT Operator action lAW TI-12.04 to:

1- Start both SI Pumps and 2- Manually initiate both trains of Phase B.

BOP

5. EVALUATE support systems:

REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28.

6. ANNOUNCE reactor trip and safety injection over PA BOP system.

7. ENSURE secondary heat sink available with either:

RO

Total AFW flow greater than 410 gpm, OR

At least one S/G NR level greater than 29% [39%

ADV].

8. MONITOR RCS temp stable at or trending to 557°F:

I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 7 Page 29 of 47 Event

Description:

AOl-6 E-0 SBLOCA Time H Position Applicants Actions or Behavior

IF any RCP running, THEN MONITOR RCS Loop T avg trending to 557°F.

OR

IF NO RCP running, THEN MONITOR RCS Loop T cold trending to 557°F.

9. ENSURE excess letdown valves CLOSED:

BOP

1-FCV-62-54

1-FCV-62-55 V

10. CHECK pzr PORVs and block valves:

RO a. Pzr PORVs CLOSED.

b. At least one block valve OPEN.

1 1. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic RO monitors.

12. CHECK pzr sprays CLOSED.

RO

13. CHECK if RCPs should remain in service:

a. Phase B signals DARK [MISSP].

RO V Perform RNO:

a. STOP all RCPs. ** GO TO Step 14.

14. CHECK S/G pressures:

All SIG pressures controlled or rising.

RO

All S/G pressures greater than 120 psig.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 7 Page 30 of 47 Event

Description:

AOI-6 E-0 SBLOCA Time Position Applicants Actions or Behavior

15. CHECK for RUPTURED SIG

All S/Gs narrow range levels CONTROLLED or RO DROPPING.

Secondary side radiation NORMAL from Appendix A.

16. CHECK cntmt conditions:

Cntmt pressure NORMAL.

Radiation NORMAL from Appendix A.

BOP

Cntmt sump level NORMAL.

Cntmt temp ann window DARK [1 04-B].

Perform RNO:

GO TO E-1, Loss of Reactor or Secondary Coolant.

Evaluator Note: SRO should direct the crew to GO TO E-1 at this point. The following steps are from E-1.

1. CHECK if RCPs should remain in service:

a. Phase B DARK [MISS P].

RD

b. RCS pressure greater than 1500 psig.

RNO already performed

2. REFER TO EPIP-1, Emergency Plan Classification SRO Flowchart.

3. RECORD current time to mark initiation of LOCA and SRO determination of time for hot leg recirc.

4. CHECK SIG pressures:

All SIG pressures controlled or rising.

BOP

All S/Gs pressures greater than 120 psig.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 7 Page 31 of 47 Event

Description:

AOl-6 E-0 SBLOCA Time I Position Applicants Actions or Behavior

5. MAINTAIN Intact S/G NR levels:

a. MONITOR levels greater than [39% ADV].

BOP b. CONTROL intact SIG levels between [39% and 50%

ADV].

6. CHECK secondary radiation:

S/G discharge monitors NORMAL.

BOP

Condenser vacuum exhaust rad monitors NORMAL.

SIG blowdown rad monitor recorders NORMAL trend prior to isolation.

7. ENSURE cntmt hydrogen analyzers in service:

PLACE 1-HS-43-200A in ANALYZE [M-10].

PLACE 1-HS-43-210A in ANALYZE [M-10].

BOP

CHECK low flow lights not lit [M-10].

Locally CHECK low analyzer temp lights NOT lit

[North wall of Train A 480V SD Bd rmj.

8. MONITOR pzr PORVs and block valves:

RO a. Pzr PORVs CLOSED.

b. At least one block valve OPEN.

9. DETERMINE if cntmt spray should be stopped:

a. MONITOR cntmt pressure less than 2.0 psig.

b. CHECK at least one cntmt spray pump RUNNING.

c. RESET cntmt spray signal.

RO

d. STOP cntmt spray pumps, and PLACE in A-AUTO.

e. CLOSE cntmt spray discharge valves 1-FCV-72-2 and 1 -FCV-72-39.

10. ENSURE both pocket sump pumps STOPPED [M-15]:

BOP

1-HS-77-410.

1-HS-77-411.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 32 of 47 Event

Description:

AOI-6 E-O SBLOCA Time I Position Applicants Actions or Behavior 1 1. CHECK SI termination criteria:

a. CHECK RCS subcooling greater than [85°F ADV].

RO Perform RNO:

a. GO TO Caution prior to Step 12.

12. RESET SI and CHECK the following:

SI ACTUATED permissive DARK.

RO

AUTO SI BLOCKED permissive LIT.

13. DETERMINE if RHR pumps should be stopped:

a. CHECK RCS pressure greater than 150 psig.

b. CHECK RHR suction aligned from RWST.

RO c. CHECK RCS pressure stable or rising.

d. STOP RHR pumps and PLACE in A-AUTO.

e. MONITOR RCS pressure greater than 150 psig.

14. CHECK pressure in all S/Gs controlled or rising.

RO

15. CHECK RCS pressure stable or dropping.

RO

16. MONITOR electrical board status:

a. CHECK offsite power available.

b. CHECK all shutdown boards ENERGIZED by offsite BOP power.

c. PLACE any unloaded D/G in standby USING SQl 82 Diesel Generators.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 33 of 47 Event

Description:

AOI-6 E-0 SBLOCA Time Position I Applicants Actions or Behavior EVALUATOR NOTE: AOl-17, Turbine Trip BOP realignment steps are at the end of this document.

17. INITIATE BOP realignment:

BOP

REFER TO AOl-17, Turbine Trip.

18. INITIATE 480V board room breaker alignments USING the following:

Appendix A (E-1), CLA Breaker Operation.

Appendix B (E-1), Ice Condenser AHU Breaker BOP Operation.

Appendix C (E-1), 1-FCV-63-1 Breaker Operation.

Appendix D (E-1), 1-FCV-63-22 Breaker Operation.

19. DETERMINE if hydrogen igniters should be energized:

a. CHECK hydrogen analyzers in service.

b. CHECK cntmt hydrogen less than 5% [M-1O].

BOP c. ENERGIZE hydrogen igniters [M-10]:

1-HS-268-73 ON.

1-HS-268-74 ON.

20. ENSURE RHR available for cntmt sump recirculation:

Power to at least one operable RHR pump AVAILABLE.

RO

Cntmt sump valve 1-FCV-63-72 or 1-FCV-63-73 to operable RHR pump AVAILABLE.

EVALUATOR NOTE: Appendix E (E-1), Equipment Evaluation is located at the back of this section.

21. EVALUATE plant equipment status:

SRO

REFER TO Appendix E (E-1), Equipment Evaluation.

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 7 Page 34 of 47 Event

Description:

AOl-6 E-O SBLOCA Time Position Applicants Actions or Behavior

22. CHECK Aux Bldg radiation for loss of RCS inventory outside cntmt:

a. Area monitor recorders 1-RR-90-1 and O-RR-90-12 Aux BOP Bldg points NORMAL.

b. Vent monitor recorder O-RR-90-1O1 NORMAL trend prior to isolation.

23. NOTIFY Chemistry of event status and plant conditions.

SRO

24. DETERMINE if RCS cooldown and depressurization is required:

RO a. CHECK RCS pressure greater than 150 psig.

b. ** GO TO ES-i .2, Post LOCA Cooldown and Depressurization.

EVALUATOR NOTE: The following steps are from ES-L2, Post LOCA Cooldown and Depressurization

1. PREPARE for switchover to RHR cntmt sump:

a. RESTORE power to 1-FCV-63-1, RWSTto RHR suction, USING Appendix A, (ES-i .2) 1-FCV-63-1 Breaker Operation.

b. WHEN RWST level less than 34%, THEN ** GO TO ES-i .3, Transfer to Containment Sump.

2. RESET SI, and CHECK the following:

SI ACTUATED permissive DARK.

AUTO SI BLOCKED permissive LIT.

3. RESET Phase A and Phase B.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 35 of 47 Event

Description:

AOl-6 E-O SBLOCA Time Position 1 AoIicants Actions or Behavior

4. ENSURE cntmt air in service:

a. Aux air press greater than 75 psig [M-l5].

b. Cntmt air supply valves OPEN [M-15]:

1-FCV-32-80.

1-FCV-32-102.

1-FCV-32-11O.

5. MONITOR electrical board status:

a. CHECK offsite power available.

b. CHECK all shutdown boards ENERGIZED by offsite power.

c. CHECK all unit boards ENERGIZED.

d. PLACE any unloaded DIG in standby USING SOI-82 Diesel Generators.

6. ENSURE pzr heaters off:

PLACE Backup heaters A-A OFF.

PLACE Backup heaters B-B OFF.

PLACE Backup heaters C OFF.

PLACE Control heaters D OFF.

7. DETERMINE if RHR pumps should be stopped:

a. CHECK RHR suction aligned from RWST.

b. CHECK RCS press:

RCS press greater than 150 psig.

RCS press stable or rising.

c. STOP RHR pumps, and PLACE in A-AUTO.

d. MONITOR RCS press greater than 150 psig.

8. MONITOR Intact SIG NR levels:

a. At least one intact SIG NR level greater than 29%

[39% ADV].

b. CONTROL intact SIG levels between 29% and 50%

[39% and 50% ADV].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 36 of 47 Event

Description:

AC 1-6 E-0 SBLOCA Time Position Applicants Actions or Behavior

9. EVALUATE Motor-Driven AFW Pumps recirc flow per FOP.

10. INITIATE RCS boration to cold shutdown boron concentration:

a. DETERMINE cold shutdown CB:

REFER TO 1-Sl-0-i0, Shutdown Margin, OR REACTINW Computer Program.

b. INITIATE RCS boration:

REFER TO SOI-62.02, CVCS Boron Concentration Control.

11. MONITOR shutdown margin during RCS cooldown:

a. NOTIFY Chemistry to monitor RCS boron concentration at the following sample points:

RCS hot leg.

CVCS letdown line.

Evaluator Note: The scenario may end once the crew has addressed the 100 °F/hr cooldown lAW ES-i.2 step 12 or at the Lead Evaluators discretion.

12. INITIATE RCS cooldown to cold shutdown:

a. WHEN RCS pressure is less than 1962 psig (P-il), THEN

BLOCK low pzr pressure SI.

BLOCK low steam pressure SI.

b. MAINTAIN T-cold cooldown rate less than 100°F in one hour.

Maintains < 100 °F/hr cooldown rate.

c. DUMP steam to condenser from Intact S/Gs.

d. IF RHR in shutdown cooling mode, THEN USE RHR and S/Gs for cooling.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 7 Page 37 of 47 Event

Description:

AOl-6 E-O SBLOCA Time Position Applicants Actions or Behavior

13. CHECK RCS subcooling greater than 65°F [85°F ADVj.

14. CHECK ECCS in service:

ANY SI pump RUNNING, OR

Flow thru BIT, OR

ANY RHR pump RUNNING ECCS mode.

15. DEPRESSURIZE RCS to refill pzr:

a. CHECK pzr level less than 29% [47% ADV].

b. DEPRESSURIZE RCS with normal pzr sprays to raise ECCS injection and reduce break flow.

c. WHEN RCS pressure is less than 1962 psig (P-i 1),

THEN

BLOCK low pzr pressure SI:

BLOCK low steam pressure SI:

d. WHEN pzr level between 29% and 63% [47% and 58% ADV],

THEN STOP RCS depressurization.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 8 Page 38 of 47 Event

Description:

E-O Appendix A and B Time U Position Applicants Actions or Behavior Booth Instructor: NONE Indications: None Directs BOP to perform E-O STEP 5:

SRO 5. EVALUATE support systems:

REFER TO Appendixes A and B (E-O), Equipment Verification pages 1 5-28.

Evaluator Note: The following are E-O Appendix A steps.

Evaluator Note: The SRO may at times interrupt the BOP, during the performance of Appendixes A and B, to perform other higher priority task.

1. ENSURE PCBs OPEN:

BOP

PCB 5044.

PCB 5088.

2 ENSURE AFW pump operation:

Both MD AFW pumps RUNNING.

BOP

TD AFW pump RUNNING.

LCVs in AUTO, or controlled in MANUAL.

3. ENSURE MEW isolation:

MEW isolation and bypass isolation valves CLOSED.

MEW reg and bypass reg valves CLOSED.

MFP A and B TRIPPED.

BOP

Standby MEP STOPPED.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 8 Page 39 of 47 Event

Description:

E-O Appendix A and B Time Position Applicants Actions or Behavior

4. MONITOR ECCS operation:

a. Charging pumps RUNNING.

b. Charging pump alignment:

RWST outlets 1-LCV-62-135 and 1-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1-LCV-62-133 CLOSED.

Charging 1-FCV-62-90 and 1-FCV-62-91 CLOSED.

Critical c. RHR pumps RUNNING.

Task #1 d. SI pumps RUNNING. NO RNO Manually starts both SI Pumps.

BOP

e. BIT alignment:

Outlets 1-FCV-63-25 and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater than 1650 psig.

RNO not >l65Opsig:

f. ENSURE SI pump flow. IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

5 CHECK cntmt isolation:

a. Phase A isolation:

Train A GREEN.

Train B GREEN.

BOP

b. Cntmt vent isolation:

Train A GREEN.

Train B GREEN.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 8 Page 40 of 47 Event

Description:

E-0 Appendix A and B Time Position Applicants Actions or Behavior

6. CHECK cntmt pressure:

Phase B DARK [MISSP].

Cntmt Spray DARK [MISSP].

Cntmt press less than 2.8 psig.

Perform RNO:

Critical Task #2 PERFORM the following:

1) ENSURE Phase B actuated.

2) ENSURE Cntmt Spray actuated.

3) ENSURE cntmt spray pumps running.

BOP 4) ENSURE cntmt spray flow.

5) ENSURE Phase B isolation:

Train A GREEN.

Train B GREEN.

6) STOP all RCPs.

7) ENSURE MSIVs and bypasses CLOSED.

8) PLACE steam dump controls OFF.

9) WHEN 10 minutes has elapsed since Phase B actuated, THEN ENSURE air return fans start.

10) USE_adverse_cntmt_[ADVI_setpoints_where_provided.

7. CHECK plant radiation NORMAL:

S/G blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation [M-12j.

Condenser vacuum exhaust rad recorder 1-RR-9O 119 NORMAL prior to trip [M-12j.

1-RR-90-106 and 1-RR901 12 radiation recorders BOP NORMAL prior to isolation [M-12].

S/G main steamline discharge monitors NORMAL.

Upper and Lower containment high range monitors NORMAL [M-30j.

NOTIFY Unit Supervisor conditions NORMAL.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 8 Page 41 of 47 Event

Description:

E-O Appendix A and B Time Position Applicants Actions or Behavior 8 ENSURE all DIGs RUNNING.

BOP

9. ENSURE ABGTS operation:

a. ABGTS fans RUNNING.

b. ABGTS dampers OPEN:

FCO 1 46A.

BOP

FCO-30-146B.

FCO-30-157A.

FCO-30-157B.

10. ENSURE at least four ERCW pumps RUNNING, one on BOP each shutdown board preferred.

ENSURE ERCW supply valves OPEN to running DIGs.

BOP

12. ENSURE CCS HX C ALT DISCH TO HDR B, BOP O-FCV-67-152, is open to position A.

13. CLOSE CCS HX C DISCH TO HDR A, O-FCV-67-144.

BOP

14. MONITOR EGTS operation:

EGTS fans RUNNING.

BOP

ENSURE dampers OPEN VERIFY filter bank P between 5 and 9 inches of water.

15. ENSURE CCS pumps RUNNING:

lA-A CCS pump.

BOP

1 B-B CCS pump.

C-S OR 2B-B CCS pump.

16. CHECK CNTMT PURGE fans STOPPED:

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # 8 Page 42 of 47 Event

Description:

E-O Appendix A and B Time Position Applicants Actions or Behavior

17. CHECK FUEL HANDLING EXH fans STOPPED, Fuel and BOP Cask loading dampers CLOSED:

18. ENSURE AB GEN SUPPLY and EXH fans STOPPED.

BOP

19. ENSURE AB GEN SUP & EXH dampers CLOSED.

BOP

20. ENSURE MCR & SPREAD RM FRESH AIR dampers CLOSED:

BOP

FCV-31-3.

FCV-31-4.

21. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, OR Fan B-B BOP RUNNING.

FCO-31-8, OPEN OR FCO-31-7, OPEN.

22. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

BOP

CB EMERG PRESS FAN A-A, OR FAN B-B RUNNING.

FCO-31-6, OPEN. OR FCO-31-5, OPEN.

23. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY and EXH FANS AND BOP dampers.

TOILET & LKR RM EXHAUST FAN AND dampers.

24. INITIATE Appendix B.

BOP

Appendix D Required Operator Actions Form ES-D2 Op Test No.: NRC Scenario # 2 Event # 8 Page 43 of 47 Event

Description:

E-O Appendix A and B Time Position Applicants Actions or Behavior Evaluator Note: E-O Appendix B is listed below

1. CHECK PHASE B actuated.

BOP

2. ENSURE 1-FCV-32-11O CLOSED. (CISP XX-55-6E) [A BOP train, window 13].

3. ENSURE 1-FCV-67-107 CLOSED. (CISP 1-XX-55-6E) [A - -

BOP train, window 43].

4. ENSURE 1-FCV-70-92 CLOSED. (CISP - 1-XX-55-6E) [A -

BOP train, window 73].

5. ENSURE 1-FCV-70-140 CLOSED. (CISP 1-XX-55-6F) [B - -

BOP train, window 74].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # None Page 44 of 47 Event

Description:

AOl-17 BOP Realignment Time I Position Applicants Actions or Behavior Booth Instructor: NONE Indications: NONE Evaluator Note: The following are the first ten steps from AOI-17 Turbine Trip, it is not expected that the BOP will perform all of these steps due to other higher priority issues..

CAUTION Performance of this instruction should not be allowed to delay or interfere with actions required by applicable emergency procedures or abnormal operating procedures.

NOTE 1 Control room operators may initiate shutdown of pumps and equipment from the benchboard immediately after a trip. Performance of this instruction will subsequently verify proper secondary equipment alignment.

NOTE 2 Steps in this section and items in Affachment 1 may be performed out of sequence.

1. DISPATCH turbine building NAUO to perform Attachment 1.

BOP

2. NOTIFY condensate demineralizer NAUO prior to Operator BOP initiated press changes in condensate.

3. REMOVE generator excitation from service:

a. PLACE voltage regulator to TEST.

b. ZERO exciter base adjuster.

BOP

c. OPEN exciter field breaker.

d. PLACE exciter regulator control to OFF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # None Page 45 of 47 Event

Description:

AOI-17 BOP Realignment Time Position Applicants Actions or Behavior

4. MONITOR main turbine:

a. WHEN less than 1500 rpm, THEN:

ENSURE seal oil backup pump RUNNING.

ENSURE turning gear oil pump RUNNING.

b. WHEN less than 600 rpm, THEN ENSURE bearing lift oil pump RUNNING.

c. WHEN turbine is at ZERO RPM, THEN ENSURE turbine on turning gear.

BOP d. MAINTAIN MTOT lube oil temp between 95° and 100°F (may require RCW isolation if TCV has excessive leakage).

e. MAINTAIN GENERATOR H2 (Cold Gas) temp 95°F (may require RCW isolation if TCV has excessive leakage).

f. ENSURE Gland Steam Spillover Bypass valve is CLOSED using 1-HS-47-191A.

5. ALIGN MSRs:

a. PUSH RESET on MSR control panel.

b. CLOSE MSR HP steam and bypass isol.

BOP c. ENSURE MSR warming valves CLOSED.

d. OPEN MSR startup vents.

e. CLOSE MSR operating vents.

BOP 6. CHECK MSIVs OPEN.

7. ENSURE adequate FW press:

a. ENSURE two hotwell pumps RUNNING.

b. IF FW isolation reset, THEN ENSURE one condensate booster pump RUNNING if needed for unit conditions.

c. ENSURE CNDS demin pumps OFF.

BOP d. STOP #3 HDT pumps, and CLOSE the discharge valves to condensate heater strings. Notify NAUO performing Attachment 1 that #3 HDT pumps are stopped.

e. STOP #7 HDT pumps, and CLOSE the discharge valves to condensate heater strings.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 2 Event # None Page 46 of 47 Event

Description:

AOI-17 BOP Realignment Time H Position I Applicants Actions or Behavior

8. SHUTDOWN any MEW pump NOT BOP required.

9. SHUTDOWN any RCW pumps NOT BOP required.

10. SHUTDOWN any CCW pumps NOT BOP required.

APPENDIX E (E-1)

Page 1 of 1 EQUIPMENT EVALUATION

1. EVALUATE plant equipment and systems needed to support long term cooling and recovery actions, as time and personnel availability permits:

a. Cntmt Isolation Status.

b. Emergency Gas Treatment System:

One train in operation, REFER TO SOI-65.02.

c. Auxiliary Building Gas Treatment:

One train in operation, REFER TO SOI-30.06.

d. Auxiliary Building Isolation alignment:

REFER TO SOI-30.06.

e. Main Control Room Isolation alignment:

REFER TO SOI-.31 .01.

f. ERCW System:

Both trains in operation.

g. Component Cooling Water System:

Both trains in operation.

Appendix D Scenario Outline Form ES-D]

Facility: Watts Bar (2008-B) Scenario No.: 3 Op Test No.: 1 Examiners: Operators:

ILJ Initial Conditions: 100% power, EOL, 69 ppm boron. 1A MD AFW Pump DOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCD 3.7.5, Action B.

Turnover: Maintain current power level. However, 1A Condensate Booster Pump has a small oil leak. A power reduction to 98% is being discussed by Ops Management in order to remove the pump from service.

Event MaIf. No. Event Event Description No. Type*

1 RP26E 0 1-BOP Steam Pressure Transmitter 1-PT-1-20A fails low. BOP manually controls feed to #3 SIG. ADI-16 entry. Tech Spec evaluation.

I-SRO 2 ZA1P1C68340 C-RD 1-PIC-68-340A PZR Master Controller fails. Spray valves close RCRO5 and all heaters energize. RD manually controls PZR pressure.

TS-SRD ADI-18 entry.

3 RXO2D I- RD Loop 4 Cold Leg RTD fails high, resulting in rod insertion. Tech Spec evaluation.

I- SRO 4 CCO5B C - BOP CCS leak inside containment on thermal barrier supply line to 2 RCP. EntryintoAOl-15..

C-SRO 5 N/A R-RD Power reduction to remove 1A Condensate Booster Pump from service.

N- SRD N-BOP 6 THO5C M-ALL # 3 S/G tube leak (40 gpm). AOl-33 entry. Tech Spec evaluation.

7 THO5C M-ALL # 3 S/G tube leak progresses to a S/G tube rupture. EOP network entry.

8 ZDIRT 1 C-RD Reactor Trip Switch on 1-M-4 fails to initiate a reactor trip. RD Neutral operates 1-M-6 trip switch.

9 SIO9L C-RD Containment Phase A fails to automatically actuate. RD manual action.

SIO9M 10 MS13C M-ALL Steam leak #3 S/G @ 2%, when SI is reset in E-3 cooldown.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9, Supplement 1

Appendix D Scenario Outline Form ES-D-1 Scenario 3 Summary Initial Conditions:

The plant is stable at 100%, EOL, 69 ppm boron. 1A MD AFW Pump OOS for motor bearing replacement.

28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B. Plan is to stay at current power level. However, 1A Condensate Booster Pump has a small oil leak. A power reduction to 96% is being discussed by Ops Management for removing the pump from service. 1-PT-68-322, Channel IV Pressurizer Pressure Transmitter failed during the last shift and has been removed from service to comply with Tech Specs.

1. Steam Pressure Transmitter 1-PT-1-20A fails low. BOP takes manual control of #3 SIG feed flow to avoid a reactor trip lAW Aol-i 6 Loss of Normal Feedwater. Tech Spec evaluation.

2. i-PIC-68-340A PZR Master Controller fails, causing spray valves to close and all heaters to energize.

RO manually controls i-PIC-68-340A to control PZR pressure. Enter AOl-18 Malfunction of Pressurizer Pressure Control System.

3. Eagle-21 Rack 4 EAI board #3 loss of 15v power supply. Results in i-PT-i-73 (Turbine Impulse Pressure) and i-LT-63-i 80 (Containment Sump Level) failing low. RO manually controls. Enter AOl-44 Eagle 21 Malfunctions, and AOl-2 Malfunction of Reactor Control System. Tech Spec evaluation.

4. CCS leak occurs in containment on the supply line to the 1 B RCP Thermal Barrier. The crew enters AOl-i 5 Loss of Component Cooling Water. Requires BOP actions to isolate the leak.

5. Operations management notifies the crew that it has been decided to reduce plant load to 96% for removal of 1A Condensate Booster Pump. The crew lowers plant load lAW GO-4, Normal Power Operation.

6. A tube leak (40 gpm) occurs on # 3 S/G. Enter AOl-33, Steam Generator Tube Leak. Tech Spec evaluation.

7. The # 3 S/G tube leak progresses to a S/G tube rupture, requiring the crew to trip the reactor and enter E-0. The manual trip switch on i-M-4 fails to initiate a reactor trip. RO operates the i-M-6 trip switch.

8. When SI actuates in E-0, Containment Phase A fails to automatically actuate. RO manually actuates Phase A.

9. After transition to E-3 and during the cooldown to target temperature, a fault occurs on # 3 S/G. Crew transitions to ECA-3.i.

10. Scenario terminates when the crew has started a plant cooldown lAW ECA-3.i.

.. 1 2 Critical Tasks: Close containment Isolate steam flow and isolation valves such feedwater flow to the that at least one valve is ruptured S/G prior to closed on each critical initiation of RCS cooldown phase-A penetration to the target temperature.

before transition out of E-0.

Appendix D NUREG 1021 Revision 9, Supplement 1

Page 1 of 3 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #3 STEAM GENERATOR TUBE RUPTRE WITH FAULT EVENT I IC/MF/RF/OR #

I DESCRIPTION/FEEDBACK 1

rst 249, switch check, select RUN Sirn. Setup 100% RTP, EOL, Cb- 69 ppm. This IC contains the verify malfunctions and overrides listed overrides and triggers.

below 0 Turns off audible alarm for the simulator fault so the Disable simulator fault alarm crew cannot hear this alarm.

0 Place A Train week 1 placard on On entrance side panel.

entrance side panel.

0 Place DANGER Tag on I A MDAFW IA MDAFW out of service.

Hand Switch Indicate/Enter in the appropriate blanks Ensure EOL Reactivity Briefing Book is used. Item this information into the reactivity 3: Delta I -3 and AUTO rod control.

briefing book, (appendix B TI-7.012) Item 4: Negative, I -CCP B, 69 Item 5: 877, Boron, BA 10.2, PW 70, BA Pot 24, PW POT 35 Item 6: PW 45 gal Item 7: PW 45 gal 100% RTP, EOL, Cb- 69 ppni.

Sim Setup if IC 249 rst 60, switch check, select run.

does not work.

1A MDAFW out of service. Prevents start of pump 0 batch OOS AFWP A and turns breaker lamp off.

0 Steam Pressure Transmitter 1-PT-1-20A fails low imfRX26E 0 0 PRZR Master Controller fails low IorZAIPIC6834O 0 0 Loop 4 Cold Leg RTD fails high imfRX2D 100 imf CCO5B CCS leak inside CNTMT on thermal barrier supply_to_RCP_#2 0 40 gpm imITHO5C 5 #3 S/G tube leak imfMSl3 5 #3 S/G steam leak @ 2%

0 RTS on 1 -M-4 fails to initiate a reactor trip 1orZDIRT I ior SIO9L CNTMT Phase A fails to automatically actuate iorSIO9M

Page 2 of 3 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #3 STEAM GENERATOR TUBE RUPTRE WITH FAULT EVENT IC/MFIRF/OR # DESCRIPTION/FEEDBACK Event # 1: imfrx26e 0 Steam Pressure Transmitter 1-PT-1-20A fails low.

Insert this When MIG/ Work Control notified acknowledge Malfunction using report.

Trigger 1 Event # 2: iorZAIPlC6834 0 PRZR Master Controller fails low When determined by NRC Examiner, Insert When MIG/ Work Control notified acknowledge this Malfunction report.

using Trigger 2 event # 3: imfrx2d 100 Loop 4 Cold Leg RTD fails high When actions When MIG/ Work Control notified acknowledge associated with AOl- report 1 8 are complete as determined by NRC Examiner, Insert this Malfunction using Trigger 3 Event #4: imfcc05b CCS leak inside CNTMT on thermal barrier supply line to #2 RCP When determined by NRC Examiner, Insert If notified as work control/maintenance concerning this Malfunction CCS leak acknowledge request.

using Trigger 4

Page 3 of 3 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO #3 STEAM GENERATOR TUBE RUPTRE WITH FAULT EVENT I IC/ME/RE/OR # DESCRIPTION/FEEDBACK Event #5 When directed by the Lead Examiner notify the crew of Managements decision to lower power to Normal Power remove IA CBP from service Reducti on When AUO is notified to close I -ISV-2-607, wait 1 0 minutes and call back and report valve is closed.

Event # 6:

imf thOSe 5 #3 S/G Tube leak of approximately 40 gpm..

When actions associated with IA CBP and power When RADPRO is notified state that you will send a reduction are Tech to survey the steam lines complete as determined by NRC Examiner, Insert this

( Malfunction using When Chemistry is notified state that you will send a frigger 5 tech to sample the S/Cs.

When notified by the Lead Examiner increase the malfunction to 30 to input the SGTR.

If asked as AUO to open 1-FCV-14-3 wait 5 minutes and report valve is open.

Events # 7 imfmsl3c 5 #3 S/G steam leak between CNTMT and MSIV When determined by As AUO or Security, when asked to investigate the NRC Lead Examiner, steam leak, wait 5 minutes and report that steam is Insert this coming from the North Vault Room:

Malfunction using Trigger 6 When notifeid as Chemistry acknowledge report When notified as RADPRO acknowledge report

SHIFT TURNOVER CHECKLIST Page of D SM US/MCR Unit UO Unit Off-going Name AUO Station STA (STA Function) On-eoming Name-Part I - Completed by off-going shift/Reviewed by on-coining shift: Ch= 69 ppm

Abnormal equipment lineup/conditions:

IA MD AFW Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule

Major Activities/Procedures in progress/planned:

100% power, EOL, 69 ppm boron. IA Condensate Booster Pump has a small oil leak. A power reduction to 96% is being discussed by Ops Management in order to remove the pump from service

Radiological changes in plant during shift:

None Part 2 Performed by on-coming shift A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUO5)

D A review of the Rounds sheets/Abnormal readings (AUOs only)

Review the following programs for changes since last shift turnover:

D Standing Orders D LCO(s) in actions (N/A for AUO5)

Immediate required reading TACF (N/A for AUOs Part 3 Performed by both off-going and on-coming shift A walkdown of the MCR control boards (N/A for AUOs)

Relief Time: Relief Date:

TVA 40741 [03-2001] Page I of I OPDP-I-l [03-14-2001]

SHIFT TURNOVER CHECKLIST Page of LI SM LI US/MCR Unit UO Unit Off-going Name LI AUO Station LI STA (STA Function) On-coming Name-Part I - Completed by off-going shift/Reviewed by on-coming shift: , 69 ppm 1

C

Abnormal equipment lineup/conditions:

IA MD AFW Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment 005.

51/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

100% power, EOL, 69 ppm boron. 1A Condensate Booster Pump has a small oil leak. A power reduction to 96% is being discussed by Ops Management in order to remove the pump from service

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift LI A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs)

LI A review of the Rounds sheets/Abnormal readings (AUO5 only)

Review the following programs for changes since last shift turnover:

LI Standing Orders LI LCO(s) in actions (N/A for AUOs)

LI Immediate required reading LI TACF (N/A for AUOs Part 3 - Performed by both otT-going and on-coming shift LI A walkdown of the MCR control boards (N/A for AUO5)

Relief Time: Relief Date:

TVA 40741 [03-2001] Page I oil OPDP-l-I [03-14-2001]

SHIFT TURNOVER CHECKLIST Page of SM D US/MCR Unit UO Unit Off-going Name AUO Station D STA (STA Function) On-coming Name-Part I - Completed by ofT-going shift/Reviewed by on-coming shift: , 69 ppm 1

C

Abnormal equipment lineup/conditions:

IA MD AFW Pump OOS for motor bearing replacement. 28 hours3.240741e-4 days 0.00778 hours 4.62963e-5 weeks 1.0654e-5 months remain in LCO 3.7.5, Action B.

Green risk associated with equipment 005.

SI/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

100% power, EOL, 69 ppm boron. IA Condensate Booster Pump has a small oil leak. A power reduction to 96% is being discussed by Ops Management in order to remove the pump from service

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs)

A review of the Rounds sheets/Abnormal readings (AUOs only)

Review the following programs for changes since last shift turnover:

Standing Orders D LCO(s) in actions (N/A for AUO5)

Immediate required reading D TACF (N/A for AUOs Part 3 - Performed by both ofT-going and on-coming shift A walkdown of the MCR control boards (N/A for AUO5)

Relief Time: Relief Date:

TVA 40741 [03-200!] Page I of I OPDP-I-l [03-14-200 I]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # I Page 1 of 45 Event

Description:

Steam Pressure Transmitter 1-PT-1-20A fails low Time N Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event I (Trigger 1)

Indications available:

3 SG Press Indicator (1-PI-1-20A) fails to 0 Alarm 63-F SG Level Deviation Alarm 118-A SG 3 Press LO Crew Diagnose a reduction in Feed Water to # 3 S!G. H May take PRUDENT Operator action lAW Tl-12.04 to take BOP manual control of feed water flow to the #3 S!G.

SRO Direct crew actions lAW AOl-i 6 Loss of Normal Feedwater H Evaluator Note: Following Steps are from AOl-16 Loss of Normal Feedwater, Section 3.1 Diagnostics and then to section 3.6 3.1 Diagnostics IF GOTO Subsection Standby MFWP TRIP without Main Turbine in service 3.2 Standby MFWP TRIP with Main Turbine in service 3.3 SRO MFWP TRIP less than 800 MWe 3.4 (67% Turbine Load)

MFWP TRIP greater than or equal to 800 MWe 3.5 (67% Turbine Load)

MEW reg or bypass reg valve control failure 3.6 MEW pump speed control circuit failure 3.7

1. CONTROL failed MFW reg or bypass reg valve in BOP MAN UAL.

2. EVALUATE placing control rods in MANUAL.

RO The SRO may or may not direct RO to place Rods in manual, depending upon how much of effect the feedwater transient has on Tavg.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 2 of 45 Event

Description:

Steam Pressure Transmitter 1-PT-1-20A fails low Time Position Applicants Actions or Behavior

3. CHECK SG levels on bypass reg valve control.

BOP **

GO TO Step 5

5. CHECK SIG levels returning to PROGRAM.

BOP

6. MONITOR TDMFW Pump speed normal for current power level.

BOP The SRO may or may not direct BOP to place TDMFW Pump speed control in manual, depending upon how effective automatic speed control responds to the transient.

7. WHEN any S!G MEW flow drops to less than 0.55 x 10 E6 lb/hr, THEN INITIATE manual anti-water hammer actions:

Step is N/A

8. CHECK power range NORMAL.

RO NOTE Steps 9 & 10 should end up having the same channel (A or B) selected for steam flow and feed flow on each S/G to ensure a loss of voltage to any one channel will have minimal effect on the affected S!G level.

9. CHECK controlling steam flow Channels NORMAL.

a. SELECT operable channel.

BOP

b. EVALUATE effect of the failed channel on the MEPs Speed Control and ADJUST in MANUAL as necessary while continuing this section.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 3 of 45 Event

Description:

Steam Pressure Transmitter 1 -PT-i -20A fails low Time Position Applicants Actions or Behavior

10. CHECK controlling FW flow channels NORMAL.

Perform RNO:

BOP JAW Note above, even though a FWflow channel did not fail, another channel is selected, to match steam flow channels.

1 1. CHECK press compensation channel(s) NORMAL.

Perform RNO:

SRO REFER TO Tech Specs:

LCO 3.3.2.1.e condition D, LCO 3.3.2.4.d condition D, LCO 3.3.3 Condition A.

12. IF affected S!G controlling channel and level NORMAL, RO THEN RETURN MFW reg valve to AUTO.

13. WHEN conditions allow auto rod control, THEN,

a. ENSURE T-avg and T-ref within 1°F.

b. ENSURE zero demand on control rod position indication [1-RO M-4].

c. PLACE rods in AUTO.

13. INITIATE repairs to failed equipment.

SRO f When technicai specifications have been identified or at discretion of the H Lead Examiner, proceed to the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 4 of 45 Event

Description:

1-PIC-68-340A PZR Master Controller output signal fails low Time N Position N Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 2 (mrf RCRO5 remote)

Indications available:

Alarm 90B PZR Pressure LO Deviation Heaters On RCS Pressure rising Crew J Diagnose a failure of 1-PIC-68-340A PZR Master Controller.

May take PRUDENT Operator action lAW Tl-12.04 to take manual control of 1-PIC-68-340A PZR Master Controller and RO raise the controller output to throttle open the spray valves and reduce heaters to lower RCS pressure to 2235 psig.

Direct crew actions lAW AOl-18 MALFUNCTION OF SRO PRESSURIZER PRESSURE CONTROL SYSTEM.

Evaluator Note: Following Steps are from AOI-18 MALFUNCTION OF PRESSURIZER PRESSURE CONTROL SYSTEM , section 3.0.

1. CHECK pressurizer pressure stable or trending to desired pressure:

. Pl-68-340A,

. P1-68-334,

. P1-68-323 RO

P1-68-322.

PLACE pzr master controller 1-PIC-68-340A in MANUAL and RESTORE press to normal

2. CHECK 1-XS-68-340D selected to a failed, controlling or backup channel.

IF pzr press is abnormally RO high, THEN GO TO Step 13.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 2 Page 5 of 45 Event

Description:

1 -PIC-68-340A PZR Master Controller output signal fails low Time N Position N Applicants Actions or Behavior Evaluator Note: Step 13 may not be applicable if the RO has already lowered RCS pressure to less than 2250 psig. The crew should realize that the heaters are operatinq properli,, for the control siqnal beinq emitted from 1-PIC-68-340A.

-i

13. DETERMINE if pzr heaters are operating properly:

a. CHECK pzr press greater than 2250 psig.

WHEN pzr press is greater greater than 2250 psig. THEN PERFORM Substep 13.b.

RO *

b. ENSURE all pzr heaters OFF.

GO TO Step 14 RO 14. ENSURE pzr sprays maintain RCS press on program.

RO 15. CHECK pzr level at or trending to PROGRAM.

Evaluator Note: The SRO should direct that Heater and Spray component controllers are left in Auto, but the PZR Master remains in manual and direction given to the RO to control RCS pressure.

16. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:

Pzr Master controller, RO

. Pzr spray controllers,

All heater groups.

17. REFER TO the following Tech Specs:

SRO No Tech Specs apply

18. INITIATE repairs to failed equipment.

SRO At the discretion of the Lead Examiner, proceed to the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 6 of 45 Event

Description:

Loop 4 Cold Leg RTD fails high, resulting in rod insertion.

Time N Position Aoolicants Actions or Behavior Booth Instructor:

When directed, initiate Event 3 (Triaaer 3 Indications available:

Continuous Control Rod insertion.

Alarm 93-F EAGLE PROC PROT CH-IV RTD FAILURE Alarm 93A RCS LOOP AT DEVIATION Alarm 94A TAVG-TREF DEVIATION Alarm 94B TAVG-T AUCT DEVIATION Alarm 11 OF PROT SET TROUBLE Loop 4 AT Power Indication 35% (1-Tl-68-67B)

Loop 4 Tavg indication 604° F (1-TI-68-67E)

Auctioneered Tavg indication 604° F (1-TR-68-2B)

The crew should diagnose that there has been a malfunction of the Reactor Control system since the rods are continuously Crew inserting, and there no indications of a plant runback since MWe is constant.

Takes Prudent Operator action lAW Tl-12.04 to place Rod RO Control in MANUAL to stop continuous rod insertion.

Evaluator Note: Following Steps are from AOI-2 MALFUNCTION OF REACTOR CONTROL SYSTEM Directs actions lAW AOI-2 MALFUNCTION OF REACTOR CONTROL SYSTEM 3i Diagnostics Diagnostics IF GO TO Subsection Continuous Rod Withdrawal/Insertion 3.2 (Page 6)

SRO Instrument failure (e.g. T-avg. NIS. PT-1-73) with Rod Control in MAN 3.2 (Page 6)

Dropped RCCA 3.3 (Page 11)

RCCA Misalignment 3.4 (Page 21)

Rod Position Indicator (RPI) Malfunction 3.5 (Page 39)

Failure of Control Rods to Move on Demand 3.6 (Page 42)

Goes to Subsection 3.2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 7 of 45 Event

Description:

Loop 4 Cold Leg RTD fails high, resulting in rod insertion.

Time Position Applicants Actions or Behavior

1. PLACE control rods in MAN.

RO

2. CHECK control rod movement STOPPED.

RO

3. MAINTAIN T-avg on PROGRAM.

(Reference Attachment 1)

RO

USE control rods.

OR

ADJUST turbine load.

Evaluator Note: The following is the portion of A 01-2 Attachment I that is expected to be use now in the scenario and later during the down power to remove the IA CBP.

RX TAVE- PZR POWER TREF LEVEL 90% 583.3 °F 56.5 %

92% 583.9 °F 57.2 %

94% 584.4 °F 57.9 %

96% 585.0 °F 58.6 %

98% 585.6 °F 59.3 %

100% 586.2 °F 60.0 %

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 8 of 45 Event

Description:

Loop 4 Cold Leg RTD fails high, resulting in rod insertion.

Time Position N Applicants Actions or Behavior

4. CHECK loop T-avg channels NORMAL.

Performs RNO DEFEAT failed loop AT and loop T-avg channels by placing 1-XS-68-2D, AT CHANNEL DEFEAT, and 1-XS-68-2M, TAVG CHANNEL DEFEAT, in failed channel position then PULL.

ENSURE TR-68-2A placed to operable channel using.1-XS-68-2B, AT RCDR TR-68-2A LOOP SELECT [1-M-.5].

RO NOTIFY Maintenance to implement lMl-160 for failed channel.

WHEN at least 3 minutes have elapsed since failed T-avg channel is defeated, THEN a) ENSURE T-avg and T-ref within 1°F.

b) ENSURE zero demand on control rod position indication [l-M-4].

c) PLACE rods in AUTO.

5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.

RO

6. CHECK NIS power range channels NORMAL.

RO

7. CHECK the following: PLACE steam dumps in pressure mode as follows:

. Turbine impulse pressure channel 1-Pl-1-73, RO NORMAL. a. PLACE steam dumps to OFF.

. Tref and Auct Tavg NORMAL b. PLACE mode selector HS to on 1-TR-68-2B STEAM PRESS.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 1 Page 9 of 45 Event

Description:

Loop 4 Cold Leg RTD fails high, resulting in rod insertion.

Time Position Applicants Actions or Behavior

8. MONITOR core power distribution parameters:

. Power range channels.

. A Flux Indicators.

. T-avg.

Loop AT.

RO

. lncoreTCs.

Feed flow/Steam flow.

RO should make recommendations for withdrawing Control Bank D back out to 220 steps.

I_______ L RO 9. INITIATE repairs to failed equipment.

10. REFER TO Tech Specs:

Refers to Tech Specs, announces entry into:

LCO 3.3.1, Table 3.3.1-1, item 6 & 7 condition W, item 13 condition V, SRO

LCO 3.3.2, Table 3.3.2-1, item 6.b, condition N.

LCO 3.4.1 may have to be entered due to RCS pressure <2214 psig.

When technical specifications have been identified or at discretion of the Lead Examiner, proceed to the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 4 Page 10 of 45 Event

Description:

CCS leak inside containment on thermal barrier supply line Time U Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 4 (Trigger 4)

Indications available:

Alarm 237B RCP I Thermal barrier RET Flow LO Alarm 237B RCP 2 Thermal barrier RET Flow LO Alarm 237B RCP 3 Thermal barrier RET Flow LO Alarm 237B RCP 4 Thermal barrier RET Flow LO Thermal Barrier #2 HX z\P (1 -PDI-70-I 04) reading 0 Thermal Barrier #2 HX Flow (I -PDI-70-1 05) reading 0 Thermal Barrier RET HDR Flow lowers to II2 gpm Alarm 830 Rx Bldg Pocket Sump Rate of Rise Alarm I60C Rx Bldg Pocket Sump Level Hi CCS Surge Tank slowly rising Should diagnose that a leak is occurring in the CCS supply line BOP to #2 RCP.

Direct crew actions lAW AOI-15 LOSS OF COMPONENT SRO COOLING WATER (CCS).

Evaluator Note: Following Steps are from AOI-15 LOSS OF COMPONENT COOLING WATER (CCS), section 3.2.

1. CHECK CCS pumps status:

a. CHECK any CCS pump TRIPPED or running pump NOT pumping forward BOP Perform RNO:

GO TO Caution prior to Step 2.

2. CHECK i-FCV-70-66, Ui Surge Tank Vent, OPEN.

BOP

3. IF surge tank level less than 57%, THEN ENSURE i-LCV BOP 70-63, Ui Surge Tank Makeup LCV, OPEN (Refer to SOI 70.01 as required if makeup not available).

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 4 Page 11 of 45 Event

Description:

CCS leak inside containment on thermal barrier supply line Time Position N Applicants Actions or Behavior

4. MONITOR A and B side surge tank levels greater than 10%.

BOP

5. IF RHR Shutdown Cooling is in service, THEN GO TO AOl-14, Loss Of RHR Shutdown Cooling.

BOP

6. MONITOR the following for Unit 1 CCS Train A:

U-i CCS Train A level

. ERCW flow to CCS Hx A IF loss of either is imminent THEN PERFORM the following:

BOP PERFORM RNO:

GO TO Step 7.

7. MONITOR the following for Unit 1 CCS Train B:

. U-i CCS Train B level

. ERCW flow to CCS Hx C BOP IF loss of either is imminent, THEN STOP and LOCKOUT the following Train B equipment:

STEP IS N/A

8. CHECK all RCP upper and lower oil cooler flows NORMAL:

Upper Cooler flow: 150-220 gpm BOP

Lower Cooler flow: 5-10 gpm

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 4 Page 12 of 45 Event

Description:

CCS leak inside containment on thermal barrier supply line Time Position Applicants Actions or Behavior

9. CHECK Thermal Barrier Hx flows NORMAL.

. Thermal Barrier flow 40-50 gpm IF flow abnormally high or low indicating possible line break, THEN:

a. ENSURE Thermal Barrier Booster pumps STOPPED.

BOP b. ENSURE the following sd valves CLOSED:

. FCV-70-133 or FCV-70-134, Thermal Barrier Supply

. FCV-70-87 or FCV-70-90, Thermal Barrier Return.

c. IF RCP lower bearing temp rising uncontrolled (180 °F max),

THEN REFER TO AOI-24, Reactor Coolant Pump Seal Abnormalities.

Evaluator Note: Steps 10 -13 are omitted.

14. IF leak location can be isolated, THEN RETURN CCS BOP surge tank to normal level (refer to SOI-70.01).

15. EVALUATE affected equipment operation USING BOP Appendix A.

16. WHEN CCS returned normal, THEN BOP

CHECK only one CCS pump per Train.

CHECK one TBBP running. (Step is N/A)

17. REFER TO Tech Specs 3.7.7, Component Cooling Water System (CCS).

SRO Step is N/A for CCS, however see AR! 83D and AR! 160C actions starting on the next page

18. INITIATE repairs.

SRO

Appendix D Required Operator Actions Form ES-.J Op Test No.: NRC Scenario # 3 Event # 4 Page 13 of 45 Event

Description:

CCS leak inside containment on thermal barrier supply line Time Position U Applicants Actions or Behavior Evaluator Note: The following are steps from AR! 83D Plant Computer Generated Alarm. (steps I and 5 are only steps that are applicable)

[1] CHECK ICS computer Annunciator 83D Alarms screen.

RO

[5] IF pocket sump Rate of Rise in alarm, REFER TO window RO 160-C Evaluator Note: The following are the first 5 steps from ARI-160C RX BLDG Pocket 1] CHECK pocket sump level by one or more of the following:

. 1-Ll-77-410, RB POCKET SUMP LEVEL [1 -M-1 5].

1-Ll-77-411, RB POCKET SUMP LEVEL {1-M-15].

SRO

. Plant Computer (L0472A & L0473A).

2] ENSURE window 159-C, RX BLDG F&EQ SUMP LEVEL HI, NOT LIT.

SRO 3] START Pocket Sump Pump(s).

SRO

[4] IF Pocket Sump rate-of-rise alarms on plant computer, THEN

[a] INITIATE 1-Sl-68-32, Reactor Coolant System Water Inventory Balance.

SRO [b] IF RCS leak is NOT suspected, THEN EVALUATE the need for entering LCO 3.4.15.

[5] IF Pocket Sump Inleakage Bias alarms on plant computer, THEN EVALUATE the need for entering LCO 3.4.15.

SRO SRO should declare Rate of Rise function of Pocket Sump level monitor inoperable while AR! 83D is in alarm for rate of rise. Tech Spec LCO 3.4.15 condition A.

At the Lead Evaluators discretion proceed to the next event.

[7pendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 14 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time Position Applicants Actions or Behavior Booth Instructor: At Lead Evaluators cue, notify crew of Managements decision to lower power to remove IA CBP.

Indications available: None Direct a load reduction down to 98% power in accordance with SRO GO-4 Normal Power Operations, Section 5.3, and SOl-62.02 Boron Concentration Control, Section 6.4.

Evaluator Note (1): GO-4, Normal Power Operation, Section 5.3 steps I thru 9 may be performed concurrently with SOl-62.02 actions to inject boric acid. GO-4 steps are listed at the end of the SOl 62.02 steps in this document.

Evaluator Note (2): The Reactivity Briefing Book should be consulted to determine the reactivity plan to reduce reactor power by 2%.

The crew may either use rods alone, boron alone, or a combination of rods and boron.

SOl-6202 Boron Concentration Control, Section 6.4 starting with step 4 (steps 1, 2, & 3 are N/A) are included below for the use of boron and then flushing the pipe with primary water.

[4] ADJUST 1-FC-62-139, BA TO BLENDER [1-M-6], for RO desired flow rate.

[5] ADJUST 1-FQ-62-139, BA BATCH COUNTER [1-M-6], for RO required quantity.

[6] PLACE 1-HS-62-140B, VCT MAKEUP MODE [1-M-6], in RO BOR.

[7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL [1-M-6], to START.

RO

[7.1] CHECK_Red_light_is_LIT.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 5 Page 15 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time N Position Applicants Actions or Behavior

[8] ENSURE 1-HS-68-341H, BACKUP HEATER C [1-M-4], is ON, RO to_equalize_RCS-Pzr_CB.

[9] MONITOR the foflowing parameters:

Instrument Location PQrn1eters

-[.1-. vOl EESS l-Fl-E2- 122 l-Ll-:2- l2A l-M- T BA :: BLEN::ER F_(vV I-FI-;2- :.

RO I -FO2- I BA BATOH OCINTER I -Fl-;2- 42 FW BLENDER F_(W I -R1-:

I -FO I 2 / BAT::H CCIJNTER 4

P i-r.1- BAT A.

I-LI-2-23.

LLI-32-12 BAT C LEVEL

[10] MONITOR NIS and Rod movement to verify expected RO response.

[11] IF 1-LI-62-129A, VCT LEVEL, rises to 63% THEN ENSURE 1-RO FCV-62-l 18A, LETDOWN DIVERT TO HUT, diverts to the HUT.

[12] WHEN Boration is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

[12.1] ENSURE 1-FC-62-142, PW TO BLENDER, on 35%

(7ogpm) and Manual-Auto toggle in AUTO.

[12.2] ADJUST 1-FC-62-139, BA TO BLENDER, to new RO RCSCB.

[12.3] PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO.

[12.4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

A. CHECK Red light is LIT.

[13] IF required to flush affected piping, THEN GO TO Section 6.3.

RO

Appendix D Required Operator Actions Form ES-D-21 Op Test No.: NRC Scenario# 3 Event# 5 Page 16 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time Position N Applicants Actions or Behavior Evaluator Note: Following Steps are from SOl-62.02 Boron Concentration Control, Section 6.3 starting with step 3 (steps I & 2 are N/A)

[3] ENSURE 1-FC-62-142, PW TO BLENDER dial [1-M-6], set to RO 35% (70 gpm), or other setting as specified in approved instruction, and Manual-Auto toggle in AUTO.

[4] ADJUST 1-FQ-62-142, PW BATCH COUNTER [1-M-6], for RO required quantity.

[5] PLACE 1-HS-62-140B, VCT MAKEUP MODE [1-M-6], in ALT R

DIL.

RO [6] PLACE 1-FCV-62-128, MAKEUP TO VCT INLET, in CLOSE.

[7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL [1-M-6], to RO START.

[7.1] CHECK Red light is LIT.

[8] ENSURE 1-HS-68-341H, BACKUP HEATER C [1-M-4], is RO ON,to_equalize_RCS-Pzr_CB.

[9] MONITOR the following parameters:

Instrument Location Parameters 1-Pl-62-122 1-M-6 VCT PRESS 1-Ll-62-129A 1-M-6 VOT LEVEL RO 1-Fl-62-142 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 1-M-6 PW BATCH COUNTER 1-FQ-62-139 1-M-6 BA BATCH COUNTER

[10] MONITOR NIS and Rod movement to verify expected RO response.

[11] IF 1-Ll-62-129A, VCT LEVEL [1-M-6], rises to 63%, THEN RO ENSURE 1-FCV-62-118A, LETDOWN DIVERT TO HUT [1-M-6],

diverts to HUT.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event# 5 Page 17 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time ,

Position 1 Applicants Actions or Behavior

[12] WHEN alternate dilution is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

[12.1] ENSURE l-FC-62-142, PW TO BLENDER, on 35%

(7ogpm) and Manual-Auto toggle in AUTO.

[12.2] ADJUST 1-FC-62-139, BA TO BLENDER, to new RCS CB.

[12.3] PLACE 1-HS-62-140B, VCT MAKEUP MODE, in RO AUTO.

[12.4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, toSTART.

A. CHECK Red light is LIT.

[12.5] ENSURE 1-HS-62-128, MAKEUP to VCT INLET, in P-AUTO.

Evaluator Note: Following Steps are from GO-4, Normal Power Operation, Section 5.3 Beginning at step 1.

[1] Operations Superintendent has authorized load reduction.

SRO

[2] REVIEW of Precautions and Limitations Section 3.0 CREW COMPLETE.

[3] IF reducing power for compliance to LCO 3.7.1, SRO Step is N/A

[4] NOTIFY RADIATION PROTECTION of impending load SRO reduction.

[5] REQUEST Chemistry evaluate status and flowrate of the following for the impending load reduction:

Steam Generator Blowdown.

SRO

Condensate Polishers.

[6] NOTIFY COND Dl Operator of load reduction and to remove BOP beds as needed.

SRO [7] NOTIFY Load Coordinator of impending load reduction.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 5 Page 18 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time Position Applicants Actions or Behavior

[8] ENSURE letdown flow is maximized.

RO Letdown may not be maximized, since the power reduction is not for an outage.

[9] DETERMINE the CPL and Rate of power reduction restrictions from Tl-45, Determination of Preconditioned BOP Reactor Power, AND RECORD in narrative log and below:

Rate of power reduction

[10] INITIATE load reduction by PERFORMING the following on the Turbine EHC panel:

[10.1] IF during any of the following steps the REFERENCE changes in an undesired manner, THEN

ADJUST VPL to stop turbine load rise.

OR

PUSH TURBINE MANUAL to place the turbine control mode in manual mode and proceed to section 5.6.

[10.2] PUSH REFERENCE CONTROL LI (lower) button to set desired load in SETTER display.

[10.3] SET LOAD RATE as required.

[10.4] PUSH GO button.

BOP

[10.5] MONITOR Generator Megawatts DROPPING.

[10.6] CHECK that load change has STOPPED when reference display equals setter OR IF desired to stop the load change, THEN STOP the load change by DEPRESSING the HOLD pushbutton

[10.7] WHEN desired to resume the load change, THEN PRESS the GO push button and continue to monitor load.

[10.8] ADJUST VALVE POSITION LIMIT to 5% above the Gov Control Indication or as needed.

[10.9] REPEAT Steps 5.3[10.2] to 5.3[10.5] to achieve desired load.

Appendix 0 Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event# 5 Page 19 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time N Position Applicants Actions or Behavior

[11] MONITOR the following during the load reduction:

[11.1] TAVG following TREF program.

RO [11.2] All RPIs, Step Counters, Loop AT, and NIS for correct power distribution, quadrant power tilts, rod insertion, rod misalignment, inoperable RPIs, and inoperable rods.

Insert Control Rods as necessary to maintain Tavg Tref RO Lead Examiner may direct initiation of the next event at his discretion If scenario is allowed to continue until IA CBP is secured, the following are steps from SOl-2&3.O1 Condensate and Feedwater System section 8.17.1 CBP Shutdown at Power CAUTION Consider load reduction of approximately 2%, based on current plant conditions.

NOTES

1) When a CBP is stopped near full power the following parameters are expected to change as follows: Feedwater flow will fluctuate and stabilize at original value, MFWP suction pressure will lower approx. 70 psig (See P&L 3.0H.10), and #3 HDT level will fluctuate approximately 1/2 inch.

2) FW Heater levels may fluctuate, consider local monitoring.

3) The ICS may be used to monitor discharge valve closure progress by observing lowering CBP motor power and raising discharge pressure.

4) Precaution 3.OF.2 should be reviewed prior to removing a CBP from service.

[1] ENSURE selected CBP AUX OIL PUMP in P-AUTO:

BOP

HS-2-105A, AUX OIL PMP CNDS BSTR PMP A

[2] THROTTLE CLOSE selected Condensate Booster Pump discharge valve:

BOP

ISV-2-607, CBP 1A DISCHARGE ISOL.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 5 Page 20 of 45 Event

Description:

Power reduction to remove 1A Condensate Booster Pump from service.

Time Position Applicants Actions or Behavior

[3] PLACE selected CBP(s) handswitch to STOP, AND HOLD UNTIL associated suction valve starts to CLOSE:

BOP

HS-2-97A, CNDS BSTR PMP A

[4] ENSURE suction valve CLOSED for applicable CBP

FCV-2-94 [1-HS-2-94A], CNDS BSTR PMP A SRO SUCTION VLV Lead Examiner may direct initiation of the next event at his discretion

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 21 of 45 Event

Description:

3 SIG tube leak (40 gpm). AOI-33 entry Time Position Applicants Actions or Behavior Booth Instructor:

1 When directed, initiate Event 6 (Trigger 5)

Indications available:

Vacuum Pump exhaust rad monitor RISING.

Alarm 175B Vac Pmp Exhaust 1-RM-119 Rad Hi Charging flow RISING.

Pressurizer Level lowering CREW Should diagnose that a S/G Tube Leak is occuring Direct crew actions lAW AOl-33 STEAM GENERATOR SRO TUBE LEAK Evaluator Note: Following Steps are from AOI-33 STEAM GENERATOR TUBE LEAK section 3.0.

1. CHECK If PZR Level Can Be Maintained:

a. CONTROL charging flow as necessary.

1. OPEN 1-FCV-62-93 as required.

RO

2. OPEN 1-FCV-62-89 as required.

b. MONITOR pzr level STABLE or INCREASING.

2. IIDENTIFY Leaking SG(s);

a. EVALUATE the following:

. Unexpected rise in any SG narrow range level,

. Feedwater flow mismatches,

. High radiation from any ChemistrySG sample results, BOP

High radiation on any SG main steamline radiation monitor,

RADCON survey of main steamlines and SG blowdown lines.

b. MONITOR Condenser Vacuum Exhaust and SG Blowdown Radiation Monitors

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 22 of 45 Event

Description:

3 S/G tube leak (-4O gpm). AOI-33 entry Time N Position Applicants Actions or Behavior

3. CHECK If VCT Level Can Be Maintained:

a. MAINTAIN VCT level greater than 13%, using automatic OR SRO manual makeup.

Evaluator Note: When management notified, the direction will be to shut down the plant.

Determine S!G Tube Leak rate to be 4O gpm.

CREW

4. DETERMINE If Plant Shutdown Is Required:

. High Secondary Radiation, AND

PZR level continues to decrease, SRO OR

Charging flow continues to rise.

5. NOTIFY The Following:

a. Plant personnel via PA system.

Attention plant personnel. The Unit has developed a S!G tube leak and Unit shutdown is in progress.

Treat all leaks as radioactive.

b. Operations Manager.

c. RadCon to survey secondary plant and site environment.

d. Chemistry to initiate the following:

SRO

Hourly RCS Cb sampling.

CM-5.O1, Primary to Secondary Leak Rate Methods.

CM-9.93, Abnormal Release Assessment (for unmonitored steam releases such as SG PORVs and TD AFWP).

ODI-90-2, Steam Generator Blowdown Release.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event# 6 Page 23 of 45 Event

Description:

3 SIG tube leak (40 gpm). AOI-33 entry Time Position Applicants Actions or Behavior

6. PERFORM The Following Evaluations:

a. EVALUATE Tech Specs for applicability:

. 3.4.13, RCS Operational Leakage, SRO to evaluate Tech Spec 3.4.13 and determine SRO secondary leakage is out of spec and LCO states to be in spec within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and be in Mode 3, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after that.

b. EVALUATE EPIP-1, Emergency Plan Classification Matrix.

7. CHECK Unit Load -GREATER THAN 30%:

a. INITIATE unit shutdown USING:

. AOI-39, Rapid Load Reduction.

SRO AND

. CONTINUE performance of this procedure.

8. MONITOR CST Level - GREATER THAN 200,000 GAL, BOP

9. MINIMIZE Secondary System Contamination:

a. CONTROL Condensate return to CST:

1. PLACE 1-LIC-2-3, in MANUAL, and CLOSE.

BOP 2. MAINTAIN condenser level 1-LR-2-12 onscale [1-M-3].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 6 Page 24 of 45 Event

Description:

3 SIG tube leak (-4O gpm). AOl-33 entry Time N Position Applicants Actions or Behavior Evaluator Note: When Lead Evaluator cue console operator to raise the severity to a SGTR, the following MONITOR step will be applicable:

1. CHECK If PZR Level Can Be Maintained:

b. MONITOR pzr level STABLE or INCREASING.

Perform RNO:

b. PERFORM the following;

1. ISOLATE letdown as necessary.

RO 2. INCREASE chg flow, and start additional chg pmp as needed.

3. IF loss of PZR level is imminent,THEN a) TRIP the reactor.

b) WHEN reactor trip is verified, THEN INITIATE Safety Injection.

c) GO TO E-O, Reactor Trip or Safety Injection, Step 1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7 & 8 Page 25 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position N Applicants Actions or Behavior Booth Instructor: NONE Indications Directs RO to manual trip the Reactor, VERIFY that the SRO Reactor Trips, then manually actuate Safety Injection.

Evaluator Note: The Reactor Trip switch on 1-M-4 will not work, if the RO attempts that switch first, the RO should go to Reactor Trip switch on 1-M-6.

RO manual trip the Reactor, VERIFY that the Reactor Trips, RO manually actuate Safety Injection Evaluator Note: The following are steps from E-O.

NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

NOTE 2 Status Trees! SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RPIs at bottom of scale.

RO

Neutron flux DROPPING.

2. ENSURE Turbine Trip:

All turbine stop valves CLOSED.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7& 8 Page 26 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position Applicants Actions or Behavior

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:CSST (offsite), OR DIG RO (blackout).

4. CHECK SI actuated:

a. Any SI annunciator LIT.

b. Both trains SI ACTUATED.

RO

1 -XX-55-6C

1-XX-55-6D BOP Evaluator Note: Appendix A (E-O), SI Support Systems, and Appendix B, Phase B Pipe Break Contingencies are contained at the end of this document.

BOP

5. EVALUATE support systems:

REFER TO Appendixes A and B (E-0), Equipment Verification pages 15-28.

6. ANNOUNCE reactor trip and BOP safety injection over PA system.

7. ENSURE secondary heat sink RO available with either:

Total AFW flow greater than 410 gpm, OR

At least one S/G NR level greater than 29% [39% ADVI.

8. MONITOR RCS temp stable at or trending to 557°F:

IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 557°F.

RO OR

IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 557°F.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7& 8 Page 27 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position N Applicants Actions or Behavior

9. ENSURE excess letdown valves CLOSED:

BOP

1-FCV-62-54

1-FCV-62-55

10. CHECK pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

RO

b. At least one block valve OPEN.

1 1. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic RO monitors.

12. CHECK pzr sprays CLOSED.

RO

13. CHECK if RCPs should remain in service:

a. Phase B signals DARK {MISSP].

RO

b. RCS pressure greater than 1500 psig.

14. CHECK S!G pressures:

All S/G pressures controlled or rising.

RO

All SIG pressures greater than 120 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7 &8 Page 28 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position Applicants Actions or Behavior

15. CHECK for RUPTURED S!G

All S/Gs narrow range levels CONTROLLED or DROPPING.

Secondary side radiation NORMAL from Appendix A.

Perform RNO:

RO IF any S/G has level rising in an uncontrolled manner or has high radiation, THEN GO TO E-3, Steam Generator Tube Rupture.

Evaluator Note: SRO should direct the crew to GO TO E-3 at this point. The following steps are from E-3.

1. REFER TO EPIP-1, Emergency Plan Classification SRO Flowchart.

2. CHECK if RCPs should remain in service:

a. Phase B DARK [MISSP].

RO

b. RCS pressure greater than 1500 psig.

3. IDENTIFY Ruptured S!G based on ANY of the following:

Unexpected rise in S!G NR level.

OR

S/G discharge monitor high radiation.

BOP OR RO *RADPROTSurvey.

OR

Chemistry sample.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7& 8 Page 29 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position Applicants Actions or Behavior

4. ENSURE Ruptured SIG PORV aligned:

a. ENSURE controller in AUTO set at 90%.

b. ENSURE HS in P-AUTO.

c. WHEN Ruptured S!G pressure less than 1 130 psig.

RO THEN BOP 1) ENSURE Ruptured S!G PORV CLOSED, OR

2) OBTAIN RADPROT support and Locally CLOSE Ruptured S/G isolation valve:

RO 5. ENSURE TD AFW pump being supplied from Intact S/G.

BOP RO 6. ENSURE Ruptured S!G blowdown isolated.

BOP RO 7. CLOSE Ruptured S!G MSIV and bypass valve.

BOP RO 8. CONTROL Ruptured S!G level:

BOP a. CHECK Ruptured SIG NR level greater than 29%

[39% ADV].

RO 9. PLACE dumpback valve to CST, 1-LIC-2-3, in MANUAL, and CLOSE valve.

BOP RO 10. MAINTAIN condenser level 1-LR-2-12 on-scale [M-3].

BOP RO 1 1. DISPATCH operator to OPEN 1 -FCV-1 4-3 to bypass condensate Dl.

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7 &8 Page 30 of 45 Event

Description:

E-0, to E-3 cool down to target temperature Time Position Applicants Actions or Behavior

12. ENSURE RADPROT dispatched to survey secondary SRO plant.

13. NOTIFY Chemistry to obtain samples as necessary for SRO confirming Ruptured S!G.

14. NOTIFY plant personnel of potential contaminated release.

SRO

15. ENSURE major steam flowpaths from the ruptured S!G isolated:

RO a. TD AFW pump steam supply from Ruptured S!G CLOSED BOP b. Ruptured S!G MSIV and bypass valve CLOSED, OR Intact S/G MSIVs and bypass valves CLOSED.

16. CHECK Ruptured S!G pressure greater than 690 psig.

RO

17. DETERMINE target incore temp for RCS cooldown:

IF Ruptured S!G pressure is between listed values, THEN USE lower value:

RUPTURED TARGET SIG PRESSURE (PSIG) INCORE TEMP (°F)

RO 1100 491°F [471°FADVI 1000 479°F [459°FADV]

900 466° F [446° F ADV]

800 451°F {431°FADV]

700 434°F [414°FADV]

690 433°F [413°FADV]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7 &8 Page 31 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time Position Applicants Actions or Behavior 1

18. INJTIATE RCS cooldown to target incore temp, determined from Step 17.

a. DUMP steam to condenser from Intact S/G(s) at maximum achievable rate IF dumps are in Tavg mode, THEN:

1) PLACE steam dump controls OFF.

2) PLACE steam dump mode switch in STEAM PRESSURE.

3) ENSURE steam dump demand indicator 1-Xl-1-33 reading zero.

4) PLACE steam dump controls ON.

5) PLACE steam dump controller in MAN, AND FULLY RO OPEN three cooldown valves (25% demand).

BOP

b. WHEN RCS pressure is less than 1962 psig (P-il),

THEN

BLOCK low pzr pressure SI.

BLOCK low steam pressure SI.

c. WHEN Tavg is less than 550°F (P-12), THEN BYPASS Lo-Lo Tavg interlock.

d. WHEN incore temp is less than target temp, THEN STOP RCS cooldown, AND MAINTAIN incore temperature less than or equal to target.

e. CONTINUE with Step 19 of this Instruction.

RO 19. MONITOR Intact S/G levels:

a. At least one S!G NR level greater than 29%

BOP b.__S!G_NR_levels_less_than_50%_and_controlled.

RO 20. CONTROL Intact S!G NR levels between 29% and 50%.

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7&8 Page 32 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time i Position N Applicants Actions or Behavior

21. MONITOR pzr PORVs and block RO valves:

a. Pzr PORVs CLOSED.

BOP b. At least one block valve OPEN.

RO 22. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic BOP monitors.

Lead Evaluator NOTE: Cue console operator to insert Trigger 6 to implement Steam_Leak_on_#3_S/G

23. RESET SI, and CHECK the following:

RO

SI ACTUATED permissive DARK.

AUTO SI BLOCKED permissive LIT.

24. RESET Phase A and Phase B.

RO

25. ENSURE cntmt air in service:

a. Aux air pressure greater than 75 psig

b. Cntmt air supply valves OPEN [M-1 5]:

BOP

1-FCV-32-80.

1-FCV-32-102.

1-FCV-32-110.

26. DETERMINE if RHR pumps should be stopped:

a. CHECK RHR suction aligned from RWST.

b. CHECK RCS pressure greater than 150 psig.

c. CHECK RCS pressure stable or rising.

Perform RNO:

RO

c. ENSURE CCS aligned to RHR heat exchanger:

1-FCV-70-153 OPEN

1-FCV-70-156 OPEN.

CLOSE SFP heat exchanger A 005 supply 0-FCV-70-1 97.

GO TO Step 27.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 7 &8 Page 33 of 45 Event

Description:

E-O, to E-3 cool down to target temperature Time [ Position L Applicants Actions or Behavior

27. CHECK target incore temperature:

a. VERIFY incore temperature less than target temperature.

RO DO NOT CONTINUE this instruction UNTIL incore BOP temperature less than target temperature.

b. STOP RCS cooldown.

c. MAINTAIN incore temperature less than target temperature.

EVALUATOR NOTE: The crew should determine either in step 28 or 29 that a transition to ECA-3. I is required.

28. MONITOR Ruptured S!G pressure stable or rising.

Perform RNO:

MAINTAIN Ruptured S/G at least 250 psig greater than the pressure of the S/G(s) used for cooldown:

RO

Slowly DUMP steam from S/G(s) used for cooldown.

MAINTAIN RCS cooldown rate less than 100° F in BOP one hour.

IF the Ruptured S/G depressurizes to less than 250 psig above the pressure of the S/G(s) used for cooldown, THEN GO TO ECA-3. 1, SGTR and LOCA Subcooled Recovery.

29. CHECK RCS subcooling greater than 85°F [105°F ADV].

Perform RNO:

RO IF subcooling is less than 65°F [85°F AD VI, THEN GO TO ECA-3. 1, SGTR and LOCA Subcooled Recovery.

IF subcooling is STABLE OR DROPPING, THEN GO TO ECA-3. 1, SGTR and LOCA Subcooled Recovery.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 9 Page 34 of 45 Event

Description:

E-O Appendix A Time Position L Applicants Actions or Behavior Booth Instructor: NONE Indications Directs BOP to perform E-0 STEP 5:

EVALUATE support systems:

SRO

REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28.

Evaluator Note: The following are E-O Appendix A steps.

Evaluator Note: The SRO may at times interrupt the BOP, during the performance of Appendixes A and B, to perform other higher priority task.

1. ENSURE PCBs OPEN:

PCB 5044.

BOP

PCB 5088.

2 ENSURE AFW pump operation:

Both MD AFW pumps RUNNING.

TD AFW pump RUNNING.

BOP

LCVs in AUTO, or controlled in MANUAL.

3. ENSURE MFW isolation:

MFW isolation and bypass isolation valves CLOSED.

MEW reg and bypass reg valves CLOSED.

MFP A and B TRIPPED.

BOP

Standby MFP STOPPED.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 9 Page 35 of 45 Event

Description:

E-O Appendix A Time Position [ Applicants Actions or Behavior

4. MONITOR ECCS operation:

a. Charging pumps RUNNING.

b. Charging pump alignment:

RWST outlets 1-LCV-62-135 and 1-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1-LCV-62-133 CLOSED.

Charging 1-FCV-62-90 and 1-FCV-62-91 CLOSED.

c. RHR pumps RUNNING.

d. SI pumps RUNNING.

e. BIT alignment:

BOP

Outlets 1-FCV-63-25 and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater than 1650 psig.

RNO if not >l65Opsig:

f. ENSURE SI pump flow. IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

Evaluator Note: The BOP or the RO may have already taken PRUDENT operator action lAW TI-I 204 to perform the next step.

5 CHECK cntmt isolation:

a. Phase A isolation:

Train A GREEN.

Train B GREEN.

b. Cntmt vent isolation:

BOP *TrainAGREEN.

Train B GREEN.

Perform RNO:

ACTUATE Phase A and Cntmt Vent Isolation signal,

6. CHECK cntmt pressure:

Phase B DARK {MISSP].

Cntmt Spray DARK [MISSP].

BOP

Cntmt press less than 2.8 psig.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 9 Page 36 of 45 Event

Description:

E-O Appendix A Time L_Position Applicants Actions or Behavior

7. CHECK plant radiation NORMAL:

S!G blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation [M-12].

Condenser vacuum exhaust rad recorder 1-RR 119 NORMAL prior to trip {M-12].

1-RR-90-106 and 1-RR-90-112 radiation recorders NORMAL prior to isolation [M-1 2].

BOP S/G main steamline discharge monitors NORMAL [M 30].

Upper and Lower containment high range monitors NORMAL [M-30].

NOTIFY Unit Supervisor conditions NORMAL.

8 ENSURE all DIGs RUNNING.

BOP

9. ENSURE ABGTS operation:

a. ABGTS fans RUNNING.

b. ABGTS dampers OPEN:

FCO-30-146A.

BOP

FCO-30-146B.

FCO-30-157A.

FCO-30-157B.

10. ENSURE at least four ERCW pumps RUNNING, one on each shutdown board preferred.

BOP 1 1. ENSURE ERCW supply valves OPEN to running D/Gs.

BOP

12. ENSURE CCS HX C ALT DISCH TO HDR B, 0-FCV BOP 152, is open to position A.

13. CLOSE CCS HX C DISCH TO HDR A, 0-FCV-67-144.

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 9 Page 37 of 45 Event

Description:

E-O Appendix A Time Position N Applicants Actions or Behavior

14. MONITOR EGTS operation:

EGTS fans RUNNING.

ENSURE dampers OPEN VERIFY filter bank dp BOP between 5 and 9 inches of water.

15. ENSURE CCS pumps RUNNING:

lA-A CCS pump.

1B-BCCS pump.

BOP

C-S OR 2B-B CCS pump.

16. CHECK CNTMT PURGE fans STOPPED:

BOP

17. CHECK FUEL HANDLING EXH fans STOPPED, Fuel and Cask loading dampers CLOSED:

BOP

18. ENSURE AB GEN SUPPLY and EXH fans STOPPED.

BOP

19. ENSURE AB GEN SUP & EXH dampers CLOSED.

BOP

20. ENSURE MCR & SPREAD RM FRESH AIR dampers CLOSED:

FCV-31-3.

BOP

FCV-31-4.

21. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, OR Fan B-B BOP RUNNING.

FCO-31-8, OPEN OR FCO-31-7, OPEN.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 9 Page 38 of 45 Event

Description:

E-O Appendix A Time N Position N Applicants Actions or Behavior

22. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

GB EMERG PRESS FAN A-A, OR FAN B-B RUNNING.

BOP

FCO-31-6, OPEN. OR FCO-31-5, OPEN.

23. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY and EXH FANS AND BOP dampers.

TOILET & LKR RM EXHAUST FAN AND dampers.

24. INITIATE Appendix B.

BOP Evaluator lote: Or Iv step I of E-O Appendix B is listed below

1. CHECK PHASE B actuated BOP WHEN PHASE B actuation occurs; THEN GO TO step 2.

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# 3 Event# 10 Page 39 of 45 Event

Description:

ECA-3.1 Time N Position N Applicants Actions or Behavior Booth Instructor: NONE Indications None Directs the crew to ECA-3. 1, SGTR and LOCA Subcooled SRO Recovery due to ruptured S/G pressure lowering uncontrolled.

Evaluator Note: The crew should recognize ECA-3. I Foldout:

EVENT DIAGNOSTIC TRANSITIONS

. IF any S/G press low or dropping uncontrolled AND SIG has NOT been isolated, unless needed for RCS cooldown, THEN GO TO E-2, Faulted Steam Generator Isolation.

The crew may go to E-2 and perform steps to verify #3 S/G is isolated, or they may continue in ECA-3. I, since they know that #3 SIG is already isolated IA W E-3.

E-2 Faulted Steam Generator steps start at page 43.

1. PREPARE for switchover to RHR cntmt sump:

a. RESTORE power to 1-FCV-63-1 USING Appendix A (ECA-3.1), 1-FCV-63-1 Breaker Operation.

RO **

b. WHEN RWST level is less than 34%, THEN GO TO ES-i .3, Transfer to RHR Containment Sump.

2. RESET SI, and CHECK the following:

SI ACTUATED permissive DARK.

RO

AUTO SI BLOCKED permissive LIT.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 10 Page 40 of 45 Event

Description:

ECA-3.1 Time Position Applicants Actions or Behavior

3. RESET Phase A and Phase B.

RO

4. ENSURE cntmt air in service:

a. Aux air press greater than 75 psig

b. Cntmt air supply valves OPEN [M-1 5]:

RO

1-FCV-32-80.

1-FCV-32-102.

1-FCV-32-11O.

5. MONITOR electrical board status:

a. CHECK offsite power available.

b. CHECK all shutdown boards ENERGIZED by offsite power.

BOP

c. CHECK all unit boards ENERGIZED.

d. PLACE any unloaded D/G in standby USING SOl-82 Diesel Generators.

6. ENSURE pzr heaters off:

PLACE Backup heaters A-A OFF.

PLACE Backup heaters B-B OFF.

RO

PLACE Backup heaters C OFF.

PLACE Control heaters D OFF.

CAUTION If any Ruptured SIG is also faulted, feed flow should remain isolated in subsequent steps UNLESS needed for RCS cooldown.

7. CONTROL Ruptured S/G level:

BOP a. CHECK Ruptured S/G NR level greater than 29%

b. ISOLATE feed flow to Ruptured S/G.

c. CONTROL Ruptured S/G NR level greater than 29%

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 10 Page 41 of 45 Event

Description:

ECA-3.1 Time Position Applicants Actions or Behavior

8. DETERMINE if RHR pumps should be stopped:

a. CHECK RHR suction aligned from RWST.

b. CHECK RCS pressure:

RCS pressure greater than 150 psig.

RCS pressure stable or rising.

c. STOP RHR pumps, and PLACE in A-AUTO.

BOP d. MONITOR RCS pressure greater than 150 psig.

If pressure still lowering:

Perform RNO:

b. IF RCS pressure low or dropping, THEN GO TO Step 9.

RO DETERMINE if cntmt spray should be stopped:

10. NOTIFY Chemistry of event status and plant conditions.

SRO SRO 1 1. NOTIFY Radiological Protection of event status and plant conditions.

Evaluator Note: Appendix D (ECA-3. 1), Equipment Evaluation is at the end of this section

12. EVALUATE plant equipment status:

BOP

REFER TO Appendix D (ECA-3.1), Equipment Evaluation.

13. CHECK S!G pressure:

All S/G pressures controlled or rising.

All S!Gs pressures greater than 120 psig.

RO Perform RNO:

IF steamline AND feedline isolation has been performed or attempted for the Faulted S/G, THEN ** GO TO Step 14.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# 3 Event# 10 Page 42 of 45 Event

Description:

ECA-3.1 Time Position Applicants Actions or Behavior

14. MAINTAIN Intact S!G NR levels:

RO a. MONITOR levels greater than 29%

b. CONTROL intact S/G levels between 29% and 50%

15. MONITOR shutdown margin during cooldown:

a. NOTIFY Chemistry to initiate sampling for boron concentration:

Ruptured S!G.

RCS.

RO

b. REFER TO 1-Sl-0-10, Shutdown Margin OR REACTINW Computer Program.

c. INITIATE boration as necessary:

REFER TO SOl-62.02, CVCS Boron Concentration Control.

16. INITIATE RCS cooldown to cold shutdown:

a. MAINTAIN T-cold cooldown rate less than 100°F in one hour.

RO b. IF RHR in service, THEN USE RHR cooling.

c. DUMP steam to condenser from Intact S/Gs.

Evaluator Note: At the Lead Evaluators discretion, the scenario may be terminated when crew has determined that the plant cooldown should not be initiated until a soak time has occurred to ensure 100 °F/hr will not be violated. Remainder of ECA-3.1 procedure not included.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # 3 Event # 10 Page 43 of 45 Event

Description:

ECA-3.1 Time N Position N Applicants Actions or Behavior The following pages are pages from E-2 and at the end is Appendix D (ECA-3. 1),

Equipment Evaluation

1. ENSURE all MSIVs and MSIV bypasses CLOSED.

BOP

2. PLACE steam dump controls OFF:

1-HS-1-103A, STEAM DUMP FSV A.

BOP

1-HS-1-103B, STEAM DUMP FSV B.

3. CHECK for at least one Intact S!G:

Any S!G pressure controlled or rising, BOP OR

Any S!G pressure greater than P-sat for RCS incore temperature.

4. IDENTIFY Faulted S/G based on ANY of the following:

Any S!G pressure dropping in an uncontrolled manner, BOP OR

Any S/G pressure less than 120 psig,

5. ISOLATE Faulted S!G:

a. ISOLATE AFW flow to Faulted S!G.

b. ENSURE MFW ISOLATED to Faulted SIG:

MFW isolation and bypass isolation valves CLOSED.

BOP

MFW reg and bypass reg valves CLOSED.

MFPs TRIPPED.

c. ENSURE Faulted S/G PORV CLOSED.

d._ENSURE_Faulted_SIG_blowdown_ISOLATED.

6. ENSURE TD AFW pump being supplied from Intact S!G.

RO

7. MONITOR CST volume greater than 200,000 gal.

RO

Appendix D Required Operator Actions Form ES-D--2 Op Test No.: NRC Scenario# 3 Event# 10 Page 44 of 45 Event

Description:

ECA3.1 Time Position Applicants Actions or Behavior

8. WHEN RCS temperature is stable or rising following Faulted S!G blowdown, THEN ADJUST Intact S!G PORV controllers in RO AUTO to:

BOP This step is N/A

9. CHECK secondary side radiation:

BOP The crew will now go back to E-3, and then go to ECA-3. I

WBN SGTR AND LOCA SUBCOOLED RECOVERY

- ECA-3.1 Rev 1 1 APPENDIX D (ECA-3.1)

Page 1 of 1 EQUIPMENT EVALUATION

1. EVALUATE plant equipment and systems needed to support long term cooling and recovery actions, as time and personnel availability permits:

a) Cntmt Isolation Status.

b) Emergency Gas Treatment System:

One train in operation, REFER TO SOl-65.02.

c) Auxiliary Building Gas Treatment:

One train in operation, REFER TO SOl-30.06.

d) Auxiliary Building Isolation alignment:

REFER TO SOl-30.06.

e) Main Control Room Isolation alignment:

REFER TO SO1-31.O1.

f) ERCW System:

Both trains in operation.

g) Component Cooling Water System:

Both trains in operation.

h) Auxiliary Building Radiation:

1-RR-90-1

O-RR-90-12A

O-RM-90-1O1.

\ppendix D Scenario Outline Form ES-D-1 Facility: Watts Bar (2008-B) Scenario No.: Op Test No.: 1 Spare Examiners: OperatchjR AFT Initial Conditions: 2% power at BOL, no equipment 005. Preparing for power escalation and mode change.

Turnover: The plant is at BOL. A startup is in progress from a forced outage to repair an EHC high pressure piping leak. Power is stable at 2%, awaiting the Operations Superintendent approval to enter Mode 1. The crew is in GO-3 Unit Startup From Less Than 4% Reactor Power to 30% Reactor Power section 5.2 step 14. The crew is then expected to raise reactor power to between 13% and 15%, per GO-3 Section 5.3.

Event MaIf. No. Event Event No. Type* Description 1 N/A R-RO Raise reactor power to between 13% and 15%.

N-SRO/BOP 2 ZAIPIC124A C-BOP/SRO #3 S/G PORV fails partially open (25%). BOP manually closes S/G PORV to restore RCS temperature. AOl-38 entry. Tech Spec TS-SRO evaluation.

3 RX18 C-SRO/RO Auctioneered Tavg fails high. AOl-2 entry.

4 CC12A TS-SRO 1A CCS Pump bearing wear results in pump failure. lB CCS Pump fails to auto start. AOl 15 entry. Tech Spec evaluation.

CCO3B C-BOP 5 RDO7B C-SRO/RO Control rod H-i 2 drops to the bottom of the core. A0l-2 entry.

Tech Spec evaluation.

TS-SRO 6 RDO7D C-SRO/RO Five minutes later control rod C-S drops to the bottom of the core, requiring reactor trip and EOP entry.

7 THO1 B M-ALL Large Break LOCA with failure of both SI trains to automatically actuate. RO manually actuates SI.

RPO2B C-RO 8 CSO6G C-BOP Containment Air Return Fans fail to automatically start 9 minutes after Phase B initiation. BOP manually starts fans.

CSO6H 9 RHO2 C-RO/SRO Failure of automatic RHR Pump swap over to Containment Sump in ES-i .3. RO manually actuates.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Appendix D NUREG 1021 Revision 9

ppendix D Scenario Outline Form ES-D-i Spare Scenario Summary Initial Conditions:

The plant is at BOL. A startup is in progress from a forced outage to repair an EHC high pressure piping leak. Power is stable at 2%, awaiting the Operations Superintendent approval to enter Mode 1. The crew is in GO-3, Unit Startup From Less Than 4% Reactor Power to 30% Reactor Power section 5.2 step 14.

The crew is then expected to raise reactor power to between 13% and 15%, per GO-3 Section 5.3.

1. Commence a power increase, in accordance with the reactivity plan.

2. The # 3 SIG PORV controlling signal fails, resulting in PORV partially opening. Tavg lowers, AT power rises. BOP manually closes PORV to restore RCS temperature. AOl-38 Main Steam or Feedwater Line Break entry. SRO evaluates Tech Specs.

3. Auctioneered Tavg fails high. Charging flow rises due to PZR level setpoint failing to 60%. RO manually controls charging lAW AOl-2 Malfunction of Reactor Control.

4. 1A CCS Pump bearing starts to wear to the point it trips on overcurrent. The 1 B CCS Pump fails to auto start on low pressure. BOP manually starts the 1 B CCS Pump lAW AOl-i 5, Loss of Component Cooling Water. SRO evaluates Tech Specs.

5. Control rod H-12 drops to the bottom of the core. AOl-2, Malfunction of Reactor Control, is entered.

SRO evaluates Tech Specs.

6. Five minutes later control rod C-5 drops into the core, requiring reactor trip and EOP entry.

7. Large Break LOCA with failure of both SI trains to automatically actuate. RO manually actuates SI.

8. Containment Air Return Fans fail to automatically start 9 minutes after Phase B initiation. BOP manually starts fans.

9. Failure of automatic RHR Pump swap over to Containment Sump in ES-i .3, requiring manual actions by RO.

10. The scenario ends when the crew has performed RHR Pump swap over to Containment Sump lAW ES-i .3.

Critical 1 2 Tasks: Manually initiates SI or Perform transfer to RHR Cntmt places in service at least sump:

one full train of ESF

Isolates SIP mini-flow.

equipment before

Isolates RHR crossties.

transition from E-0.

Aligns CCP and SIP supply from RHR.

Aligns RHR discharge to CCP and_SIP_suctions.

Appendix D NUREG 1021 Revision 9

Page 1 of 5 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO SPARE Power Increase with LBLOCA I EVENT I IC/MF/RF/OR # I DESCRIPTION/FEEDBACK

. rst 248, switch check, select RUN Sini. Setup 2% RTP, BOL, Cb- 1807 ppm. This IC contains the verify malfunctions and overrides listed overrides and triggers.

below 0 . Turns off audible alarm for the simulator fault so the Disable simulator fault alarm crew cannot hear this alarm.

0 Place A Train week I placard on

. On entrance side panel.

entrance side panel.

0 Indicate/Enter in the appropriate blanks Ensure BOL Reactivity Briefing Book is used. Item this information into the reactivity 3: Delta I -3 and AUTO rod control.

briefing book, (appendix B TI-7.012) Item 4: Negative, 1-CCP B, 890 0 Item 5: 1 807, Boron, BA 10.2, PW 70, BA Pot 24, PW POT 35 Item 6: PW 45 gal Item 7: PW 45 gal rst 49, switch check, select run, follow GO-2 to take simulator critical and 2% RTP, BOL, Cb 1 807 ppm.

Sini Setup ifIC 248 does not work. raise power to 2% and stabilize.

0 0 #3 S/G PORV fails partially open to 25%.

iorZAIPIC124A 25 0 Auctioneered Tave fails high imfRXl8 100 imfCCl2A 100 1A CCS Pump bearing wear results in 0 pump failure with lB CCS pump fails to auto start.

imfRDO7B Control Rod 11-12 drops inot the core 0 Control Rod C-S drops inot the core imfRDO7D 0 imfTHOlB 65 LBLOCA with both SI Trains failing to auto_actuate 0 imfRHO2 0 Failure of automatic RHR Pump swapover to CNTMT sump

Page 2 of 5 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO SPARE Power Increase with LBLOCA I EVENT I IC/MF/RF/OR # I DESCRIPTION/FEEDBACK irnfCSO6G 0 Containment Return Fans fail to automatically 0 start 9 minutes after Phase B initiation.

imfCSO6H 0 0 lB CCS Pump fails to auto start.

imfCCO3B 0 Event# 1: none Increase power from 2% to -45% for turbine operatio n.

Increase power as determined by NRC Examiner.

3 S!G PORV fails partially open to 25%.

Event # 2: iorZAIPCI24A 25 If notified as work control/maintenance concerning When power increase #3 S/G PORV problems, acknowledge request.

complete as determined by NRC 3xaniiiier, Insert this rvlal fttnction using Trigger I

Page 3 of 5 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO SPARE Power Increase with LBLOCA I EVENT I IC/MF/RF/OR # I DESCRIPTION/FEEDBACK imfrxl8 100 Auctioneered Tave fails high Event # 3:

When actions associated with AOl-38 are complete as If notified as work control/maintenance concerning determined by NRC Auctioneered Tave failure acknowledge request Examiner, Insert this Malfunction using Trigger 2 1A CCS pump trip due to bearing failure with lB CCS pump failing to auto start.

Event # 4:

imfccl2a 100 If notified as AUO, wait 5 minutes and report that the When actions IA CCS pump motor is hot to the touch.

associated with Auctioneered Tave failure are complete If notified as AUO, report that 1A CCS pump tripped as determined by on overcurrent.

NRC Examiner, Insert this Malfunction using Trigger 3 If notified as work control/maintenance concerning IA CCS pump acknowledge request.

Page 4 of 5 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO SPARE Power Increase with LBLOCA I EVENT I IC/M F/RE/OR # I DESCRIPTION/FEEDBACK Event # 5 & 6:

imf rdO7b Control Rod H-12 drops to the bottom of the core.

When actions 5 minutes later Control Rod C-5 drops to the associated with IA imfrd07d (e4 5:00) bottom of the core.

CCS Pump are complete as determined by NRC Examiner, Insert this Malfunction using Trigger 4 As Reactor Engineering, if asked, wait 5 mm then inform MCR that you are evaluating the core anomaly.

Page 5 of 5 NRCO8A Rev 0 CONSOLE OPERATOR INSTRUCTIONS SCENARIO SPARE Power Increase with LBLOCA I EVENT I IC/MF/RF/OR # I DESCRIPTION/FEEDBACK I Events #7, 8, & 9 imfthOlb 65 LBLOCA with failure of SI to auto actuate, Failure of Containment Air Return Fans to start, When actions and failure of RHR Pump to auto swapover to associated with CNTMT sump.

dropped rods are complete as determined by NRC As AUO, when asked initiate AOI-17, Turbine Trip Examiner, Insert this BOP Alignment Malfunction using Trier 19 As AUO, when asked to initiate B-I, Appendix A, CLA Breaker Operation, wait 10 minutes and report Appendix complete.

As AUO, when asked to initiate B-i, Appendix B, Ice Condenser AHU Breaker Operation wait 10 minutes and report Appendix complete.

As AUO, when asked to initiate B-I, Appendix C, I FCV 1 Breaker Operation wait 1 0 minutes and report Appendix complete As AUO, when asked to initiate B-i, Appendix D, I FCV-63-22 Breaker Operation wait 10 minutes and report Appendix complete

SHIFT TURNOVER CHECKLIST Page of D SM 1 US/MCR Unit D UO Unit Off-going Name AUO Station STA (STA Function) On-coming Name-Part I - Completed by off-going shift/Reviewed b on-coming shift: Cb= 1807 ppm

Abnormal equipment lineup/conditions:

None.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule Maor Activities/Procedures in progress/planned:

2% power at BOL, no equipment OOS. Preparing for power escalation and mode change. A .

startup is in progress from a forced outage to repair an EHC high pressure piping leak. Power is stable at 2%, awaiting the Operations Superintendent approval to enter Mode 1. Currently in GO-3 section 5.2 step 14. The crew is then expected to raise reactor power to between 13% and 15%. per 00-3 Section 5.3.

I Abnormal equipment lineup/conditions:

N one.

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUO5)

A review of the Rounds sheets/Abnormal readings (AUOs only)

Review the following programs for changes since last shift turnover:

E Standing Orders LCO(s) in actions (N/A for AUOs)

D Immediate required reading E TACF (N/A for AUOs Part 3 - PerIrmed by both off-going and on-coming shift A walkdown of the MCR control boards (N/A for AUOs)

Relief Time: Relief Date:

SHIFT TURNOVER CHECKLIST Page of D SM D US!MCR Unit UO Unit Off-going Name AUO Station STA (STA Function) On-coming Name-Part I - Completed by oflgoing shift/Reviewed by on-coming shift: C 1807 ppm Abnormal equipment lineup/conditions:

None.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

2% power at BOL, no equipment OOS. Preparing for power escalation and mode change. A .

startup is in progress from a forced outage to repair an EHC high pressure piping leak. Power is stable at 2%, awaiting the Operations Superintendent approval to enter Mode I. Currently in GO-3 section 5.2 step 14. The crew is then expected to raise reactor power to between 13% and 15%, per GO-3 Section 5.3.

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift LI A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs)

LI A review of the Rounds sheets/Abnormal readings (AUOs only)

Review the following programs for changes since last shift turnover:

LI Standing Orders LI LCO(s) in actions (N/A for AUO5)

LI Immediate required reading LI TACF (N/A for AUOs Part 3 - Performed by both off-going and on-coming shift LI A walkdown of the MCR control boards (N/A for AUO5)

Relief Time: Relief Date:

TVA 4074! [03-200!] Page I of! OPDP-I-I [03-14-200!]

SHIFT TURNOVER CHECKLIST Page of El SM El US/MCR Unit UO Unit Off-going Name El AUO Station El STA (STA Function) On-coming Name-Part 1 - Completed by off-going shift/Reviewed by on-coining shift: Cb= 1807 ppm Abnormal equipment lineup/conditions:

None.

Green risk associated with equipment OOS.

SI/Test in progress/planned: (including need for new brief)

See Schedule Major Activities/Procedures in progress/planned:

2% power at BOL, no equipment OOS. Preparing for power escalation and mode change. A .

startup is in p1-ogress from a forced outage to repair an EHC high pressure piping leak. Power is stable at 2%, awaiting the Operations Superintendent approval to enter Mode 1. Currently in GO-3 section 5.2 step 14. The crew is then expected to raise reactor power to between 1 3% and 15%, per GO-3 Section 5.3.

Radiological changes in plant during shift:

None Part 2 - Performed by on-coming shift El A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUO5)

El A review of the Rounds sheets/Abnormal readings (AUO5 only)

Review the following programs for changes since last shift turnover:

El Standing Orders El LCO(s) in actions (N/A for AUOs)

El Immediate required reading El TACF (N/A for AUOs Part 3 - Performed by both off-going and on-coming shift El A walkdown of the MCR control boards (N/A for AUOs)

Relief Time: Relief Date:

TVA 40741 [03-20011 Page of I OPDP-l-I [03-14-2001]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # I Page 1 of 40 Event

Description:

Raise from 2% toward 14%

Time N Position N Applicants Actions or Behavior Booth Instructor:

No action required for Event I Indications available:

None Applicable SRO Raise load in accordance with GO-3 Unit Startup From Less Than 4% Reactor Power to 30% Reactor Power Evaluator Note: Following Steps are from GO-3 Unit Startup From Less Than 4%

Reactor Power to 30% Reactor Power starting at section 5.3 step I.

[1] REVIEW plant parameters and indications, and CHECK CREW stability before Reactor power escalation.

[2] IF SG blowdown is in-service, THEN ADJUST 1-HIC-15-43, SG BLOWDOWN FLOW CONTROL to desired flow rate (pt BOP F061 9A).

Step is N/A, blowdown is in service.

[3] INITIATE a methodical and deliberate rise in Reactor power RO to between 13 and 15% by rod withdrawal and/or RCS dilution.

Should use rod withdrawal as discussed in shift turnover.

[4] WHEN greater than 5% power, THEN LOG MODE 1 RO ENTRY.

[5] ENSURE MFW Bypass Reg Controllers maintain SG levels BOP on program.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 1 Page 2 of 40 Event

Description:

Raise from 2% toward 14%

Time Position U Applicants Actions or Behavior Evaluator Note: Lead Examiner may direct initiation of the next event at his discretion.

[6] WHEN greater than or equal to 10% power on at least 2-out-of-4 PRMs, THEN

[6.1] CHECK Permissive 64-F, P-10 NUC AT POWER RO PERMISSIVE, is LIT.

[6.2] CHECK Permissive 70-D, P-7 LO POWER TRIPS BLOCKED, is NOT LIT.

[6.3] COMPARE the highest PRM with the highest loop AT indication, and IF greater than 5% deviation exists, THEN STOP power rise, and NOTIFY the SRO.

Start of Critical Step(s)

[6.4] BLOCK the IR Hi-Flux Reactor trip and PR Lo-Flux Reactor trips by performing the following:

[6.4.1] PLACE the following switches to BLOCK:

. N38A, IR TRIP BLOCK P-b, AND

. N38B, IR TRIP BLOCK P-b

[6.4.2] CHECK PERMISSIVE 65-C, INTERMED RANGE RO TRIP BLOCKED, IS LIT.

[6.4.3] PLACE the following switches to BLOCK:

. N47A, PR LO POWER TRIP BLOCK P-b, AND

. N47B, PR LO POWER TRIP BLOCK P-lU

[6.4.4] CHECK ALARM 64-D, POWER RANGE LO SETPOINT TRIP BLOCKED, IS LIT.

End of Critical Step(s)

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 2 Page 3 of 40 Event

Description:

3 S/G PORV fails partially open Time Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 2 (Trigger 1)

Indications Tavg lowering zT Power rising PZR Pressure lowering Alarm 94A Tavg-Tref All Steam Dumps closed Crew Diagnose a cool down event.

Evaluator Note: The crew may take any of the following actions:

Take PRUDENT Operator action JAW Tl-12.04 to close #3 S/G PORV by either using 1-HS-1-24 or by placing 1-PlC-1-24A to MANUAL and close.

Perform actions IAWAOI-38 MAIN STEAM OR FEEDWATER LINE LEAK Direct actions per AOI-38 MAIN STEAM OR FEEDWATER SRO LINE LEAK Evaluator Note: The following are the first 3 steps are out of AOI-38 MAIN STEAM OR FEEDWATER LINE LEAK

1. IF leak threatens personnel safety, THEN:

a. TRIP Rx.

RO

b. CLOSE all MSIVs and bypass valves.

c. ** GO TO E-O, Reactor Trip or Safety Injection.

BOP 2. CHECK S!G PORVs CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# Spare Event# 2 Page 4 of 40 Event

Description:

3 S/G PORV fails partially open Time N Position Applicants Actions or Behavior BOP 3. CHECK steam dump valves CLOSED.

Evaluator Note: The following are steps the SRO should perform Evaluate Tech Specs:

3.7.4 Atmospheric Dump Valves (ADV5)

LCO 3.7.4 Four ADV lines shall be OPERABLE.

APPLICABILITY: MODES 1.2, and 3, MODE 4 when steam generator is relied upon for heat removal.

SRO ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ADV line A.1 Restore required ADV line to 7 days inoperable. OPERABLE status.

Should stop the power escalation, if still if in Mode 2 SRO Initiate Repairs When Tech Specs have been addressed, or at Lead Examiners discretion, proceed to the next event.

Appendix D Required Operator Actions Form ES-D2 Op Test No.: NRC Scenario # Spare Event # 3 Page 5 of 40 Event

Description:

Auctioneered Tavg fails high.

Time N Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 3 (Trigger 2)

Indications available:

Alarm 92A PZR Level Hi/Lo Alarm 94B Tavg-Tauct Deviation Auctioneered Tavg failed high on 1TR-68-2B.

Charging Flow rising Pressurizer Level rising The crew should diagnose that there has been a failure C rew affecting Auctioneered Tavg.

May take Prudent Operator action lAW Tl-12.04 to place RO Charging (1-FCV-62-93) in manual and lower charging flow to normal.

Evaluator Note (1): The crew may go to either A 01-2 MALFUNCTION OF REACTOR CONTROL SYSTEM orAOl-20, MALFUNCTION OF PRESSURIZER LEVEL CONTROL SYSTEM. (ARI-92A has a step which states: IF Malfunction Of Pressurizer Level Control System, THEN GO TO A 01-20)

Evaluator Note (2): Following Steps are from A 01-20, MALFUNCTION OF PRESSURIZER LEVEL CONTROL SYSTEM.

1. CHECK pzr level program signal NORMAL:

. LR-68-339 (green pen).

Perform RNO:

PERFORM the following:

RO

a. PLACE charging valve controller 1-HIC-62-93A in MAN, and RESTORE level to normal.

b. IF letdown in service, THEN GO TO Step 10.

10. INITIATE repairs to failed instrument/circuitry.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 3 Page 6 of 40 Event

Description:

Auctioneered Tavg fails high.

Time N Position Applicants Actions or Behavior 1 1. RETURN TO instruction in effect.

RO Evaluator Note: FollowIng Steps are from A 01-2 MALFUNCTION OF REACTOR CONTROL SYSTEM.

Directs actions lAW AOI-2 MALFUNCTION OF REACTOR CONTROL SYSTEM 3.1 Diagnostics Diagnostics IF GO TO Subsection Continuous Rod Withdrawal/Insertion 3.2 (Page 6)

SRO Instrument failure (e.g. T-avg. NIS. PT-1-73) with Rod Control in MAN 3.2 (Page 6)

Dropped RCCA 3.3 (Page 11)

RCCA Misalignment 3.4 (Page 21)

Rod Position Indicator (RPI) Malfunction 3.5 (Page 39)

Failure of Control Rods to Move on Demand 3.6 (Page 42)

Goes to Subsection 3.2 RO 1. PLACE control rods in MAN.

RO 2. CHECK control rod movement STOPPED.

3. MAINTAIN T-avg on PROGRAM. (Reference Attachment 1)

RO

USE control rods.

OR

ADJUST turbine load.

4. CHECK loop T-avg channels NORMAL.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 3 Page 7 of 40 Event

Description:

Auctioneered Tavg fails high.

Time Position Applicants Actions or Behavior

5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.

Perform RNO:

CONTROL pzr level in MAN with 1-FCV-62-93.

(Reference Attachment 1)

RX TAVG- PZR POWER TREF LEVEL RO 2% 557.6 °F 25.7 %

4% 558.2 °F 26.4 %

6% 558.8 °F 27.1 %

8% 559.3 °F 27.8 %

10% 559.9 °F 28.5 %

12% 560.5 °F 29.2 %

14% 561.1 °F 29.9%

6. CHECK NIS power range channels NORMAL.

RO

7. CHECK the following:

. Turbine impulse pressure channel 1-Pl-1-73, NORMAL.

. Tref and Auct Tavg NORMAL on 1 -TR-68-2B Perform RNO: (No actions required, since plant in Startup Mode)

BOP PLACE steam dumps in pressure mode as follows:

a. PLACE steam dumps to OFF.

b. PLACE mode selector HS to STEAM PRESS.

c. ADJUST steam dump demand to zero.

d. PLACE steam dumps to ON.

e. ENSURE controfler set at 84% (1092 psig).

f. WHEN conditions allow, THEN REFER TO 501-i .02 and PLACE steam dumps in TAVG Mode.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 3 Page 8 of 40 Event

Description:

Auctioneered Tavg fails high.

Time Position N Applicants Actions or Behavior

8. MONITOR core power distribution parameters:

. Power range channels.

. A Flux Indicators.

. T-avg.

RO

Loop LIT.

. Incore TCs.

Feed flow/Steam flow.

Should be no changes SRO 9. INITIATE repairs to failed equipment.

10. REFER TO Tech Specs:

SRO none applicable.

At discretion of the Lead Examiner, proceed to the next event H

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 4 Page 9 of 40 Event

Description:

1A CCS Pump trips. lB CCS pump fails to auto start on low pressure Time Position Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 4 (Trigger 3)

Indications available:

CCS PMPS IA-A & lB-B DISCH PRESS LO [250C].

LOW FLOW (headers or individual equipment).

Breaker disagreement WHITE light on 1-HS-70-46A CCS PMP IA-A Handswitch Alarm 226E ERCW/CCS Motor Tripout The crew should diagnose that there has been a failure Crew affecting CCS flow.

May take Prudent Operator action lAW Tl-12.04 to start 1 B BOP CCS Pump and place the 1A in PTL.

Evaluator Note: Following Steps are from A 01-15 Loss of Component Cooling Water Directs actions lAW AOl-15 Loss of Component Cooling Water 3.1 Diagnostics IF GOTO Loss of ccs Flow, Subsection 3.2 OR Surge tank level less than 60%

or dropping uncontrolled.

SRO Surge tank level greater than 72% or Subsection 3.3 rising uncontrolled OR CCS Rad Monitor alarm.

Loss of OCS due to loss of Ac power train. AOl-35 Goes to Subsection 3.2

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event# 4 Page 10 of 40 Event

Description:

1A CCS Pump trips. lB CCS pump fails to auto start on low pressure Time Position Applicants Actions or Behavior

1. CHECK CCS pumps status:

a. CHECK any CCS pump TRIPPED or running pump NOT pumping forward:

. ERG W/CCS Motor tripout alarm,

. Low header pressure (train A or B),

. Multiple low flow alarms.

b. CHECK at least one U-i Train A header supply pump BOP RUNNING AND pumping forward:

iA-A

. lB-B Should diagnose that IA CCS Pump is tripped. Should perform RNO to start lB CCS

b. START available U-i Train A CCS Pump.

c. CHECK any Train B header supply pump RUNNING AND pumping forward:

BOP

C-S

2B-B Determines that B Train is operating properly BOP d. PLACE any non-operable or tripped CCS pump in STOP/PULL-TO-LOCK.

e. CHECK TWO U-lTrain A header supply pumps RUNNING:

iA-A

lB-B Perform RNO:

BOP ENSURE at least one of the following CLOSED to avoid excessive flow:

RHR htx A, i-FCV-70-i56, OR

SEP htx A, O-FCV-70-i97.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 4 Page 11 of 40 Event

Description:

1A CCS Pump trips. lB CCS pump fails to auto start on low pressure Time Position Applicants Actions or Behavior

f. CHECK flows returned to NORMAL.

BOP Determines that flows returned to normal due to absence of alarms.

g. CHECK A and B side surge tank levels between 57% and BOP 85%.

BOP h. GO TO Step 15.

BOP Evaluator Note: AOl-15 Appendix A pages are at the end of this document.

15. EVALUATE affected equipment BOP operation_USING_Appendix_A.

16. WHEN CCS returned normal, THEN CHECK only one CCS pump per Train. CHECK one TBBP running.

Will need to Perform RNO and stop and place one TBBP in P-Auto BOP IF 2 CCS pumps or 2 TBBPs running, THEN:

. STOP second running CCS pump and Return HS to A P AUTO.

. STOP second running TBBP pump and Return HS to A-PUTO.

Evaluator Note: Following Steps are from ARI-11O-D LTDN TO DEMINS TEMP HI

[1] IF letdown temperature is greater than 137.5 F on Q

1-Tl-62-78 t1-M-6J. THEN ENSURE CVCS demineralizers bypassed (lights above 1-HS-62-79

[1-M-61).

RO [2) ENSURE letdown flow is 45 gpm to 120 gpm on 1-Fl-62-82 [1..M-6J.

[3] ENSURE charging flow is 57 gpm to 132 gprn on 1-Fl-62-93A

[1-M-5].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 4 Page 12 of 40 Event

Description:

1A CCS Pump trips. lB 005 pump fails to auto start on low pressure Time Position Applicants Actions or Behavior After CCS is restored RO [4] ADJUST 1-HIC-62-78A to maintain letdown temperature less than 127 F on 1-Tl-62-78.

[7] WHEN ready to return to normal. THEN RO PLACE 1-HS-62-79A. LTDN HI TEMP DIVERT, in DEMIN position, and HOLD until 1-TCV-62-79 is fully open.

Evaluator Note: Following Steps are SRO Actions in A 01-15

17. REFER TO Tech Specs 3.7.7, Component Cooling Water System (CCS).

SRO Enters LCO 3. 7.7 condition A for one train CCS inoperable.

SRO 18. INITIATE repairs.

GO TO appropriate plant procedure.

SRO When technical specifications have been identified or at discretion of the Lead Examiner, proceed to the next event

LAppendix D Required Operator Actions Form ES-D-2 OpTestNo.: NRC Scenario# Spare Event# 4 Page 13 of 40 Event

Description:

1A CCS Pump trips. lB CCS pump fails to auto start on low pressure Time N Position Applicants Actions or Behavior I AOI-15 WBN LOSS OF COMPONENT COOLING WATER (CCS) Revision 30 Page27of3l APPENDIX A Page 1 of 2 HEADER CROSS-REFERENCE ESF EQUIPMENT IA COMPONENT NORMAL FLOW FLOW INDICATOR CCP 1A Gear & Oil CIr 28 gpm 1-FI-70-146 SIP 1A Oil Cir 15 gpm 1-FI-70-147 CS Pump 1A Oil CIr 2 gpm 1-FI-70-150 RHR Pump 1A Seal Hx 10 gpm 1-FI-70-151 RHR Hx 1A 5000 gpm 1-Fl-7D-158 ESF EQUIPMENT lB COMPONENT NORMAL FLOW

[ FLOW INDICATOR 1-FI-70-145 CCP lB Gear & Oil CIr 28 gpm SIP lB Oil CIr 15 gpm 1-FI-70-148 CS Pump lB Oil Clr 2 gpm 1-FI-70-149 RHR Pump lB Seal Hx 10 gpm l-FI-70-152 RHR Hx lB 5000 gpni 1-FI-70-l55

Appendix D Required Operator Actions Form ES-D-21 Op Test No.: NRC Scenario # Spare Event # 4 Page 14 of 40 Event

Description:

1A CCS Pump trips. 1 B 005 pump fails to auto start on low pressure Time Position N Applicants Actions or Behavior AOI-15 WBN LOSS OF COMPONENT COOLING WATER (CCS) Revision 31 Page 28 of 31 APPENDIX A Page 2 of 2 HEADER CROSS-REFERENCE Equipment Affected by Isolation of the Rx Bldg or Misc Equip Hdr NOTE: All listed equipment affected by isolation Misc Equip and Rx Bldg Hdrs.

COMPONENT ACTION RX BLDG HDR EQUIPMENT Excess Letdown Hx Remove from service USING SOl-62.01.

Stop RCP(s) if motor bearing rises to 195°F RCP Motor Bearings (alarm @ 185°F).

RCPs must be tripped within 10 minutes of loss of 005 to oil coolers.

Thermal Barrier Booster Pump Stop TB pumps. Check RCP seal temp & flow.

supply Post Accident Sampling Notify Chemistry.

MISC HDR EQUIPMENT Seal Water Hx Check VCT temp. Should be slight rise in seal supply temp (max 130°F).

Letdown Hx Isolate charging and letdown (Excess Letdown is NOT available).

Sample Hxs Notify Chemistry.

Waste Gas Compressor Remove from service USING SO1-77.02

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# Spare Event# 5&6 Page 15 of 40 Event

Description:

Dropped Control Rod Time N Position N Applicants Actions or Behavior Booth Instructor:

When directed, initiate Event 5 & 6 (Trigger 4)

Indications available:

Alarm 87D Rod at Bottom Rod H-12 indicates fully inserted Reactor Power Nis lowering The crew should diagnose that there has been a dropped Crew Control Rod.

The SRO may direct the reactor trip breakers at any time the SRO crew believes the reactor is subcritical.

Evaluator Note: Following Steps are from AOl-2 MALFUNCTION OF REACTOR CONTROL SYSTEM Directs actions lAW AOI-2 MALFUNCTION OF REACTOR CONTROL SYSTEM 3.1 Diagnostics Diagnostics IF GO TO Subsection Continuous Rod Withdrawal/Insertion 3.2 (Page 6)

SRO Instrument failure (e.g. T-avg. NIS. PT-1-73) with Rod Control in MAN 3.2 (Page 6)

Dropped RCCA 3.3 (Page 11)

RCCA Misalignment 3.4 (Page 21)

Rod Position Indicator (RPI) Malfunction 3.5 (Page 39)

Failure of Control Rods to Move on Demand 3.6 (Page 42)

Goes to Subsection 3.3

1. PLACE control rods in MAN.

RO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 5& 6 Page 16 of 40 Event

Description:

Dropped Control Rod Time N Position Applicants Actions or Behavior

2. CHECK core power distribution parameters normal:

Power Range Channels

. AFlux Indicators

. Tavg RO

Loop AT

Incore TCs

Feed Flow/Steam Flow Continue with Step 4.

EVALUATOR NOTE: The following step will be required when the second rod drops into the core.

4. IF two or more RCCAs have dropped, THEN:

a. TRIP reactor.

RO

b. GO TO E-O, Reactor Trip or Safety Injection.

5. ENSURE T-avg and T-ref within 3LIF:

ADJUST turbine load and/or Boron concentration as RO necessary.

NO ACTION SHOULD BE PERFORMED

6. MONITOR core power distribution parameters:

Power range channels.

AFlux Indicators.

RO

T-avg.

Core AT.

IncoreTCs.

. Feed flow/Steam flow.

7. RESET any power range monitor POSITIVE RATE TRIP BOP window LIT, [1-M-13].

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario# Spare Event# 5&6 Page 17 of 40 Event

Description:

Dropped Control Rod Time N Position Applicants Actions or Behavior NOTE If the reactor is subcritical, retrieval of a dropped rod is NOT the conservative action. Reactor Engineering evaluation should consider opening the reactor trip breakers.

Lead Evaluator Note: If the crew directs a NAUO to open the reactor trip breakers, queue the console operator to delete the time delay for the second dropped rod and implement the malfunction at this time.

8. NOTIFY Reactor Engineering to evaluate core anomaly.

SRO

9. NOTIFY STA to perform 1-Sl-O-21, Excore QPTR.

SRO Step is N/A.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event# 5&6 Page 18 of 40 Event

Description:

Dropped Control Rod Time Position Applicants Actions or Behavior

10. REFER TO Tech Specs:

3.1.5, Rod Group Alignment Limits.

Tech Spec 3.15 applies 1<. ..ne rod :0, rirhir. .0 oro rod towi:[iir:

, ii ii flirt. juno-.- 1 oni O.Z1,! ,rnj rn

1. .r::,n not) i:,..I.. Iitittt SRO f-.... ]u--t1,,n. n.nne:v 1 1. RECORD the following information:

. Time the RCCA dropped.

Core location of RCCA.

SRO

Reactor power prior to dropping.

Affected RCCA height prior to dropping.

At discretion of the Lead Examiner, proceed to the next event

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 19 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time Position N Applicants Actions or Behavior Booth Instructor: NONE Indications SRO Directs RO to manual trip the Reactor.

Evaluator Note: A LB LOCA occurs at the tIme of the reactor trip, with a failure of auto initiation of both trains of SI Evaluator Note: The following are steps from E-O.

NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

NOTE 2 Status Trees / SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RO

RPIs at bottom of scale.

Neutron flux DROPPING.

2. ENSURE Turbine Trip:

RO

All turbine stop valves CLOSED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 20 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time Position JL Applicants Actions or Behavior

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:CSST (offsite), OR DIG RO (blackout).

4. CHECK SI actuated:

a. Any SI annunciator LIT.

Perform RNO:

DETERMINE if SI required:

a. IF ANY of the following exists:

S/G press less than 675 psig, OR

RCS press less than 1870 psig, RO OR

Cntmt press greater than 1 .5 psig CRITICAL TASK #1 THEN ACTUATE SI manually.

b. Both trains SI ACTUATED.

1 -XX-55-6C

1-XX-55-6D Evaluator Note: RCP Trip Criteria conditions lAW E-O Foldout page are applicable:

FOLDOUT for E-O RCP TRIP CRITERIA

Phase B Isolation, OR

One charging pump OR one SI pump injecting AND RCS press reduced uncontrolled to less than 1500 psig.

Adverse #s are also in effect due to the Phase B

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 21 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time N Position Applicants Actions or Behavior BOP Evaluator Note: Appendix A (E-O), SI Support Systems, and Appendix B, Phase B Pipe Break Contingencies are contained at the end of this document.

BOP

EVALUATE support systems:

REFER TO Appendixes A and B (E-0), Equipment Verification pages 15-28.

6. ANNOUNCE reactor trip and BOP safety injection over PA system.

7. ENSURE secondary heat sink RO available with either:

Total AFW flow greater than 410 gpm, OR

At least one S!G NR level greater than 29% [39% ADV].

8. MONITOR RCS temp stable at or trending to 557°F:

IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 557°F.

RO OR

IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 557°F.

9. ENSURE excess letdown valves CLOSED:

BOP 1-FCV-62-54

1-FCV-62-55

10. CHECK pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

RO

b. At least one block valve OPEN.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 22 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time Position N Applicants Actions or Behavior 1 1. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic RO monitors.

12. CHECK pzr sprays CLOSED.

RO

13. CHECK if RCPs should remain in service:

a. Phase B signals DARK [MISSP].

RO Perform RNO:

a. STOP all RCPs.** GO TO Step 14.

14. CHECK S!G pressures:

All S/G pressures controlled or rising.

RO

All S/G pressures greater than 120 psig.

15. CHECK for RUPTURED S!G

All S/Gs narrow range levels CONTROLLED or RO DROPPING.

Secondary side radiation NORMAL from Appendix A.

16. CHECK cntmt conditions:

Cntmt pressure NORMAL.

Radiation NORMAL from Appendix A.

BOP

Cntmt sump level NORMAL.

Cntmt temp ann window DARK [1 04-B).

Perform RNO:

GO TO E-1, Loss of Reactor or Secondary Coolant.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 23 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time Position N Applicants Actions or Behavior Evaluator Note(1): SRO should direct the crew to GO TO E-1 at this point. The following steps are from E-1.

Evaluator Note(2): SRO should direct the crew to GO FR-P.1 when the STA reports RED path for Pressurized Thermal Shock status tree.

There is only one step to perform and then immediately back into E-1.

1. CHECK if RCPs should remain in service:

a. Phase B DARK [MISSP].

RO

b. RCS pressure greater than 1500 psig.

RNO already performed

2. REFER TO EPIP-1, Emergency Plan Classification SRO Flowchart.

3. RECORD current time to mark initiation of LOCA and SRO determination of time for hot leg recirc.

4. CHECK S!G pressures:

All S!G pressures controlled or rising.

BOP

All S/Gs pressures greater than 120 psig.

5. MAINTAIN Intact S!G NR levels:

a. MONITOR levels greater than [39% ADV].

BOP b. CONTROL intact S/G levels between [39% and 50%

ADV].

6. CHECK secondary radiation:

S!G discharge monitors NORMAL.

Condenser vacuum exhaust rad monitors NORMAL.

BOP

S!G blowdown rad monitor recorders NORMAL trend prior to isolation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 24 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time Position Applicants Actions or Behavior

7. ENSURE cntmt hydrogen analyzers in service:

PLACE 1-HS-43-200A in ANALYZE [M-10].

PLACE 1-HS-43-210A in ANALYZE [M-10].

BOP

CHECK low flow lights not lit [M-10].

Locally CHECK low analyzer temp lights NOT lit

[North wall of Train A 480V SD Bd rm].

8. MONITOR pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

RO

b. At least one block valve OPEN.

Evaluator Note: Containment Pressure should be less than 2 psig ap roximately 15 minutes post LOCA

9. DETERMINE if cntmt spray should be stopped:

a. MONITOR cntmt pressure less than 2.0 psig.

b. CHECK at least one cntmt spray pump RUNNING.

c. RESET cntmt spray signal.

RO

d. STOP cntmt spray pumps, and PLACE in A-AUTO.

e. CLOSE cntmt spray discharge valves 1-FCV-72-2 and 1-FCV-72-39.

10. ENSURE both pocket sump pumps STOPPED [M-15]:

1-HS-77-410.

BOP

1-HS-77-411.

1 1. CHECK SI termination criteria:

a. CHECK RCS subcooling greater than [85°F ADVJ.

RO Perform RNO:

a. GO TO Caution prior to Step 12.

12. RESET SI and CHECK the following:

SI ACTUATED permissive DARK.

RO

AUTO SI BLOCKED permissive LIT.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 25 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time osition Applicants Actions or Behavior

13. DETERMINE if RHR pumps should be stopped:

a. CHECK RCS pressure greater than 150 psig.

RO Perform RNO:

a. ENSURE RHR pumps RUNNING.GO TO Step 16.

16. MONITOR electrical board status:

a. CHECK offsite power available.

b. CHECK all shutdown boards ENERGIZED by offsite BOP power.

c. PLACE any unloaded D/G in standby USING SOI-82 Diesel Generators.

EVALUATOR NOTE: AOl-I 7, Turbine Trip BOP realignment steps are at the end of this document.

17. INITIATE BOP realignment:

BOP

REFER TO AOl-17, Turbine Trip.

EVALUATOR NOTE: E-1 Foldout page states:

SUMP RECIRC SWITCHOVER CRITERIA IF RWST level less than 34%, THEN GO TO ES-1.3, Transfer to RHR Containment Sump.

The crew should go to ES-1.3 when the RWST level gets to less than 34%.

18. INITIATE 480V board room breaker alignments USING the following:

Appendix A (E-1), CLA Breaker Operation.

Appendix B (E-1), Ice Condenser AHU Breaker BOP Operation.

Appendix C (E-1), 1-FCV-63-1 Breaker Operation.

Appendix D (E-1), 1-FCV-63-22 Breaker Operation.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 26 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time Position Applicants Actions or Behavior

19. DETERMINE if hydrogen igniters should be energized:

a. CHECK hydrogen analyzers in service.

b. CHECK cntmt hydrogen less than 5% [M-10].

BOP c. ENERGIZE hydrogen igniters [M-10j:

1-HS-268-73 ON.

1-HS-268-74 ON.

20. ENSURE RHR available for cntmt sump recirculation:

Power to at least one operable RHR pump AVAILABLE.

RO

Cntmt sump valve 1-FCV-63-72 or 1-FCV-63-73 to operable RHR pump AVAILABLE.

EVALUATOR NOTE: Appendix E (E-1), Equipment Evaluation is located at the back of this section.

21. EVALUATE plant equipment status:

SRO

REFER TO Appendix E (E-1), Equipment Evaluation.

22. CHECK Aux Bldg radiation for loss of RCS inventory outside cntmt:

a. Area monitor recorders 1-RR-90-1 and 0-RR-90-12 Aux BOP Bldg points NORMAL.

b. Vent monitor recorder 0-RR-90-101 NORMAL trend prior to isolation.

23. NOTIFY Chemistry of event status and plant conditions.

SRO

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 27 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time N Position N Applicants Actions or Behavior

24. DETERMINE if RCS cooldown and depressurization is required:

a. CHECK RCS pressure greater than 150 psig.

RO Perform RNO:

a. IF RHR pump injecting to RCS, THEN GO TO Step 25.

25. PREPARE for switchover to RHR cntmt sump:

a. ENSURE power restored to 1-FCV-63-1 USING Appendix C (E-1), 1-FCV-63-1 Breaker Operation.

RO b. CHECK RWST less than 34%.

Perform RNO:

GO TO Step 20.

EVALUATOR NOTE: The crew will loop between steps 20 and 25 until RWST is less than 34% and go then to ES-1.3.

The following step are out of ES-1.3:

1. ENSURE both RHR pumps RUNNING.

RO

2. ESTABLISH CCS to RHR heat exchangers {M-27B]:

a. ENSURE RHR heat exchanger outlet valves 1-FCV-70-1 53 and 1-FCV-70-156 OPEN.

b. CLOSE SFP heat exchanger A CCS supply 0-FCV-70-1 97.

BOP c. ENSURE CCS flow to ESF supply header and greater than 5000 gpm.

. Train A: 1-FI-70-159

Train B: 1-Fl-70-165

d. MONITOR level in CCS surge tanks.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 28 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time Position Applicants Actions or Behavior RO 3. CHECK RWST level less than 34%.

RO 4. CHECK cntmt sump level greater than or equal to 16.1 %.

EVALUA TOR NOTE: RO WILL BE REQUIRED TO MANUALLY OPEN CNTMT SUMP VALVES 1-FCV-63-72 and 1-FCV-63-73.

PART OF

5. ENSURE automatic switchover complete:

CRITICAL

a. ENSURE cntmt sump valves 1-FCV-63-72 and i-FCV TASK #2 63-73 OPEN.

b. ENSURE RWST to RHR suction valves 1-FCV-74-3 RO and 1-FCV-74-21 CLOSED.

c. INITIATE power restoration to 1-FCV-63-1 USING Appendix A (ES-i .3), 1-FCV-63-1 Breaker Operation.

RO 6. MONITOR RWST level greater than 8%.

Evaluator Note: Both steps 7 & 8 are included however, only one step will be performed, depending upon Containment Pressure when the crew reaches step 7.

7. DETERMINE if cntmt spray should be stopped:

a. MONITOR cntmt press less than 2.0 psig.

RNO: WHEN cntmt press less than 2.0 psig, THEN PERFORM Substeps 7b thru e. GO TO Step 8.

b. CHECK at least one cntmt spray pump RUNNING.

RO RNO: IF both spray pumps stopped, THEN GO TO Step 9.

c. RESET cntmt spray signal.

d. STOP cntmt spray pumps and PLACE in A-AUTO.

e. CLOSE cntmt spray discharge valves 1-FCV-72-2 and 1-FCV-72-39.

f. GO TO Step 9.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 29 of 40 Event

Description:

E-0, E-1 LBLOCA to ES-i .3 Time Position Applicants Actions or Behavior

8. DETERMINE if ONE train cntmt spray should be stopped:

a. CHECK BOTH trains cntmt spray delivering flow.

RNO: GO TO Step 9.

RO

b. RESET cntmt spray signal.

c. STOP ONE cntmt spray pump and PLACE in A-AUTO.

d. CLOSE spray discharge valve for stopped pump.

RO 9. IF RCS press rises to greater than 1350 psig, THEN STOP both SI pumps.

PART OF

10. (#1) ISOLATE SI pump miniflow:

CRITICAL

CLOSE 1-FCV-63-3.

TASK #2 RO

CLOSE 1-FCV-63-175.

CLOSE 1-FCV-63-4.

PART OF

11. (#2) ISOLATE RHR crossties:

CRITICAL

CLOSE 1-FCV-74-33.

TASK #2 RO

CLOSE 1-FCV-74-35.

PART OF

12. (#3) ALIGN charging pump and SI pump supply from RHR:

CRITICAL

OPEN 1-FCV-63-6.

TASK #2 RO

OPEN 1-FCV-63-7.

ENSURE 1-FCV-63-177 OPEN.

PART OF

13. (#4) ALIGN RHR discharge to charging pump and SI pump CRITICAL suction:

TASK #2 RO a. OPEN 1-FCV-63-8.

b. OPEN 1-FCV-63-11.

Evaluator Note: The scenario may end at this point or any step up thru step 20 at the discretion of the Lead Evaluator

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 7, 8, & 9 Page 30 of 40 Event

Description:

E-0, E-i LBLOCA to ES-i .3 Time Position Applicants Actions or Behavior F

14. DO NOT CONTINUE this Instruction UNTIL Steps 10 thru RO 13 complete.

15. RESTART any charging pumps and SI pumps as RO necessary.

16. (#5) RESET SI, and CHECK the following:

SI ACTUATED permissive DARK.

RO

AUTO SI BLOCKED permissive LIT.

17. IF offsite power is lost, THEN:

a. PLACE charging pumps in PULL TO LOCK.

b. RESTART RHR pumps.

RO

c. RESTART charging pumps.

d. IF RCS press less than 1350 psig, RESTART SI pumps.

18. (#6) ISOLATE charging pump suction from RWST:

a. CLOSE 1-LCV-62-135.

b. CLOSE i-LCV-62-136.

RO

c. ENSURE 1-HS-62-135A in A-AUTO (pushed in).

d. ENSURE 1-HS-62-136A in A-AUTO (pushed in).

19. (#7) ISOLATE SI pump suction from RWST:

RO

CLOSE 1-FCV-63-5.

20. (#8) ISOLATE RHR suction from RWST:

RO a. ENSURE power restored to 1-FCV-63-1 USING Appendix A (ES-i .3), 1-FCV-63-1 Breaker Operation.

b. CLOSE 1-FCV-63-1.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 8 Page 31 of 40 Event

Description:

E-0 Appendix A and B Time I Position Applicants Actions or Behavior Booth Instructor: NONE Indications: None Directs BOP to perform E-O STEP 5:

5. EVALUATE support systems:

SRO

REFER TO Appendixes A and B (E-0), Equipment Verification pages 15-28.

Evaluator Note: The following are E-O Appendix A steps.

Evaluator Note: The SRO may at times interrupt the BOP, during the performance of Appendixes A and B, to perform other higher pr ority task.

1. ENSURE PCBs OPEN:

PCB 5044.

BOP

PCB 5088.

2 ENSURE AFW pump operation:

Both MD AFW pumps RUNNING.

BOP

TD AFW pump RUNNING.

LCVs in AUTO, or controlled in MANUAL.

3. ENSURE MFW isolation:

MFW isolation and bypass isolation valves CLOSED.

MFW reg and bypass reg valves CLOSED.

MFP A and B TRIPPED.

BOP

Standby MFP STOPPED.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.; NRC Scenario # Spare Event # 8 Page 32 of 40 Event

Description:

E-0 Appendix A and B Time Position N Applicants Actions or Behavior

4. MONITOR ECCS operation:

a. Charging pumps RUNNING.

b. Charging pump alignment:

RWST outlets 1-LCV-62-135 and 1-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1-LCV-62-133 CLOSED.

Charging 1-FCV-62-90 and 1-FCV-62-91 CLOSED.

c. RHR pumps RUNNING.

d. SI pumps RUNNING.

BOP e. BIT alignment:

Outlets 1-FCV-63-25 and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater than 1650 psig.

RNQ not >l65Opsig:

f. ENSURE SI pump flow. IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

5 CHECK cntmt isolation:

a. Phase A isolation:

Train A GREEN.

Train B GREEN.

BOP

b. Cntmt vent isolation:

Train A GREEN.

Train B GREEN.

Annendix D Required Onerator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 8 Page 33 of 40 Event

Description:

E-0 Appendix A and B Time Position Applicants Actions or Behavior Evaluator Note: WHEN 10 minutes has elapsed since Phase B actuated, the Air Return Fans will fail to auto start. See item 9 below:

6. CHECK cntmt pressure:

Phase B DARK [MISSP].

Cntmt Spray DARK {MISSP].

Cntmt press less than 2.8 psig.

Perform RNO:

PERFORM the following:

1) ENSURE Phase B actuated.

2) ENSURE Cntmt Spray actuated.

3) ENSURE cntmt spray pumps running.

BOP 4) ENSURE cntmt spray flow.

5) ENSURE Phase B isolation:

Train A GREEN.

Train B GREEN.

6) STOP all RCPs.

7) ENSURE MSIVs and bypasses CLOSED.

8) PLACE steam dump controls OFF.

9) WHEN 10 minutes has elapsed since Phase B actuated, THEN ENSURE air return fans start.

10) USE_adverse_cntmt_[ADVI_setpoints_where_provided.

7. CHECK plant radiation NORMAL:

S/G blowdown rad recorder 1-RR-90120 NORMAL prior to isolation [M-12].

Condenser vacuum exhaust rad recorder 1-RR 119 NORMAL prior to trip {M-12].

1-RR-90-106 and 1-RR-90-112 radiation recorders BOP NORMAL prior to isolation [M-12].

S/G main steamline discharge monitors NORMAL.

Upper and Lower containment high range monitors NORMAL [M-30].

NOTIFY Unit Supervisor conditions NORMAL.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 8 Page 34 of 40 Event

Description:

E-0 Appendix A and B Time Position Applicants Actions or Behavior 8 ENSURE all D/Gs RUNNING.

BOP

9. ENSURE ABGTS operation:

a. ABGTS fans RUNNING.

b. ABGTS dampers OPEN:

FCO-30-146A.

BOP

FCO-30-146B.

FCO-30-157A.

FCO-30-157B.

10. ENSURE at least four ERCW pumps RUNNING, one on BOP each shutdown board preferred.

1 1. ENSURE ERCW supply valves OPEN to running DIGs.

BOP

12. ENSURE CCS HX C ALT DISCH TO HDR B, 0-FCV BOP 152, is open to position A.

13. CLOSE CCS HX C DISCH TO HDR A, 0-FCV-67-144.

BOP

14. MONITOR EGTS operation:

EGTS fans RUNNING.

ENSURE dampers OPEN VERIFY filter bank dp BOP between 5 and 9 inches of water.

15. ENSURE CCS pumps RUNNING:

lA-A CCS pump.

lB-B CCS pump.

BOP

C-S OR 2B-B CCS pump.

16. CHECK CNTMT PURGE fans STOPPED:

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 8 Page 35 of 40 Event

Description:

E-0 Appendix A and B Time Position Applicants Actions or Behavior

17. CHECK FUEL HANDLING EXH fans STOPPED, Fuel and Cask loading dampers CLOSED:

BOP

18. ENSURE AB GEN SUPPLY and EXH fans STOPPED.

BOP

19. ENSURE AB GEN SUP & EXH dampers CLOSED.

BOP

20. ENSURE MCR & SPREAD RM FRESH AIR dampers CLOSED:

DCD *FCV-31-3.

FCV-31-4.

21. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, OR Fan B-B BOP RUNNING.

FCO-31-8, OPEN OR FCO-31-7, OPEN.

22. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

CB EMERG PRESS FAN A-A, OR FAN B-B RUNNING.

BOP

FCO-31-6, OPEN. OR FCO-31-5, OPEN.

23. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY and EXH FANS AND BOP dampers.

TOILET & LKR RM EXHAUST FAN AND dampers.

24. INITIATE Appendix B.

BOP

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # 8 Page 36 of 40 Event

Description:

E0 Appendix A and B Time Position Applicants Actions or Behavior Evaluator Note: E-O Appendix B is listed below 1 CHECK PHASE B actuated BOP

2. ENSURE 1-FCV-32-1 10 CLOSED. (CISP XX-55-6E) [A-BOP train, window 13]

3. ENSURE 1-FCV-67-107 CLOSED. (CISP XX-55-6E) [A -

BOP train, window 43]

4. ENSURE 1-FCV-70-92 CLOSED. (CISP - 1-XX-55-6E) [A -

BOP train, window 73]

5. ENSURE 1-FCV-70-140 CLOSED. (CISP XX-55-6F) [B -

BOP train, window 74]

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # None Page 37 of 40 Event

Description:

AOI-17 BOP Realignment Time N Position N Applicants Actions or Behavior Booth Instructor: NONE Indications: NONE Evaluator Note: The following are the first ten steps from AOl-17 Turbine Trip, it is not expected that the 80P will perform all of these steps due to other higher priority issues..

CAUTION Performance of this instruction should not be allowed to delay or interfere with actions required by applicable emergency procedures or abnormal operating procedures.

NOTE I Control room operators may initiate shutdown of pumps and equipment from the benchboard immediately after a trip. Performance of this instruction will subsequently verify proper secondary equipment alignment.

NOTE 2 Steps in this section and items in Attachment 1 may be performed out of sequence.

1 DISPATCH turbine building NAUO to perform Attachment 1.

BOP

2. NOTIFY condensate demineralizer NAUO prior to Operator SOP initiated press changes in condensate.

3. REMOVE generator excitation from service:

a. PLACE voltage regulator to TEST.

b. ZERO exciter base adjuster.

BOP

c. OPEN exciter field breaker.

d. PLACE exciter regulator control to OFF.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # None Page 38 of 40 Event

Description:

AOI-17 BOP Realignment F Time N Position N Applicants Actions or Behavior

4. MONITOR main turbine:

a. WHEN less than 1500 rpm, THEN:

. ENSURE seal oil backup pump RUNNING.

. ENSURE turning gear oil pump RUNNING.

b. WHEN less than 600 rpm, THEN ENSURE bearing lift oil pump RUNNING.

c. WHEN turbine is at ZERO RPM, THEN ENSURE turbine on turning gear.

BOP d. MAINTAIN MTOT lube oil temp between 95° and 100°F (may require RCW isolation if TCV has excessive leakage).

e. MAINTAIN GENERATOR H2 (Cold Gas) temp 95°F (may require RCW isolation if TCV has excessive leakage).

f. ENSURE Gland Steam Spillover Bypass valve is CLOSED using 1-HS-47-191A.

5. ALIGN MSRs:

a. PUSH RESET on MSR control panel.

b. CLOSE MSR HP steam and bypass isol.

BOP c. ENSURE MSR warming valves CLOSED.

d. OPEN MSR startup vents.

e. CLOSE MSR operating vents.

BOP 6. CHECK MSIVs OPEN.

7. ENSURE adequate FW press:

a. ENSURE two hotwell pumps RUNNING.

b. IF FW isolation reset, THEN ENSURE one condensate booster pump RUNNING if needed for unit conditions.

c. ENSURE CNDS demin pumps OFF.

BOP d. STOP #3 HDT pumps, and CLOSE the discharge valves to condensate heater strings. Notify NAUO performing Attachment 1 that #3 HDT pumps are stopped.

e. STOP #7 HDT pumps, and CLOSE the discharge valves to condensate heater strings.

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: NRC Scenario # Spare Event # None Page 39 of 40 Event

Description:

AOl-17 BOP Realignment Time Position Applicants Actions or Behavior

8. SHUTDOWN any MEW pump NOT BOP required.

9. SHUTDOWN any RCW pumps NOT BOP required.

10. SHUTDOWN any CCW pumps NOT BOP required.

APPENDIX E (E-1)

Page 1 of 1 EQUIPMENT EVALUATION

1. EVALUATE plant equipment and systems needed to support long term cooling and recovery actions, as time and personnel availability permits:

a. Cntmt Isolation Status.

b. Emergency Gas Treatment System:

One train in operation, REFER TO SOI-65.02.

c. Auxiliary Building Gas Treatment:

One train in operation, REFER TO SOI-30.06.

d.Auxiliary Building Isolation alignment:

REFER TO SOI-30.06.

e. Main Control Room Isolation alignment:

REFER TO SO1-31.O1.

f. ERCW System:

Both trains in operation.

g. Component Cooling Water System:

Both trains in operation.

ML102371256

Text

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description:

Description: