Text

Initial Exam 2011-301 Draft Simulator Scenarios
	ML111960216
Person / Time
Site:	Farley
Issue date:	07/02/2011
From:	; NRC/RGN-II
To:	; Southern Nuclear Operating Co
References
	50-348/11-301, 50-364/11-301, ES-D-1
	Download: ML111960216 (457)
	v • d • e

Appendix D Scenario Outline Form ES-D-l AFT SUB41TT*

Facility: Farley Nuclear Plant Examiners:

j Scenario No.: 7 Op-Test No.: FA2O1 1-301 Operators: SRO RO BOP Initial Conditions: 72% power, continuing a ramp to 100%

power, 909 ppm, MOL.

GB D at 175 steps. (Xe is -1795 pcm and building in)

Turnover:

. 2C DG TIC for governor work. (OOS 2 days, ETA 4 hrs)

. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETA 2 hrs)

. Fuel handling is on going in the SFP room with the last fuel bundle being moved.

. Current Risk Assessment is and projected is GRUEI,

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama

& Western Georgia SPLIT TRAIN ALIGNMENT Event Malt. Event Type*

No. Event Description No.

1 I (RO) PT-444 fails high 1

TS (SRO) TS 3.4.1 DNB (low pressure) 2 I (BOP) R-25A FAILS HIGH and SEP ventilation does not secure, 2 PRF starts TS (SRO) TS 3.3.8 3 3 I (RO) LK-459F fails LOW 4 4 A (RO & 1A RCP #1 seal fails to 7 over 90 seconds BOP) 5 C (BOP) Loss of the 1G emergency bus (DG-15 trips open) 5 TS (SRO) TS 3.8.1 6 M (PC & 1A RCP #1 seal fails to 10 over 120 seconds BOP) 6 C (AC) Reactor will not trip, CADM MG set breakers will open (CT) 7 C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 8 M(ALL) TDAFW pump will trip 1 minute after it starts.

8 9 The 1A MDAFW pump begins to experience degraded head 10 1 B MDAFWP will not start when required and cannot be started from the MCB or HSD panel.

Farley May 2011 exam Page 1 of 5

Appendix D Scenario Outline Form ES-D-1 DRAFT SUBMITfAL Terminate event when SGFP flow to SGs accomplished (CT)

L and FRP-H.1 transition criteria reached.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Changes in BLUE Changed the order to ensure the ramp is accomplished.

Changed this since the lB DG trip caused other unexpected problems with the scenario.

Farley May 2011 exam Page 2 of 5

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 7 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

CB D at 175 steps. (Xe is -1795 pcm and building in)

Turnover:

. 20 DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearing replacement. (OCS 6 hrs, ETR 2 hrs)

. Fuel handling is on going in the SFP room with the last fuel bundle being moved.

. Current Risk Assessment is and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Wester n Georgia SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

1 I (AC) PT-444 fails high TS (SRO) TS 3.4.1 DNB (low pressure) 2 I (BOP) R-25A FAILS HIGH and SFP ventilation does not secure, PRF 2 starts TS (SRO) TS 3.3.8 3 3 I (AC) LK-459F fails LOW 4 R (RO & 1A POP #1 seal fails to 7 over 90 seconds 4

BOP) 5 C (BOP) Loss of the 1 G emergency bus (DG-1 5 trips open) 5 TS (SRO) TS 3.8.1 6 M (PC & 1A RCP #1 seal fails to 10 over 120 seconds BOP) 6 C (RO) Reactor will not trip, CRDM MG set breakers will open (CT) 7 C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 8 M(ALL) TDAFW pump will trip 1 minute after it starts.

8 9 The 1A MDAFW pump begins to experience degraded head.

10 1 B MDAFWP will not start when required and cannot be started from the MOB or HSD panel.

Farley May 2011 exam Page 1 of 5

Appendix D Scenario Outline Form ES-D-1 Terminate event when SGFP flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 5

Appendix D Scenario Pre-sets Form ES-D-1 0 0 Tag out 1 B EH pump

CMFmalf I cmshfpb_cp2 0 0 20 DG output breakers racked out

cBK1 0J06_d_cpl cBK2DJO6_d_cpl CMFmaIf / cBK1 DJO6_d_cpl CMFmaIf I cBK2DJO6_d_cpl 0 0 Main turbine fails to auto trip:

MALE / T / MAL-TUR2 Prevent manual trip of main turb.

imf mal-tur24 0 0 Fail RTB from opening in auto

imf cbkrxtrp_cc6 open imf cbkrxtrp_cc5 open 0 0 1 B DG fails to auto start

set jdgblkl b = true 8 0 lb mdafw breaker will not close

imf cafpolb_d_cr5 8 0 Trip TDAFW pump 1 minute after start Trigger 1 VLVS/mal-fwmlc/ 1 mm delay/Trigger 1 8 0 1 A MDAFW develops degraded head when SI occurs Trigger 2 imf NAFP01A-D_th (2 0) 100 60 7 0 1A MSIVs will not close on auto closure

imf crsh00la_cc5 open imf cmsh0O2a_d_cc5 open 1 B MSIVs will not close on auto closure imf crshoolb_cc5 open imf cmsho02b_d_cc5 open 1C MSIVs will not close on auto closure imf crsh00l c_cc5 open imf cmsho02c_dcc5 open Triggers and Commands 8 0 Event Trigger 1 monitors start of TDAEW:

Trgset 1 jtdafwp 8 0 Event Trigger 2 Auto Start (AMPS > 70):

Trgset 2 yAFPO1 B> 70 Farley May 2011 exam Page 3 of 5

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

Turnover:

2C DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Fuel handling is on going in the SEP room with the last fuel bundle being moved.

Current Risk Assessment is and projected is

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 PT-444 fails high.

Verifiable actions: AOP-1 00, take manual control of PORV (close), close spray valves and manually control pressure. DNB TS 3.4.1 Event 2 R-25A FAILS HIGH - SEP ventilation does not secure, PRF starts. TS 3.3.8 Verifiable actions: Manual isolation of dampers is to ensure SFP area is isolated properly.

Event 3 LK-459F fails LOW Verifiable actions: RO will take manual control of charging and adjust seal injection flows.

Due to the failure letdown could be secured and then placed back on service.

Event 4 1A RCP #1 seal fails to 7 over 90 seconds Verifiable actions: Ramp unit off line using rod control and boron Event 5 Loss of the 1G emergency bus (DG-15 trips is opened due to tagging order error) and 1 B DG does not auto start. TS 3.8.1 on DG (There will have to be cues to show there are no electrical faults on the 1 B SU Xfmr and no visual problems with the 1 B DG)

Verifiable actions: nO will start 1A CHG Pump; BOP will close M0V517 and start the lB DG per attachment 6.

Event 6 1A RCP #1 seal fails to 10 over 120 seconds Verifiable actions: RO will trip the reactor; BOP will secure 1A RCP and shut HV81 41 A.

Event 7 Reactor will not trip, CRDM MG set breakers will open (CT)

Main Turbine will not trip automatically or manually, Manual Fast action will be used to close GVs (CT)

Event 8 TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW pump begins to experience degraded head.

1 B MDAFWP will not be available (cannot be started in auto or manually).

Establish SGFP flow to the SGs. (CT)

Terminate event when SGFP flow to SGs accomplished and ERP-H.1 transition criteria reached.

AOP-1 00/ ARP/ AOP-5.0/ AOP-4.1/ EEP-0/ FRP-H. 1 Farley May 2011 exam Page 4 of 5

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Manual Rx trip vs CRDM trip Manipulation of CRDM MG Set Breaker hand switches when conditions require a Reactor trip. Negative reactivity must be inserted within 6 minutes of the start of the event with MEW in service and > 40% power. (PRA NR:27) (WOG CT E A)

Both CRDM MG Set Supply breakers open.

2. Eailure of the turbine to trip. The team should: (WOG CT E 0) -

Close main turbine GVs prior to SGs boiling dry.

3. Heat sink or feed and bleed Establish feedwater flow into at least one SG before feed and bleed is required (2 SG is < 12% WR level). (PRA NR:4) (WOG CT ER-H.1

- - - A)

Verify flow to A, B, or C S/G using A or B SGFP.

SCENARIO The team should be able to:

OBJECTIVE!

Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARP5, AOP-100, AOP-5.0, AOP-4.1 and AOP-13 and Tech Specs

Respond to a RCP seal failure and then a Loss of Eeed event when the reactor trips.

The crew will have to establish feed water flow to the SGs with the SGFPs pumps and transition to the appropriate procedure.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after EOP entry (12) 5

3. Abnormal events (24) 5

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 0

6. EQP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley May 2011 exam Page 5 of 5

Scenario #7 FA2O1 1301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #7 Validation time: 100 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approva: Gary Ohmstede Date: 2-8-2011 NRC Chief Examiner Ron AieIIo Date:

SOUTHERN COMPANY

Appendix D Scenario #7 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 7 Op-Test No.: 2011 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

CB D at 175 steps. (Xe is -1795 pcm and building in)

Turnover:

. 2C DG T/O for governor work. (DOS 2 days, ETR 4 hrs)

. 1 B EHC pump TIC for motor bearing replacement. (005 6 hrs, ETR 2 hrs)

. Fuel handling is on going in the SFP room with the last fuel bundle being moved.

. Current Risk Assessment is and projected is k3R,

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Maif. Event Type* Event Description No. No.

1 I (RO) PT-444 fails high 1

TS (SRO) TS 3.4.1 DNB (low pressure) 2 I (BOP) R-25A FAILS HIGH and SFP ventilation does not secure, PRF 2 starts TS (SRO) TS 3.3.8 3 3 I (RO) LK-459F fails LOW 4 R (RD & 1A RCP #1 seal fails to 7 over 90 seconds BOP) 5 C (BOP) Loss of the 1 G emergency bus (DG-1 5 trips open) 5 TS (SRO) TS 3.8.1 M (RD & 1A RCP #1 seal fails to 10 over 120 seconds 6

BOP) 6 C (RO) Reactor will not trip, CRDM MG set breakers will open (CT) 7 C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 8 M(ALL) TDAFW pump will trip 1 minute after it starts.

9 The 1A MDAFW pump begins to experience degraded head.

8 10 1 B MDAFWP will not start when required and cannot be started from the MCB or HSD panel.

Farley May 2011 exam Page 2 of 14

Appendix D Scenario #7 Outline Form ES-D-1 Terminate event when SGFP flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

(N)orma, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 3 of 14

Appendix D Scenario 7 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 IC-21 7, 72% RTP, MOL, 909 ppm, A Train 0/S A Train CB D 175 steps (Xe is -1795 pcm and building in)

Base IC-56 RUN RUN simulator 0 0 Generic setup:

bat generic_setup_HLT.txt 0 0 Quick setup (all items with are included):

bat 201 1 nrcexam_07.txt 1 B DG fails to auto start: Part of setup file.

EXPERT / SET JDGBLK1B = T Check this= TRUE so lB DG will not start PRESETS 0 0 Tag out lB EH pump CMFmalf I_cmshfpb_cp2 0 0 2C DG output breakers racked out

cBK1 DJO6_d_cpl cBK2DJO6_d_cpl CMFmalf / cBK1 DJO6_d_cpl CMFmalf I_cBK2DJO6_d_cpl 0 0 Main turbine fails to auto trip:

MALE I T /_MAL-TUR2 Prevent manual trip of main turb.

imf_mal-tur24 0 0 Eail RTB from opening in auto

imf cbkrxtrp_cc6 open imf_cbkrxtrp_cc5_open 0 0 1 B DG fails to auto start

set_jdgblkl b_=_true 8 0 1 B mdafw breaker will not close

imf_cafpolb_d_cr5 8 0 Trip TDAFW pump 1 minute after start Trigger 1 VLVS_I_mal-fwml cI_1_mm__delay I_Trigger_1 8 0 1A MDAFW develops degraded head when SI occurs Trigger 2 imf_NAFPO1A-D_th_(2_0)_100_60 Farley May 2011 exam Page 4 of 14

Appendix D Scenario 7 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 7 0 1A MSIVs will not close on auto closure

imf crshOola_cc5 open imf cmsho02a_d_cc5 open 1 B MSIVs will not close on auto closure imf crsho0l b_cc5 open imf cmsh002b_d_cc5 open 1C MSIVs will not close on auto closure imf crsh00lc_cc5 open imf cmshoo2c_d_cc5 open Triggers_and_Commands 8 0 Event Trigger 1 monitors start of TDAFW:

Trgset 1 jtdafwp 8 0 Event Trigger 2 Auto Start (AMPS > 70):

Trgset 2 yAFPO1 B> 70 Farley May 2011 exam Page 5 of 14

Appendix D Scenario 7 Simulator setup Form ESD-1 MCB setup Place 1 B EH pump HS to STOP and HOLD Tag on HS 1 HOLD tag HS to STOP 2C DG Mode selector switch Place in Mode 3 Place HOLD Taci 2C DG MSS 1 HOLD TAG Place HOLD Taci on 2C DG output breakers 2 HOLD TAGS DEH Clear DEH alarms Select POWER OPS PRIMARY on MCB monitor IPC Acknowledcje computer alarms Delete R-25A on plant computer. Use IPC operation from Delete R-25A SIM BOOTH Workstation.doc to delete the point from the plant computer.

IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared Provide a marked up copy of UOP-3.1 version 109 UOP-3.1 copy through step 5.18 FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 6 of 14

Appendix D Scenario 7 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn PT-444 fails high Imf pt444 2500 30 NRC R-25A FAILS HIGH and SFP ventilation does not secure, CUE PRF starts lmffh5failon 2 Do BOTH buttons to Start PRF imf cmi3365a_d_cc4 closed imf cmi3366a_d_cc4 closed LK-459F tails LOW Imflk459F-D045 1A RCP #1 seal fails to 7 over 90 seconds 4 MAL/MAL-CVC27A/5/60 sec ramp Loss of the 1 G emergency bus (DG-1 5 trips open) 5 B train LOSP occurs on the loss of 1G 4160V Bus CMFmalf I cBK1 DG1 5_d_co2 Farley May 2011 exam Page 7 of 14

Appendix D Scenario 7 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Failure below will NOT be used if the Reactor is tripped in Event 5 When att 6 is 1A RCP #1 seal fails to 10 over 120 seconds complete of AOP- MAL / MAL-CVC27A /7/60 sec ramp 5.0 6

DA5 comes into alarm here to simulate #2 seal failure.

preset Reactor will not trip, Reactor will trip manually with handswitch 7

Main Turbine will not trip automatically or manually, Secure DEH pumps to close GVs preset TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW pump begins to experience degraded 8

head.

1 B MDAFW PUMP will NOT START.

Terminate event when SGFP flow to SGs accomplished and FRP-H.1 transition criteria reached.

End of Exam

_-J HORNS OFF i

FF,L2 simulator Stop data collection for Simview file sv DataCollection.uvl Export data file with the to name of NRC examOl Ensure data file created.

grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Restore R-25A on plant computer after all scenarios are run Use IPC operation from SIM BOOTH Workstation.doc to restore the plant computer point to normal.

Farley May 2011 exam Page 8 of 14

Appendix D Scenario 7 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 WHEN REQUESTED MAINTENANCE PERSONNEL: When requested to place jumpers to defeat FW isolation.

REMOTE / N21 / LOA-CFWO47 / installed After five minutes, l&C reports:

Jumpers are installed per the attachment in FRP-H.1 8 5 minutes after request Open SGFP Bypass Remote / N21 / Ioa-cfwO2l / 1 / 60 seconds 8 5 minutes after request: Close SGFP minif low isolation valves Remote / N21 / loa-cfwol 5 / 0 / 30 seconds Remote / N21 / Ioa-cfw0l 6/ 0 / 30 seconds Farley May 2011 exam Page 9 of 14

Appendix D Scenario 7 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 8 2 minutes after request. Open breakers for MOV-3232A/B/C Then when asked open each breaker QUICKLY CMFremote / cMF3232A_d_cdl / open CMFremote/cMF3232B_d_cdl I open CMFremote / cMF3232C_d_cdl I open Farley May 2011 exam Page 10 of 14

Appendix D Scenario 7 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

1 WHEN REQUESTED SSS-plant, SM and Dispatcher:

Recognize and repeat back PT444 failure, CR in the cue and that type of communications.

2 WHEN REQUESTED Unit 2 Unit Operator:

R-25A is in high alarm.

R-25A is pegged high with the RED high light LIT.

R-25B is reading normal mid range scale.

WHEN REQUESTED SSS-plant, SM and Dispatcher:

Recognize and repeat back RE25 failure, CR in the cue and that type of communications.

3 WHEN REQUESTED SM! DISPATCHER:

ACKNOLWEDGE failure and CR that will be written and in the queue.

4 IF REQUESTED Rover:

RCP seal injection filter DP is 3.8 psid.

5 IF/WHEN REQUESTED ROVER:

DG-15 looks normal. There are no trip flags on the breaker.

DBSO:

Alarm 22, SW LOW FLOW, annunciator is in alarm.

SSS-plant, SM and Dispatcher:

I will write a CR and investigate why DG-15 tripped open Time compression: SM:

When one charging This is the Shift Manager, EM has reported the SU transformer, the pump is started, then 1 B DG and all electrical equipment is fine. Start the 1 B DG and call the SS and say place it the on the 1 G 41 60V bus. I will call to let you know when you can place the 1G 4160V bus on the grid.

Radside SO:

I will check the SFP cooling system on service and swap it per SOP-54.0.

6 IF REQUESTED Radside SO:

RCDT level is rising at a faster rate.

7 NONE REQUIRED Farley May 2011 exam Page 11 of 14

Appendix D Scenario 7 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

8 IF/WHEN REQUESTED ROVER:

IA MDAFW pump appears to be running but its discharge pressure is very low.

1 B MDAFW pump has no obvious problem TDAFWP trip throttle valve linkage is broke in half and cannot be repaired.

SM report: I will classify the event.

Dispatcher: 5 minutes after requested report to the SS that jumpers are installed per Attachment 1 of FRP-H.1.

TBSO:

I will open the SGFP BYPASS VALVE I will open the SGFP miniflow valves 5 minutes after asked report the valves above are open.

Farley May 2011 exam Page 12 of 14

Scenario 7 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

Turnover:

2C DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Fuel handling is on going in the SEP room with the last fuel bundle being moved.

Current Risk Assessment is and projected is

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 PT-444 fails high.

Verifiable actions: AOP-1 00, take manual control of PORV (close), close spray valves and manually control pressure. DNB TS 3.4.1 Event 2 R-25A FAILS HIGH - SFP ventilation does not secure, PRF starts. TS 3.3.8 Verifiable actions: Manual isolation of dampers is to ensure SEP area is isolated properly.

Event 3 LK-459F fails LOW Verifiable actions: RO will take manual control of charging and adjust seal injection flows.

Due to the failure letdown could be secured and then placed back on service.

Event 4 1A RCP #1 seal fails to 7 over 90 seconds Verifiable actions: Ramp unit off line using rod control and boron Event 5 Loss of the 1 G emergency bus (DG-15 trips is opened due to tagging order error) and 1 B DG does not auto start. TS 3.8.1 on DG (There will have to be cues to show there are no electrical faults on the 1 B SU Xfmr and no visual problems with the 1 B DG)

Verifiable actions: RO will start 1 A CHG Pump; BOP will close MOV51 7 and start the 1 B DG per attachment 6.

Event 6 1A RCP #1 seal fails to 10 over 120 seconds Verifiable actions: RO will trip the reactor; BOP will secure 1A RCP and shut HV8141A.

Event 7 Reactor will not trip, CRDM MG set breakers will open (CT)

Main Turbine will not trip automatically or manually, Manual Fast action will be used to close GVs (CT)

Event 8 TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW pump begins to experience degraded head.

1 B MDAFWP will not be available (cannot be started in auto or manually).

Establish SGFP flow to the SGs. (CT)

Terminate event when SGFP flow to SGs accomplished and FRP-H.1 transition criteria reached.

AOP-1 001 ARPI AOP-5.0/ AOP-4.1/ EEP-0/ FRP-H.1 Farley May 2011 exam Page 13 of 14

Scenario 7 Critical Task sheet Appendix D Form ES-D-1 et CRITICAL TASK SHEET

1. Manual Rx trip vs CRDM trip Manipulation of CRDM MG Set Breaker hand switches when conditions require a Reactor trip. Negative reactivity must be inserted within 6 minutes of the start of the event with MEW in service and > 40% power. (PRA NR:27) (WOG CT E A)

Both CRDM MG Set Supply breakers open.

2. Failure of the turbine to trip. The team should: (WOG CT E 0) -

Close main turbine GVs prior to SGs boiling dry.

3. Heat sink or feed and bleed Establish feedwater flow into at least one SG before feed and bleed is required (2 SG is < 12% WR level). (PRA NR:4) (WOG CT ER-H.1

- - - A)

Verify flow to A, B, or C S/G using A or B SGFP.

SCENARIO The team should be able to:

OBJECTIVE/

Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARP5, AOP-100, AOP-5.0, AOP-4.1 and AOP-13 and Tech Specs

Respond to a RCP seal failure and then a Loss of Feed event when the reactor trips.

The crew will have to establish feed water flow to the SGs with the SGFPs pumps and transition to the appropriate procedure.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after EOP entry (12) 5

3. Abnormal events (24) 5

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 0

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley May 2011 exam Page 14 of 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 1 Page 1 of 28 Event

Description:

PT-444 fails HIGH PT-444 fails HIGH. The PORV closes in manual, Przr pressure control will be in manual.

Indications Available:

Annunciators: Recognize indications of PT-444 failing HIGH:

- PRZR PORV TEMP HI (HA5) - PK-444A demand

- PRZR SAFETY VLV TEMP HI (HA4) - PORV 444B open

- REL VLV 444B\445A OPEN (HE1) - P1s 455;456;457, RCS Press

- PRZR PRESS RELVLV 445A OR BU HTRS - Pressurizer B/U heaters energizing ON (HD1) - Tl-463 PORV Tailpiece temps t

- PRZR PRESS HI-LO (HC1) - Tl-465; Tl-467; Tl-469 Code Safety Tailpiece temps I Time Pos. Expected Actions/Behavior I Comments I OP-100 ver 100, Instrumentation Malfunction, section 1.1 SAC Direct entry into AC P-i 00 RO (step 1) Take manual control of the Steps 1 and 2 are ICAs following equipment as necessary:

- PORV 444B

- ALL Pzr heaters

- PK-444C & D

- PK-444A (step 2) IF pressurizer pressure is

Spray valves verified decreasing due to a mechanically stuck functioning properly (closed) open spray valve PCV444C or PCV444D No actions required RO (step 3) If the PORV is open then close the PORV 444B will close with the PORV when RCS pressure is < 2310 psig. handswitch RO (step 4) IF an alarm was caused by an CONTROL instrument (PT-4441445) CR component failure, THEN perform the following as required to restore RCS pressure to desired value.

- Take manual control of PORVs, Block valves, Pressurizer heaters and spray.

SAC (step 5) Determine NO protection instrument failure occurred.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 1 Page 2 of 28 Event

Description:

PT-444 fails HIGH Time Pos. Expected Actions/Behavior Comments RO (step 6) References required Technical Specifications:

3.4.1 for DNBR limits RCS pressure < 2209 psig CONDITION A TECHNICAL SPECIFICATION 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit soecified in the COLR SRO CONDITION REQUIRED ACTION COMPLETIO N TIME A. One or A.1 Restore RCS DNB more RCS parameter(s) to within hours DNB limit.

parameters not within limits.

SRO (step 7)

- Notify the Shift Manager SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO (step 10) IF the pressurizer PORVs operated, THEN perform the following:

. Refer to SOP-i .2, Reactor Coolant Pressure Relief System, for cooldown of the PRT

. Refer to SOP-0.0, General Instructions To Operations Personnel, for reporting requirements.

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

2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 2 Page 3 of 28 Event

Description:

R-25A fails HIGH and SFP ventilation does not secure, PRF starts R-25A fails HIGH. The PRF system starts properly but the SFP ventilation system does not secure as per design.

- Fuel movement is in progress in the SEP room

- To determine the status of the rad monitor the control room will call the extra operator! U-2 BOP.

Indications Available:

Annunciators: Indications:

- SEP AREA RE25 A OR B HI RAD (FH5) - A TRN PRF starting Time Pos. Expected Actions/Behavior Comments Annunciator Response Procedure, ARP-1.6 version 67, FH5 SRO Direct entry into FH5. R-25A will be failed HIGH

- Determines the cause of the alarm. NOTE: SEP ventilation did not (Cause will be a failed instrument so that secure so this is a Tech Spec Tech Spec 3.3.8 will be evaluated.) issue.

BOP (step 3 of ARP) Verify HV-3538A is OPEN BOP (step 5 of ARP) Verify automatic actions have occurred. Remains Running o Trips the Fuel Handling Area Supply and Exhaust Fans. Remains OPEN o Closes the Fuel Handling Area Supply and Exhaust Dampers.

o Starts the Penetration Room 1A OR 1A PRF starts lB_Filtration_Units.

3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 2 Page 4 of 28 Event

Description:

R-25A fails HIGH and SFP ventilation does not secure, PRF starts Time Pos. Expected Actions/Behavior Comments BOP (step 5 of ARP) Go to SOP-58.O, 4.8.6 (Verification of automatic actions resulting from SFP AREA RE25 A OR B HI RAD (Annunciator FH5))

NOTE: Technical Specification SR 3.7.12.1 requires both trains of PRF aligned to the spent fuel pool room during movement of irradiated fuel assemblies in the spent fuel pool room. The following step is N/A during fuel movement.

Fuel movement is in progress (step 4.8.6.1) Verify open HV3538A and B (step 4.8.6.2) is not required to be done since a fuel handling accident is not in progress.

(step 4.8.6.3) Verify 1A PRF RECIRC FAN Since A Train PRF is running, and 1A PRF EXH FAN started these steps will be checked.

(step 4.8.6.5) Secure SEP AHU as follows:

- Stop SEP AHU SUPP FAN M002.

- Stop 1A(1B) SEP EXH FAN MOO1A(B)

(step 4.8.6.6) Verify closed the following:

o SEP EXH FAN SUCT DMPR HV3990A o SEP EXH FAN SUCT DMPR HV3990B o SEP AHU DISCH TO SEP HV3991A o SEP AHU DISCH TO SEP, HV3991 B RO (step 6 and 7 of ARP) Announces receipt of Evacuate the SEP area if the the alarm and the affected area. alarm is in high SS (step 8 of ARP) Call SM to evaluate EIP-9.O classifications and to inform SM of the R-25A failure (step 9 of ARP) Call Health Physics to This will be reported as a determine the validity of the alarm. failed instrument SS (step 12 of ARP) Refer to Tech Spec 3.3.8 Penetration Room Filtration (PRF) System Actuation Instrumentation 4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 2 Page 5 of 28 Event

Description:

R-25A fails HIGH and SFP ventilation does not secure, PRF starts Time Pos. Expected Actions/Behavior TECHNICAL SPECIFICATION 3.3.8, Penetration Room I

Filtration Comments (PRF) System Actuation Instrumentation The PRF actuation instrumentation for each Function in Table 3.3.8-1 shall be OPERABLE.

Table 3.3.8-1 (page 1 of 1)

PRFActuation Instrumentation FUNCTION APPLICABLE REQUIRED MODES OR OTHER CHANNELS SPECIFIED CONDITIONS

1. Manual Initiation 1,2,3,4, (a), 2 trains

2. Automatic Actuation 1,2,3,4 2 trains Logic and Actuation Relays

3. SFP Room (a) 2 Radiation Gaseous (R-25A, B)

(a) During movement of irradiated fuel assembiies in the SFP room.

CONDITION REQUIRED COMPLETION ACTION TIME A. One or more A.1 Place one 7 days Functions with PRF train in one channel or Operation.

train inoperable.

SEP Room Radiation Gaseous (R-25A, B)

(a) During movement of irradiated fuel assemblies in the spent fuel pool room. 2 channels required.

Condition A- Place one train PRF in operation in 7 days since only one channel is inoperable.

BASES (B 3.3.8-2) 3. Spent Fuel Pool Room Radiation The LCO specifies two required Gaseous Radiation Monitor channels to ensure that the radiation monitoring instrumentation necessary to initiate the PRF remains OPERABLE. Each monitor will initiate the associated train of PRF and isolate the normal SFP Room ventilation.

SS Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

After Tech Spec analysis and at the discretion of the Lead Examiner move to Event #3.

5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 3 Page 6 of 28 Event

Description:

LK-459F Fails LOW Afterwards, LK-459F will fail low slowly and charging flow will slowly decrease. The crew will enter AOP-100 and take manual control of charging. Charging will remain in manual control the rest of the scenario.

Indications Available:

Annunciators: Recognize indications of LK-459F failing low:

- CHG HDR FLOW HI-LO (EA2) - FT-122, CHG FLOW

- LT-1 12/1 15, VCT level

- LT-459, 460, 461, Actual Przr level .

Time Pos. Expected Actions/Behavior Comments AOP-100 ver 0.0, Instrumentation Malfunction, section 1. is the expected procedure to enter based on a component malfunction. However, if the crew determines this is a CVCS malfunction then AOP-16 would be entered.

SRO Direct entry into AOP-100 or AOP-16.0 AOP-16 steps on page 7 below AOP-100 steos below:

RO (step 1) Check pressurizer level is on or trending to program value RO (step 1 RNO) Take Manual control of FK-122 and raise the demand to approximately 80 100 gpm RO (step 2) Check RCP Seal Injection flows 6-13 gpm

[1 Adjust as necessary using HIK 186 SRO (step 3) Determine if a pressurizer level NOTE: LK-459F has failed transmitter/indicator loop has failed

[] Failed or erroneous reading on Ll459, L1460 or L1461 RO (step 4) Check letdown in service Letdown will still be in service No action for step 5 and 6 SRO (step 7) Notify the Shift Manager 6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 3 Page 7 of 28 Event

Description:

LK-459F Fails LOW Time Pos. Expected Actions/Behavior Comments RO (step 8) WHEN plant conditions permit, NOTE: LK-459F will not be THEN restore components to automatic fixed so Pzr level control will in control as follows: manual the rest of the scenario

[] Restore charging flow control to automatic SRO (step 9) Submit a Condition Report for the failed level channel, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the Condition Report version 16, CVCS Malfunction RO (Step 1) Verify CHG flow adequate to cool Closes HV8149 A, B and C letdown CHG FLOW Fl-122A LTDN HX OUTLET FLOW Fl-i 50 -

REGEN HX OUTLET TEMP TI-i 40 -

BOP (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level (Step 4) Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation

- P1-121 and ammeter for chg pump RO (Step 5) Check charging pump RUNNING YES RO (Step 6) Check Charging flow FK-i22 NOTE: There will be flow controlling in AUTO with flow indicated indicated and FK-122 in AUTO FK- 122 is taken to manual control RNO Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm.

7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 3 Page 8 of 28 Event

Description:

LK-459F Fails LOW Time Pos. Expected Actions/Behavior Comments RO (Step 7) Check DE3 clear YES it letdown was taken off service.

(Step 8) Determine Status of Normal Letdown:

Manually close charging FK-122 Minimize seal injection between 6-13 gpm Direct Chemistry to shutdown the zinc addition system (ZAS) 8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 3 Page 9 of 28 Event

Description:

LK-459F Fails LOW Time Pos. Expected Actions/Behavior Cóinments RO (Step 9) If letdown removed from service, place letdown back in service by:

- Verify all letdown orifice isolation valves CLOSED

- Place LP LTDN PRESS PK 145 on service:

. Place controller in MANUAL

. Adjust demand signal to 50% or Less

- Place LTDN HX OUTLET TEMP TK 144 on service:

- Place controller in AUTO

. Set to maintain temperature 90 to 115°F

- Verify VCT HI LVL DIVERT VLV LCV-1 15A alignment:

. Position indicator VCT light LIT

. Handswitch in AUTO

- Verify LTDN HI TEMP DIVERT VLV TCV1 43:

. DEMIN light LIT

. Handswitch in AUTO

- Verify LTDN LINE CTMT ISO HV8152 OPEN

- Verify LTDN LINE ISO valves -

OPEN LCV459 and LCV46O

- Initiate minimum charging flow:

. Verify CHG FLOW FK 122 in MAN

- Establish minimum charging flow based on orifices to be placed on service:

- Open HV-8149B or C RO IF all backup heaters energized due to NOTE: This is a continuing pressurizer level deviation, THEN verify two action step sets of backup heaters in ON prior to level deviation clearing.

RO Adjust LP LTDN PRESS PK 145 to maintain Set controller to 4.3-7.5 and letdown pressure 260-450 psig PK-145 to AUTO 9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 3 Page 10 of 28 Event

Description:

LK-459F Fails LOW Time Pos. Expected Actions/Behavior Comments RO Control LTDN HX OUTLET TEMP TK 144 to Tl-116 VCT TEMP maintain Letdown temperature 90 to 1 15°F. Tl-143 DIVERT LTDN HX TEMP TI-144 CCW LTDN HX TEMP SRO (Step 10) determine the status of letdown

- Check letdown on service

- Go to procedure and step in effect SRO - Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

- Notify the Shift Manager At the discretion of the Lead Examiner move to Event #4.

10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 4 Page 11 of 28 Event

Description:

1 A RCP #1 seal fails to 7 gpm over 90 seconds 1A RCP seal fails high which will result in ramping the unit off line.

Indications Available:

Annunciators: Indications of 1A RCP #1 seal failure:

- RCP SEAL INJ FLOW LO (DD1) - RCP 1A WR SL FRO154A to 7.26 gpm

- RCP #1 SEAL LKOF FLOW HI (DC2)

Time Pos. Expected Actions/Behavior Comments Annunciator Response Procedure, ARP-1.4 version 50, DC2 AOP-4.1, Abnormal Reactor Coolant Pump Seal Leakage, version 6 SRO Direct ARP entry DC2 RO (ARP DC2 step 1) Compare and determine if an instrument failure has occurred SRO Direct entry into AOP-4.1 RO (step 1) Verify at least one method of RCP seal cooling to all RCPs in progress

- Check Seal injection flow

- Check CCW flow to Thermal Barrier Heat_exchanger RO (step 2) Check #1 seal leakoff flow less than NO> 5 gpm 5 gpm.

RO (step 4) Check #1 seal leakoff GREATER NOTE: this is a continuing than 6 gpm. action step RO (step 5) Check #1 seal leakoff LESS than 8 NOTE: this is a continuing gpm action step RO (step 6) CHECK #2 SEAL LKOF HI NOTE: this is a continuing Annunciator (DA5, DB5 or DC5) for affected action step RCP CLEAR.

11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 4 Page 12 of 28 Event

Description:

1A RCP #1 seal fails to 7 gpm over 90 seconds Time Pos. Expected Actions/Behavior Comments SRO (step 7) Monitor RCDT level increase to NOTE: this is a continuing approximate #2 SEAL LEAKOFF rate, action step while continuing with this procedure.

- Check the combination of #1 SEAL LEAKOFF AND #2 SEAL LEAKOFF remains less than 8 gpm.

BOP (step 8) CHECK RCP lower seal water NOTE: this is a continuing bearing and seal water outlet temperatures action step stabilizes less than 225°F.

RO (step 9) Perform a controlled shutdown of the unit lAW UOP-3.1 concurrent with the remainder of this procedure.

RO (step 9.1) Maintain GREATER than 9 gpm seal injection flow to the affected RCP while the pump is running.

SRO (step 9.2) WHEN the reactor is shutdown, THEN STOP the affected RCP(s).

BOP (step 9.2.1) IF 1A OR lB RCP is secured, THEN close the pressurizer spray valve for the affected RCP.

[jPK444Cf0r1ARCP

[] PK444D for lB RCP BOP (step 9.2.2) WHEN the RCP has come to a complete stop as indicated by minimum RCS flow in the affected loop, THEN close the appropriate RCP SEAL LEAKOFF VALVE.

[1 Q1E21HV8141A 12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 4 Page 13 of 28 Event

Description:

1A RCP #1 seal tails to 7 gpm over 90 seconds Time Pos. Expected Actions/Behavior Comments BOP (step 9.2.3) WHEN affected RCP has been removed from service, THEN refer to FNP-1 -

AOP-4.0, LOSS OF REACTOR COOLANT FLOW.

Ramp lAW UOP-3.1 below.

S RO/ At step 8.5 the following note explains Flux is maintained +/- 5% from RO how flux should be controlled: the target value NOTE: In the following step it is desirable to maintain axial flux difference within +/- 5%

from the target value to help ensure axial flux does not exceed limits specified in the COLR Figure 3. During transients maintaining axial flux difference within the +/- 5% of the target value maynot be possible. For planned load reductions Engineering Support should provide a ramp strategy to maintain axial flux difference within the limits of COLR Figure 3.

BOP Begin lowering turbine load to 40 MW using NOTE: since the ramp rate will the appropriate DEH controls be 2 MW/mm, the BOP will

. Ensure load rate increase is within have to enter the desired rate required limitations, into DEH either before or after

. Verify the HOLD light is LIT. the start of the ramp.

. Depress the GO pushbutton and ensure the GO light is LIT.

. Ensure the Main Turbine starts to ramp down, GVs start to close.

RD Verify rods are in AUTO or Manual and maintaining Tavg close to Tref.

13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 4 Page 14 of 28 Event

Description:

1A RCP #1 seal fails to 7 gpm over 90 seconds Ti me Pos. Expected Actions/Behavior Comments RO (Step 1 .0) Borating per SOP-2.3 appendix B Version 56

Set the boric acid integrator to the desired quantity NOTE: A continuous boration

. Adjust LTDN TO VCT FLOW LK 112 is allowed by appendix C setpoint as desired which maintains the BA

. M/U mode selector to STOP system lined up and the RO

. MKUP MODE SEL SWITCH to BOR will take the MSS to START

. MKUP MODE CONT SWITCH to START. each time a boration is (Step 1 .6) Verify proper boration operation by required.

observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B opens.

BORIC ACID TO BLENDER FCV113A opens.

Boric acid flow is displayed on Fl-113 MAKEUP FLOW TO CHGNCT.

RO (Step 1 .7) Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR FCV1 13B closes.

BORIC ACID TO BLENDER FCV113A closes.

When the ramp is initiated and at the discretion of the Lead Examiner move to Event #6.

14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 15 of 28 Event

Description:

Loss of 10 4160V bus; AOP-5.O entry 1G 4160V emergency bus will be de-energized at power. The lB DG will not auto start. The lB DG can be manually started to re-energize the 1G bus. TS 3.8.1 will apply.

Indications Available:

Annunciators: Recognize indications of a LOSP on B Train

- 1G, 1J OR 1 L 4KV BUS BKR AUTO TRIP - Loss of running equipment. Since A Train (VE1) is on service the 1A chg pump will have to

- Many other alarms will come in and clear be started to regain charging ability and pzr level control Time Pos. Expected Actions/Behavior Comments SRO Direct entry into the ARP VE1, then direct entry to AOP-5.0, Loss of A or B Train Electrical Power AOP-5.0, Loss of A or B Train Electrical Power, version 27 BOP (step 1) Verify at LEAST one Train of 41 60V YES emergency busses energized o A train (1 F 4160 V bus) power available light lit o B Train (1G 4160V bus) power available light lit Check 1 B Diesel Generator started. NO see page 13 for DG start per attachment 6 Dispatch personnel to investigate the 1 B DG start failure RNO column Perform the following while continuing with Call to DB SO this procedure at step 5.

BOP (step 2.2 RNO) Isolate SW to the Turbine Bldg on the affected train

- Close MOV-517 on MCB BOP (step 2.3 RNO) Determine cause of the start NOTE: this is a continuing failure, action step WHEN cause of start failure is corrected, THEN start the 1 B Diesel Generator per see page 13 for Attachment 6 ATTACHMENT 6 actions 15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 16 of 28 Event

Description:

Loss of 1G 4160V bus; AOP-5.O entry Time Pos. Expected Actions/Behavior Comments NOTE: the shift manager will be called and the communications sheet will have the Crew place the lB DG on the 1 G 41 60V bus and not align the bus to the grid.

BOP (step 5) IF not required, THEN stop any running MDAFW pump o Momentarily place MDAFW FCV 3227 RESETATRNORBTRN switches to the reset position. Verify 1 B MDAFW Pump amps o Stop 1 B MDAFW Pump at 0 on ll3305A or B.

BOP (step 6) Check SW available in unaffected train o Two SW Pumps running o SW pressure greater than 60 psig BOP (step 7) Verify at least one CCW PUMP in the unaffected train STARTED.

RO (step 9) Verify at least one CHG PUMP in the CUE: when the charging pump unaffected train STARTED.

- is started the team will be directed to start the lB DG and place it on the 1G 4160V bus.

g on BOP (step 10) Check ON SERVICE CCW train -

operating.

Checks flows for running CCW pumps and Hxs SRO (step 14) Maintain plant stable per applicable UOP-3.1 due to being in Mode UOP and evaluate existing plant conditions. 1 > 25% power 16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 17 of 28 Event

Description:

Loss of 1G 4160V bus; AOP-5.O entry Time Pos. Expected Actions!Behavior Comments SRO (step 14) Apply appropriate Technical Condition A applies since the Specification. TS 3.8.1 Condition A and B offsite power is not available to Perform SR 3.8.1 .1 for required OPERABLE one bus since one SU breaker offsite circuit w/l 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and every 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is open.

after. Initiate performance of FNP STP-27.1, AC SOURCE VERIFICATION to 1 B DG is inoperable since it monitor AC electrical availability, did not auto start as required AND by the LOSP signal Declare required feature(s) supported by the inoperable DG set inoperable when its required redundant feature(s) is inoperable.

TECHNICAL SPECIFICATION 3.8.1, AC SourcesOperating The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1 E AC Electrical Power Distribution System; and

b. Two diesel generator (DG) sets capable of supplying the onsite Class 1 E power distribution_subsystem(s);

CONDITION REQUIRED ACTION COMPLETIO N TIME A. One A.1 Perform SR 3.8.1.1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months required for required AND offsite circuit OPERABLE once per 8 inoperable. offsite circuit. hours Thereafter AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months A.2 Declare required from feature(s) with no discovery of offsite power available no offsite inoperable when its power to one redundant required train conc feature(s) is with mop of inoperable. redundant required feature(s)

AND 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months A.3 Restore required AND offsite 13 days from circuit to discovery of failure to meet LCO 17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 18 of 28 Event Descnption: Loss of 1G 4160V bus; AOP-5.O entry Time Pos. Expected Actions/Behavior Comments CONDITION REQUIRED ACTION COMPLETIO N TIME B. One DG NOTE set LCO 3.O.4c is inoperable. applicable when only one of the three DGs is inoperable. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND B.1 Perform SR 3.8.1.1 Once per 8 for the required offsite hours circuit(s). Thereafter AND B.2 Declare required 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from feature(s) supported by discovery of the inoperable DG set inoperable when its Condition B concurrent required redundant feature(s) is with inoperable. inoperability AND of redundant B.3.1 Determine required OPERABLE feature(s)

DG set is not inoperable 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months due to common cause failure.

BOP (step 15) Verify all RCP busses -

ENERGIZED. YES 1A, lB and 1C416Ov Bus YES iDand 1E416Ov bus BOP (step 16) Verify the following on the unaffected Train. (A Train) o LCCsG,H,A,D o MCCSK,A,F,S,U BOP (step 17) Check SEP in service call Radside SO (Step 18) Check 125V DC battery loads less than:

o A Train 250 amps o B_Train 300_amps 18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 19 of 28 Event

Description:

Loss of 1G 4160V bus; AOP-5.O entry Time Pos. Expected ActionslBehavior Comments SRO (step 19) Minimize DC loads in the affected train o Direct DC loads reduced per the attachment 2 and direct EM to estimate remaining RO (step 20) Verify DRPI ENERGIZED SRO (step 21) Initiate performance of FNP-1-STP-27.1, AC SOURCE VERIFICATION to monitor AC electrical availability.

RO (step 22) Secure non required equipment Secures 1 chg pump o Stop any non required CHG PUMP.

o IF off service CCW train NOT required, THEN stop CCW PUMP in off service train.

SRO (step 24) If off-site power available then If starting the 1 B DG per perform the following: attachment 6 see below:

BOP (step 24.1) 24.1 Check any fault condition This step may be entered from clear. step 5 above. Notice it does (STEP 24.2) Verify closed breaker DF13. (1 F not align the grid to the bus but 4160 V bus tie to 1H 4160 V bus) does parallel and then secure the running DGs. This (STEP 24.3) Verify closed breaker DG13 (1G procedure assumes the DGs 4160 V bus tie to 1J 4160 V bus) start as required.

(STEP 24.4) Parallel and secure running SOP-36.2 version 24 can be diesel generators using FNP-0-SOP-38.0, used to energize the dead bus DIESEL GENERATORS. from the grid.

Attachment 6, Restoring 1 G 41 60V )US BOP (step 1) Verify no faults on 4160 V 1G OR 1L buses.

19

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 20 of 28 Event

Description:

Loss of 1 G 41 60V bus; AOP-5.O entry Time Pos. Expected ActionslBehavior Comments (step 2) Verify the load shed- check the following breakers open:

[] SU TR 1A BKR DG-01-1

[]SU TR 1BBKR DG-15-1

[] 1C BATT CHARGER B TRN BKR EE-06-1

[] 1 B BATT CHARGER BKR EE-05-1

[1 1 B CCW PUMP BKR DG-05-1

[1 1A CCW PUMP BKR DG-04-1

[] 1C SW PUMP BKR DL-05-1

[1 1D SW PUMP BKR DL-03-1

[] 1 E SW PUMP BKR DL-04-1

[1 #4 RW PUMP BKR DJ-03-1

[1 #5 RW PUMP BKR DJ-04-1

[1 1A CRDM CLG FAN BKR EE-13-1

[1 1BCS PUMP BKR DG-11-1

[1 lB RHR PUMP BKR DG-09-1

[1 1 B CHG PUMP B TRN BKR DG-07-1

[1 1C CHG PUMP BKR DG-06-1

[1 lB MDAFWP BKR DG-10-1 BOP (step 2.2) Start 1 B diesel generator

- Start diesel generator from EPB in Mode 2 using START pushbutton.

(step 2.4)

- Check 1 B DG output breaker DG-08-1 closed

- Verify diesel generator frequency 59-61 Hz.

- Verify diesel generator voltage 3740-4580 V.

- Verify 4160 V bus power available light lit.

- Verify adequate SW flow.

- Check 1 B DG lube oil temperature annunciator NOT IN ALARM. (155 ft, DG BLDG_local_control_panel) 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 5 Page 21 of 28 Event

Description:

Loss of 1G 4160V bus; AOP-5.O entry Time Pos. Expected Actions/Behavior Cornments (step 2.8) IF 1G 4160 V bus energized, THEN exit this Attachment and go to procedure step 5.

SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO Inform the SM of the failure and Tech Spec entry WHEN ATTACHMENT 6 IS COMPLETE and at the discretion of the Lead Examiner move to Event #5.

Tech specs can be discussed after the scenario is complete to move the scenario along.

21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 6 Page 22 of 28 Event

Description:

1A RCP #1 seal fails to 10 gpm over 90 seconds When the ramp is initiated and 5% power decrease then the seal wilt fail to 10 gpm. This will require a Reactor trip per AOP-4.1.

Indications Available:

Annunciators: Indications of 1A RCP #1 seal failure:

- 1A RCP #2 SEAL LKOF FLOW HI (DA5) - RCP 1AWR SL FRO154A t to> 10 gpm Pos. Expected Actions/Behavior Comments DM comes i n at 0.75 gpm. This in combination with a known seal leakoff of 7.6 gpm would put the total leakoff >8 gpm.

SRO Directs AOP-4.1 CAS implemented.

RO (step 5) Check #1 seal leakoff LESS than 8 NOTE: this is a continuing gpm action step (step 5.1 RNO) Shutdown the 1A RCP as RO follows:

- Manually Trip the reactor and go to EEP-0 SRO (step 5.1) WHEN the reactor is shutdown, THEN STOP the 1A RCP BOP (step 5.2) when 1A RCP is secured, THEN close the pressurizer spray valve for the affected RCP.

[] PK444C for 1A RCP BOP (step 5.3) WHEN the 1A RCP has come to a complete stop as indicated by minimum RCS flow in the affected loop, THEN close the 1A RCP SEAL LEAKOFF VALVE.

[]Q1E21HV8141A 22

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 7 Event # 6 Page 23 of 28 Event

Description:

1A RCP #1 seal fails to 10 gpm over 90 seconds Pos. Expected Actions/Behavior Corn ments BOP (step 5.4) WHEN affected RCP has been removed from service, THEN refer to -AOP 4.0, LOSS OF REACTOR COOLANT FLOW.

Event 7 and 8 will occur automatically.

23

Op Test No.: FA2011301 Scenario # 7 Event # 7 Page 24 of 28 Event

Description:

Loss of all AFW, Transition to FRP-H.1 When the reactor is tripped a safety injection may or may not will occur since the GVs will be closed in Manual Fast action.

Indications Available:

Annunciators: Recognize indications

- Many and various - Safety Injection horn Enter EEP-O, Reactor Trip or Safety Injection, version 38 SRO Reactor trip Direct the reactor trip and enter EEP-0.

RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

Check nuclear power FALLING.

check rod bottom lights LIT. - NOTE: CRITICAL TASK Trip the reactor using the Open CRDM MG set breakers handswitches on the MCB (step 2) Check turbine TRIPPED.

- CRITICAL TASK TSLB2 14-1 thru 4 lit GVs will be closed by manual fast action per EEP (step 3) Check power to 4160 V ESF 0.

busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR B Train (G & L) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 4) Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION IF SI in progress continue

[} ACTUATED status light lit here, if not the transition to

[]MLB-1 1-1 lit ESP-0.1 will occur.

[]MLB-1 11-1 lit Transition to FRP-H.1 will occur when a RED path comes in after approx. 60 seconds.

24

Op Test No.: FA2011301 Scenario # 7 Event # 7 Page 25 of 28 Event

Description:

Loss of all AFW, Transition to FRP-H.1 I I NOTE: The TDAFW pump will trip 1 minute after it starts.

SRO (step 5) Directs continuing into EEP-O at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to do attachment 2.

RO (step 6) Check containment pressure- HAS NOTE: [CA] step REMAINED LESS THAN 27 psig RO (step 7) Announce Unit 1 reactor trip and safety injection.

RO (step 8) Check AFW status. RNQ- Verify all available AFW Check secondary heat sink Available pumps started o Check total AFW flow > 395 gpm - 1A MDAFWP has degraded

[] Ft 3229A head

[] Fl 3229B - 1 B MDAFWP will not start

[] Fl 3229C - TDAFWP trips o Total Flow Fl 3229 - AFW total flow is <395 gpm OR Check any SG NR level > 31% {48%} NOTE: Red path on FRP-H.1 SRO Updates Crew on Transition Requirement to FRP-H.1 and enters FRP-H.1 FRP-H.1, version 27, STEPS BELOW SRQ (step 1) Check secondary heat sink -

REQUIRED.

o Check RCS pressure > any non-faulted SG pressure on PT-402/403 o Check RCS hot leg temperatures>

F on TR 413 0

350 SRO (step 2) Directs monitoring of bleed and feed criteria

- Check at least two SG wide range levels GREATER THAN 12%.

- Check pressurizer pressure < 2235 psig 25

Op Test No.: FA2011301 Scenario # 7 Event # 7 Page 26 of 28 Event

Description:

Loss of all AFW, Transition to FRP-H.1 SRO (step 3) Direct l&C to defeat feedwater NOTE: Calls I&C isolation signal by installing jumpers per ATTACHMENT 1.

BOP (step 4) Check CST level > 5.3 feet and call for makeup to CST as required BOP (step 5) Try to establish AFW flow to at least NOTE: continuing action step one SG.

Verifies blowdown isolated from all SGs RNO: WHEN any feed flow

- Verifies SG blowdown sample valves established AND at least isolated one SG narrow range level

- Recognizes AFW pumps not available greater than 31 %{48%}

THEN go to procedure and

- Check total AFW flow to SGs > 395 gpm step in effect Continue efforts to establish AFW flow.

RO (step 6) Stops all RCPs SRO (step 7) Try to establish main feedwater flow to intact SGs with one SGFP.

BOP (step 7.1) Verify at least one CNDS PUMP started

- Verify Back up cooling is aligned to the NOTE: will call TB SO to verify condensate pumps BOP (step 7.2) Check intact SGs MSIVs open

- HV3369AandBandC

- HV 3370A and B and C (step 7.3) Check all SG pressures > 540 psig (step 7.4) Check Condenser available (step 7.5) Verify EH pumps running (step 7.6) Verify Main Lube oil for SGFPs available BOP (step 7.7) Verify all main feedwater FCVs and bypass valves closed and in manual 26

Op Test No.: FA2011301 Scenario # 7 Event # 7 Page 27 of 28 Event

Description:

Loss of all AFW, Transition to FRP-H.1 BOP (step 7.8) IF SI has NOT actuated since RNO: Reset SI reactor trip, THEN reset FW ISO.

SRO (step 7.9) Check that I&C has defeated feedwater isolation signal by installing jumpers per ATTACHMENT 1.

BOP (step 7.10) Verify Phase A reset BOP (step 7.11) Verify the following service water valves OPEN OR THROTTLED.

- MOV5l5and5l6

- MOV5l4and5l7

- MOV 540 and 542

- M0V543 and 541 BOP (step 7.12) Verify SGFP speed control -

MAN UALLY ADJUSTED TO 0%.

- SK-509A

- SK-509B or C BOP (step 7.13) Latch 1A(1B) SGFP turbine.

(step 7.14) Open 1A(1B) SGFP LOW PRESS. STOP VALVE.

(step 7.15) Open 1A(1B) SGFP HIGH PRESS. STOP VALVE.

BOP (step 7.16) Raise 1A(1B) SGFP to minimum speed.

1A(1B) SGFP

[] INCREASE SPEED depressed

[1 BOILER CONTROL light illuminated (step 7.17) Open 1A(1B) SGFP discharge valve.

SGFP 1A(1B) DISCH VLV

[1 N1N21V5O3A

[1 N1N21V5O3B BOP (step 7.18) Verify all intact SGs main feedwater stop valves OPEN.

- M0V3232A.BandC 27

Op Test No.: FA2011301 Scenario # 7 Event # 7 Page 28 of 28 Event

Description:

Loss of all AFW, Transition to FRP-H.1 BOP (step 7.19) Place 1A(1B) SGFP speed controller in AUTO.

1A(1B) SGFP SPEED CONT

[] 5K 509B

[]SK509C BOP (step 7.20) Adjust master speed controller to raise feedwater discharge header pressure to 50 psi greater than steam header pressure.

FW HDR PRESS

[] P1 508 STM HDR PRESS

[1 PI 464A BOP (step 7.21) Control BYPASS FCVs to supply water to the SGs FK 479, 489, 499 RO (step 7.22) WHEN P-12 light lit, THEN perform the following.

- Block Low STM line pressure SI

- Turn the following handswitches:

STM LINE PRESS SI BLOCK RESET -

[] A TRN to BLOCK

[1 B TRN to BLOCK

- Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[] TRAIN A BLOCKED light lit

[1 TRAIN B BLOCKED liciht lit SRO (step 8) Verify SG levels: Note: continuing action step

- Check WR levels rising CRITICAL TASK OR continue feeding the SGs and

- Check CETCs temperatures falling then transition back to the (step 8.2) Check at least one NR level >31% procedure and step in affect.

Terminate scenario when the transition to ESP-Oi or EEP-O is announced.

28

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2O11-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

Assign ojerating rositions.

Ask for and answer guestions.

Appendix U Turnover sheet Form ES-D-2

[XjUnitl [ ]Unit2 Shift: Date I Off-goingSS j OncomingSS I [ ]N {X]D I Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, 5, D, SW, X on key ring. SS Unit 72% power, continuing a ramp to 100% power, 909 ppm, MOL, 7000 MWD/MTU Status (Xe is -1795 pcm and building in) CB D is at 175 steps.

TAR(ifT ZERo hiy Da. ErY Job Saidv A Train On-Service A Train STPs/Evolutions:

Fuel handling is on going in Protected the SEP room with the last

fuel bundle being moved.

1.0_; 109.1 Noadi.; 63.7; FSP-20,0 Status of Special Testing General Information

1. Ramping up in power.

2. 2C DG TIC for Jacket Water leak repair (COS 2 days, ETR 4 hrs)

3. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

4. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia

5. Current Risk Assessment is and projected is GREEN 6.

7.

8.

9.

Equipment Status 2C DG TIC for Jacket Water 1 B EHC pump is tagged out Maintain VCT gas pressure 25-30 psig leak repair Reactivity Plan Waste Management Status 20 Gallon Dilutions as required to maintain #3 RHT On Service temperature and power.

WGS secured LCO Status 2C DG (Admin)

Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part III: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X J Yes [X I Yes [X] Yes [X]Yes [X]Yes [X] Yes

Appendix D Scenario Outline Form ES-D-1 DRAFT SUBMITTAL Facility: Farley Nuclear Plant Scenario No.: 6 Op-Test No.: FA2OI1-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, viOl, completed thru step step 5.57.

Ready to perform step 5.58. 1209 ppm, MOL; 1A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) 1A OW pump only 0/S.

Turnover:

. 1 B EHC pump TIC for motor bearing replacement. (OCS 6 hrs, ETR 2 hrs)

. FRV bypasses controlling feedwater to the SGs

. Current Risk Assessment is and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

R (RO & Ramp up to 12% power 1

BOP) 1 C (RO) 1 C charging pump high lube oil temperature. Will have to be 2 secured and 1 A or 1 B Chg pump started.

TS (SRO) LCO 3.5.2, admin 13.1.5.

2 I (BOP) 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm until control of SGFP is regained.

3 I (RO) PK-444D will open and can be closed in manual. When the 4 spray valve opens, EA1 1, 1A Pzr Heater breaker, trips open TS (SRO) TS 3.49 5 4 C (BOP) The GSSC EXH fan trips (Loss of Vacuum) and recovered 5 C (BOP) Vacuum continues to drop after initial recovery. Eventual SGFP 6

trip, AOP-1 3 entry to trip the reactor.

6 M (ALL) 1 A SGTR 300 gpm ramped in over 5 minutes 7 C (PC) Block manual and auto Rx trip. Crew must open CRDM MG set 8 breakers to trip the reactor. (CT) 8 Block auto SI. Initiate a SI manually (CT) 9 C (BOP) No AFW pumps start. Start one AFW pump.

10 10 C (BOP) FCV-3227A 1A AFW FCV fails open. Isolate AFW flow (CT)

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 Changes in BLUE Removed two critical tasks. The afw pump start was not a CT due to SG level not dropping low enough to make this a CT, and the depressurization in E-3 is not required and would only lengthen the scenario for no value.

Changed termination point to shorten scenario.

Farley May 2011 exam Page 2 of 6

Appendix D Scenario Outline Form ES-D-1 Facility:

j Farley Nuclear Plant Scenario No.: 6 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SAC RO BOP Initial Conditions: 4% power, UOP-1.2, viOl, completed thru step step 5.57.

Ready to perform step 5.58. 1209 ppm, MOL; 1A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) 1A OW pump only 0/S.

Turnover:

. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

. FRV bypasses controlling feedwater to the SGs

. Current Risk Assessment is (R and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Maif. Event Type* Event Description No. No.

R (AC & Ramp up to 12% power 1

BOP) 1 C (AC) 10 charging pump high lube oil temperature. Will have to be 2 secured and 1A or lB Chg pump started.

TS (SRO) LCO 3.5.2, admin 13.1.5.

2 I (BOP) 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm until control of SGFP is regained.

3 I (RO) PK-444D will open and can be closed in manual. When the 4 spray valve opens, EA1 1, 1 A Pzr Heater breaker, trips open TS (SRO) TS 3.4.9 4 C (BOP) The GSSC EXH fan trips (Loss of Vacuum) and recovered C (BOP) Vacuum continues to drop after initial recovery. Eventual SGFP 6

trip, AOP-1 3 entry to trip the reactor.

6 M (ALL) 1 A SGTR 300 gpm ramped in over 5 minutes 7 C (RO) Block manual and auto Rx trip. Crew must open CRDM MG set 8 breakers to trip the reactor. (CT) 8 Block auto SI. Initiate a SI manually (CT) g 9 C (BOP) No AFW pumps start. Start one AFW pump.

10 10 C (BOP) FCV-3227A 1A AFW FCV fails open. Isolate AFW flow (CT)

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 Terminate scenario when 1A SG flow isolation is complete in EEP-3.O (N)ormal, (R)eacttvity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 6

Appendix D Scenario Pre-sets Form ES-D-1 0 0 RackoutlBEHpump

Cmfmalf I cmshfpb_cp2 0 0 Fail RTB from opening on manual or auto trip

CMFmalf /cBKRXTRP_cc2l / closed CMFmalt / cBKRXTRP_cc22 / closed 0 0 Fail auto SI signals, Manual SI works

CMFmalf / csttyinj_ccl / open CMFmalf I csftyinj_ccl 1 / open 9 0 Prevent TDAFWP auto start

CMFmalf / cMS3235B-ccl I open CMFmalf I cms3235b_cc2 / open CMFmalf I cms3235a_ccl I open CMFmalf I cms3235a_cc2 / open 9 0 Prevent MDAFWP auto start CMFmalf I Cafpola_cr7 CMFmalf / Cafpolb_cr7 5 0 Trip 1A SGFP when condenser pressure > 4.9 psia Trigger 3 imt mal-twml la (30) 10 0 Loss of air to 1A SG MDAFW FCV Trigger 1 CNH / hic3227a-r I 600 sec delay! Trigger 1 4 0 EA1 1 breaker trip and annunciator comes into alarm Trigger 2 Cmf malt! imf cpc2O27c_col (2 0)

Triggers and Commands 8 0 Trigger 1 monitors when HHSI flow is> 100 gpm

trgset 1 fi943> 100 4 0 Trigger 2: monitors PK444D placed in lower

trgset 2 x30I058L 6 0 Trigger 3: monitors condenser pressure

Trgset 3 pr4029b > 4.9 Fancy May 2011 exam Page 3 of 6

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 4% power, MOL, 5,000 MWD, A Train O/S, A Train protected, RCS boron concentration is 1209 ppm. 1A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) 1 A CW pump only 0/s Turnover:

1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is and projected is .

FRV bypasses controlling feedwater to the SGs

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Increase Reactor power to 12% and get ready to roll the Main Turbine.

Verifiable actions: RO will pull rods and BOP will adjust stm dumps to increase reactor power.

Event 2 IC charging pump high lube oil temperature.

Verifiable actions: Will have to be secured and 1A or lB Chg pump started. ARP and SOP-2.1 OR AOP-16 actions here. The LO temperature will be approx. 160°F, which will probably cause a loss of letdown and then subsequent recovery.

TS entry mandatory until the 1 B chg pump is swapped to the other train. LCO 3.5.2, Admin 13.1.5.

The 1C Chg pump will be tripped if temperature is allowed to reach 175°F.

Event 3 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm until control of SGFP is regained.

Verifiable actions: Since the FRV Bypass valves are being used to control Feed flow, this will be a different response. AOP-l00 entry.

Event 4 PK-444D will open and can be closed in manual. When the spray valve opens, EA11, 1A Pzr Heater breaker, trips open TS 3.4.9 Verifiable actions: RO will place PK-444D in manual and close, then ensure all heaters are on.

Event 5 The GSSC EXH fan trips to start this event. ARP will be entered.

Loss of Vacuum will occur due to this failure call to start ALL CT fans.

Verifiable actions: Start 1 B CW pump and the other GSSC EXH fan from the MOB.

AOP-8.0.

Event 6 Vacuum continues to get worse, 1A SGFP Trips Trip the reactor lAW AOP-13.

Event 7 IA SGTR 300 gpm ramped in over 5 minutes with the AUTO SI and AUTO & manual trip blocked.

Event 8 Actuate a manual Rx trip by opening CRDM MG set breakers (CT)

Initiate a manual SI (CT)

Event 9 No AFW pumps start. Start one AFW pump Farley May 2011 exam Page 4 of 6

Appendix D Scenario detailed summary sheet Form ES-D-1 Event 10 FCV-3227A 1 A AFW FCV fails open after 6.667 minutes after the SI occurs. Isolate SGs steam and AFW (CT) 1C chg pump will auto start on the SI. If allowed to run and increase temperature to 175°F, then 1 C chg pump will be tripped. Not critical task since one chg pump will be running on the other train.

Terminate scenario when cooldown determined at step 6.1 in EEP-3.0 UOP-1 .2/ SOP-2.1 or AOP-1 6/ AOP-1 00 or AOP-1 3/ AOP-1 00/ AOP-81 EEP-0/ EEP-3.0 Farley May 2011 exam Page 5 of 6

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Actuate a manual Rx trip prior to SI (WOG CT E-O - - A)

2. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-O - - D)

Transition to any E-3 series procedure

Manually Actuate SI

3. Isolate FCV-3227A 1A AFW FCV and 1A MSIVs in EEP-3.O before a transition to ECP-3.1 occurs. (WOG CT E-3 - - A)

SCENARIO While at 8% power, the team will have to:

OBJECTIVE/OV

Respond to a loss of vacuum and use AOP-8 to correct vacuum ERVIEW: problem.

Respond to several instrument and component problems and respond using the appropriate ARPs, AOP-100 and AOP-13.

Respond to a SGTR and isolate AFW flow and Steam flow from the SG using EEP-3.O.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after EOP entry (12) 4

3. Abnormal events (24) 5

4. Major transients (12)

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 3 Farley May 2011 exam Page 6 of 6

Scenario #6 FA2O1 1301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #6 Validation time: 120 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approval: Gary Ohmstede Date: 2/8/201 1 NRC Chief Examiner Ron AieIIo Date:

SOUTHERN COMPANY

Appendix D Scenario #6 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 6 Op-Test No.: 201 1-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, viOl, completed thru step step 5.57.

Ready to perform step 5.58. 1209 ppm, MDL; 1A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half oftheA, B,Ctowers) 1ACW pumponlyO/S.

Turnover:

. 1 B EHC pump T/C for motor bearing replacement. (DOS 6 hrs, ETR 2 hrs)

. FRV bypasses controlling feedwater to the SGs

. Current Risk Assessment is 4-Ii and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

R (RD & Ramp up to 12% power 1

BOP) 1 C (RO) 1C charging pump high lube oil temperature. Will have to be 2 secured and 1 A or 1 B Chg pump started.

TS (SRO) LCO3.5.2, admin 13.1.5.

2 I (BOP) 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm until control of SGFP is regained.

3 I (RO) PK-444D will open and can be closed in manual. When the 4 spray valve opens, EA1 1, 1 A Pzr Heater breaker, trips open TS (SRO) TS 3A.9 5 4 C (BOP) The GSSC EXH fan trips (Loss of Vacuum) and recovered 5 C (BOP) Vacuum continues to drop after initial recovery. Eventual SGFP 6

trip, AOP-1 3 entry to trip the reactor.

6 M (ALL) 1A SGTR 300 gpm ramped in over 5 minutes 7 C (RO) Block manual and auto Rx trip. Crew must open CRDM MG set 8 breakers to trip the reactor. (CT) 8 Block auto SI. Initiate a SI manually (CT) 9 C (BOP) No AFW pumps start. Start one AFW pump.

10 10 C (BOP) FCV-3227A 1A AFW FCV fails open. Isolate AFW flow (CT)

Farley May 2011 exam Page 2 of 14

Appendix D Scenario #6 Outline Form ES-D-1 Farley May 2011 exam Page 3 of 14

Appendix D Scenario 6 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 IC-216 4% RTP, MOL, A Train 0/S A Train protected 1209 ppm, MOL; 1A SGFP on service. Aux steam from U-2.

Only partial of 2 sets of cooling tower fans will be on service.

(i.e. half of the A, B,C towers) 1A CW pump only 0/S.

Base IC-65 RUN

.1 RUN simulator 0

0 0 Generic setup:

bat generic_setup_H LT.txt r

0 Quick setup (all items with

are included):

bat 201 1 nrcexam_06.txt PRESETS U U Rack out 1 B EH pump Cmfmalf I cmshfpb_cp2 0 0 Fail RTB from opening on manual or auto trip CMFmalf /cBKRXTRP_cc2l / closed CMFmalf I cBKRXTRP_cc22 I closed 0 0 Fail auto SI signals, Manual SI works

CMFmalf / csftyinj_ccl / open CMFmalf / csftyinj_ccl 1 / open 9 0 Prevent TDAFWP auto start CMFmalf/ cMS3235B-ccl / open CMFmalf / cms3235b_cc2 / open CMFmalf / cms3235a_ccl I open CMFmaIf / cms3235a_cc2 / open 9 0 Prevent MDAFWP auto start CMFm alt / CafpOl a_cr7 CMFmalf I Cafpolb_cr7 5 0 Trip 1A SGFP when condenser pressure > 4.9 psia Trigger 3 imf mal-fwml la (3 0) 10 0 Loss of air to 1A SG MDAFW FCV Trigger 1 CNH / h1c3227a-r I 600 sec delay! Trigger 1 4 0 EA1 1 breaker trip and annunciator comes into alarm Trigger 2 Cmf malt! mt cpc2O27c_col (2 0)

Triggers_and_Commands 8 0 Trigger 1 monitors when HHSI flow is> 100 gpm

trgset 1 fi943> 100 Farley May 2011 exam Page 4 of 14

CD CD m D z

-I C OH CD m

cl:cc m acD (DZ

- H C

-33m g g ci J8 H CD D

CD .1aZ D 0 C> a,

- _-o -

t3 -

CD 0

CD Cl)

-!E I 0 CD I -I C I Z 0

m 0)

C

Appendix D Scenario 6 Simulator setup Form ES-D-1 MCB setup Verify 1 B EH pump handswitch in OFF and TAG 1 HOLD tag Verify half of Cooling tower fans Secure top row fans TOP row jul iwi 1Y Verify the 1 B CW pump Take 1 B CW pump to STOP DEH Clear DEH alarms Select POWER OPS PRIMARY on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared Provide a marked up copy of UOP-1 .2 version 101 UOP-1 .2 copy throucih step 5.57 complete and sicined off I

r 4

Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview I sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 sv sim_clock.uvl VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 6 of 14

Appendix D Scenario 6 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1 0 Rampuptol2%power At 10% 1 C charging pump high lube oil temperature. Will have to power be secured and 1 A or 1 B Chg pump started (this takes achieved by closing CCW supply valve V31 OC:

to come in) REMOTE / P17 / LOACCWO59 /0 2

tchspoil(3)

If 1C charging pump L.O. temperature exceeds 175°F, then trip the pump:

CMFmaIf / cCVPO1 C_d_col NRC 1A SGFP controller failure. SGFP speed will decrease CUE to 3200 rpm until control of SGFP is regained.

Cnh / sk5O9B-A 0 240 NRC PK-444D will open and can be closed in manual.

CUE lmfpk444d-a105 When PK444D is taken to manual, EA1 1, 1A Pzr Heater breaker, trips open EA1 1 trips on trigger 2 Farley May 2011 exam Page 7 of 14

Appendix D Scenario 6 Booth Guide Form ES-D-1 The GSSC EXH fan trips (Loss of Vacuum)

Increase cond pressure FIRST using vacuum control button to the right Remote /cond and FW /

loa-cfwO49 500 (0-WHEN vacuum starts to increase, trip the GSSC exh fan 1000%)

using the button below: adjust vacuum on instructor station 5 summary as necessary to maintain value < 3.0 psia CMF MALF/ CTSPO37_CC3 CLOSED 300 is a good value to hold the vacuum steady Pr4029a When the adjust vacuum on GSSC Vacuum continues to drop.

EXH fan is instructor station started REMOTES LOA then put in CFWO49 place remote next event When PSIA is reading 4.95 psia on MCB, then trip 1A value to 1000 6 SGFP if Trigger 3 did not work If crew elects to ramp the unit to <5% power, trip the 1 A SGFP prior to 6% power.

Malf/ f/ imf mal-fwml la Trigger 3 NRC 1A SGTR 300 gpm ramped in over 5 minutes CUE 7 step 1 MaIf I R I imf mal-rcs4A 300 300 ESP-0. 1 zJ preset Block manual and auto Rx trip. Crew must open CRDM 8 MG set breakers to trip the reactor.

Auto SI Blocked g preset No AFW pumps start.

10 preset FCV-3227A 1A AFW FCV fails open.

Terminate scenario when cooldown determined at step 6.1 in EEP-3.0.

End of Exam HORNS OFF Farley May 2011 exam Page 8 of 14

Appendix D Scenario 6 Booth Guide Form ES-D-1 FREEZE simulator Stop data collection for Simview file sv_DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

grpX.txt NOTE: Substitute grpX with grpl, grp2, orgrp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Farley May 2011 exam Page 9 of 14

Appendix D Scenario 6 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 2 minutes after 1 C Chg pump LO Temperature requested:

3 NONE REQUIRED 4 NONE REQUIRED 5 When the GSSC fan Control Vacuum by adjusting loa-cfwO49 to a value that will cause trips vacuum results needed see instructor summary Start Cooling tower fans as directed by control room using XTREMEview. Go to Panel view and click the E 1 located next to the MCB H/S for each switch.

6 NONE REQUIRED 7 NONE REQUIRED 8 3 minutes after being Locally open reactor breakers called initiate action and call CR as the ROVER to tell them the RTBs are open. A TRAIN CMFmalf / cBKRXTRP_cc2 1 / open B Train CMFmalf / cBKRXTRP_cc22 / open 9 IF REQUIRED If 1C charging pump L.O. temperature exceeds 175°F, then trip the pump:

tchspoil(3)

Trip 1C CHG at 175°F FarleyMay 2011 exam Page 10 of 14

Appendix D Scenario 6 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

1 NONE REQUIRED 2 2 minutes after Rad Side SO:

REQUESTED The 1C Charging pump LO temperature reads (look at monitor under local operator actions to read temperature) 3 WHEN REQUESTED TBSO:

SGFP is running at 5500 RPM. I see no other problems 4 WHEN REQUESTED ROVER:

EA1 1 is open. (there are no indications available on this breaker)

DISPATCHER:

Acknowledges when informed that the CR is in the queue.

5 WHEN REQUESTED TB SO: report the following as requested SJAEs look fine

- I see no leaks on the Turbine Deck

- I see no problem in the TB basement

- Aux Stm pressure looks fine with a reading of 175 psig

- Finally if asked: report that the 1 A GSSC exh fan is not running or that no GSSC exh tan is running SOP-28.4 4.1.1.2 Place the 1 B GSSC EXH FAN in service as follows:

Verify open 1 B GSSC EXH FAN suction valve Ni N32V592.

Verify closed 1 A GSSC EXH FAN suction valve Ni N32V593 Throttle open 1 B GSSC EXH FAN discharge valve Ni N32V591 to approximately 30% open.

Verity closed iA GSSC EXH FAN discharge valve Ni N32V574 Have the CR Start the 1 B GSSC fan lAW SOP-28.4 Outside SO:

I will start turning on ALL the Cooling Tower Fans 6 NONE REQUIRED 7 NONE REQUIRED 8 3 minutes after being initiate LOAs and call CR as the ROVER to tell them the RTB5 are requested open 9 NONE REQUIRED iO IF REQUESTED ROVER:

I will close the isolation valve V017D for 3227A Farley May 2011 exam Page 11 of 14

Scenario 6 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 4% power, MOL, 5,000 MWD, A Train OIS, A Train protected, RCS boron concentration is 1209 ppm. 1A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) 1A CW pump only 0/s Turnover:

1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is and projected is kR1.

FRV bypasses controlling feedwater to the SGs

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Increase Reactor power to 12% and get ready to roll the Main Turbine.

Verifiable actions: RO will pull rods and BOP will adjust stm dumps to increase reactor power.

Event 2 1C charging pump high lube oil temperature.

Verifiable actions: Will have to be secured and 1A or 1 B Chg pump started. ARP and SOP-2.1 OR AOP-16 actions here. The LO temperature will be approx. 160°F, which will probably cause a loss of letdown and then subsequent recovery.

TS entry mandatory until the 1 B chg pump is swapped to the other train. LCO 3.5.2, Admin 13.1.5.

The 1C Chg pump will be tripped if temperature is allowed to reach 175°F.

Event 3 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm until control of SGFP is regained.

Verifiable actions: Since the FRV Bypass valves are being used to control Feed flow, this will be a different response. AOP-1 00 entry.

Event 4 PK-444D will open and can be closed in manual. When the spray valve opens, EA11, 1A Pzr Heater breaker, trips open TS 3.4.9 Verifiable actions: RO will place PK-444D in manual and close, then ensure all heaters are on.

Event 5 The GSSC EXH fan trips to start this event. ARP will be entered.

Loss of Vacuum will occur due to this failure call to start ALL CT tans.

Verifiable actions: Start lB CW pump and the other GSSC EXH fan from the MCB.

AOP-8.0.

Event 6 Vacuum continues to get worse, 1A SGFP Trips Trip the reactor lAW AOP-13.

Event 7 1 A SGTR 300 gpm ramped in over 5 minutes with the AUTO SI and AUTO & manual trip blocked.

Event 8 Actuate a manual Rx trip by opening CRDM MG set breakers (CT)

Initiate a manual SI (CT)

Event 9 No AFW pumps start. Start one AFW pump Farley May 2011 exam Page 12 of 14

Scenario 6 detaHed summary Appendix D Form ES-D-1 Event 10 FCV-3227A 1A AFW FCV fails open after 6.667 minutes after the SI occurs. Isolate SGs steam and AFW (CT) 1 C chg pump will auto start on the SI. If allowed to run and increase temperature to 175°F, then 1C chg pump will be tripped. Not critical task since one chg pump will be running on the other train.

Terminate scenario when cooldown determined at step 6.1 in EEP-3.O UOP-1 .2/ SOP-2.1 or AOP-1 6/ AOP-1 00 or AOP-1 3/ AOP-1 00/ AOP-8/ EEP-0/ EEP-3.0 Farley May 2011 exam Page 13 of 14

Scenario 6 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET

1. Actuate a manual Rx trip prior to SI (WOG CT E-O - - A)

2. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOO CT E-O - - D)

Transition to any E-3 series procedure

Manually Actuate SI

3. Isolate FCV-3227A 1A AFW FCV and 1A MSIVs in EEP-3.O before a transition to ECP-3.1 occurs. (WOG CT E-3 - - A)

SCENARIO While at 8% power, the team will have to:

OBJECTIVEIOV

Respond to a loss of vacuum and use AOP-8 to correct vacuum ERVIEW: problem.

Respond to several instrument and component problems and respond using the appropriate ARPs, AOP-100 and AOP-13.

Respond to a SGTR and isolate AFW flow and Steam flow from the SO using EEP-3.O.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after EOP entry (12) 4

3. Abnormal events (24) 5

4. Major transients (12) 1

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 3 Farley May 2011 exam Page 14 of 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 1 Page 1 of 44 Event

Description:

Ramp UP to 12% power.

Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% lAW UOP-1 .2. At 8% the NRC will evaluate going to the next event. This evolution will take approx. 15 -20 minutes Indications Available:

Annunciators: NA Time Pos. Expected Actions/Behavior I Comments UO -1.2, Startup of Unit from Hot Standby to Minimum Load, version 100,step 5.58 RO Begin to increase reactor power to greater than 12% with following controls.

Manual adjustment of control rods Steam dumps in Steam Pressure Control Mode SRO Monitor reactor power and Steam Dump adjustments as reactor power rises BOP Will be reviewing UOP-1 .2 and getting ready to roll the main turbine.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 1 Page 2 of 44 Event

Description:

Ramp UP to 12% power.

Time Pos. Expected Actions/Behavior Comments RO WHEN Nuclear at Power Permissive P-b permissive status light is illuminated (2/4 power ranges greater than 10%), THEN perform the following: {CMT-0003695}

Block the intermediate range reactor trip and overpower rod stop.

Place INTEMEDIATE RANGE BLOCK TRN A to BLOCK.

Place INTEMEDIATE RANGE BLOCK TRN B to BLOCK.

On the Bypass and Permissive Panel verify the following:

The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.

The INTERM RANGE TRAIN B TRIP BLOCKED light illuminated.

Block the power range low setting reactor trip.

Place POWER RANGE BLOCK TRN Ato BLOCK.

Place POWER RANGE BLOCK TRN B to BLOCK.

On the Bypass and Permissive Panel verify the following:

The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.

The POWER RANGE LOW SETTING TRAIN B TRIP BLOCKED light illuminated.

2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 1 Page 3 of 44 Event

Description:

Ramp UP to 12% power.

Time Pos. Expected Actions/Behavior Comments RO Verify that Low Power Trip Block P-7 status light is not illuminated to ensure the unblocking of the following reactor trips.

Pressurizer Low Pressure Pressurizer High Water Level Loss of Flow-Two Loops RO Verify NR-45B is in the desired speed, i.e.,

2 n d speed (2 min/div) OR normal speed. (10 min/div)

SRO Direct qualified EM or OPS personnel to close disconnect switch 915 When 12% power is reached and at the discretion of the Lead Examiner move to event #2.

NOTE: The next event takes 3 minutes to get the first alarm 3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 4 of 44 Event

Description:

1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

The charging pump will be running without CCW. Oil temperatures will rise slowly and the alarm will come in at 140°F. 2 minutes after the alarm comes in the temper ature will be at 160°F. Then 2 minutes later the temperature will be at 170°F. We will trip the pump at 170°F if action is not taken to remove it from service.

Indications Available:

Annunciators: Indications of CHG PUMP LUBE OIL TEMP HI

- CHG PUMP LUBE OIL TEMP HI (EA3) - Annunciator Only Time ( Pos. Expected ActionslBehavior I Comments Annunciator Response Procedure, ARP-1.5, version 54.0, EA3 SOP-2.1, CVCS System Plant Startup and Operation, version 118.0 AOP-16, version 17 SRO Direct entry into the ARP and evaluate securing the 1C charging pump.

RO Call the Radside SO to look at the IC Chg NOTE: A report will be given in pump local temperature indication. approx 2 minutes and will be the actual value from the plant computer.

BOP (step 1) After the report IF local temperature NOTE: The temperature will indication is> 160°F, THEN immediately be >160°F and the 1C chg shutdown the 1C charging pump. pump will be secured per the ARP.

Start another charging pump per SOP-2.1, Since the pump is secured, CVCS Plant Startup And Operation DEl, REGEN HX LTDN FLOW DISCH TEMP HI will come into alarm. It is possible that letdown is secured per that ARP and AOP-16 entered.

4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 5 of 44 Event

Description:

1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

Time Pos. Expected Actions/Behavior Comments RO SOP-2.1 version 118 step 4.7, Starting a Charging Pump or Swapping a Charging Pump When RCS Temp is> 180°F:

(step 4.7.1) Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB (step 4.7.2) Check open miniflow isolation Qi E21 MOV81O9A or B.

(step 4.7.3) Verify Qi E21 MOV81 06, is open.

(step 4.7.4) Verify a 1C or lB CCW pump is running.

(step 4.7.5) Verify FCV-122 and HIK 186 are closed if no other chg pump is running RO (step 4.7.6) Start 1A OR lB Charging pump (step 4.7.7) Observe CHG HDR PRESS indicator P1 121 and motor ammeter to check proper pump operation (step 4.7.8) WHEN charging pump comes up to speed, THEN check auxiliary oil pump stops as indicated by white light JQI being illuminated on MCB.

(step 4.7.9) IF swapping chg pumps, then perform the following:

- Adjust FCV-1 22 to obtain chg flow proper flow

- Place FCV-122 in Auto

- Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP

- STOP the 1C CHG if not already secu red SRO Direct STP-8.0, RCP seal injection leakage NOTE: This will be assigned to test to be performed an extra operator 5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 6 of 44 Event Descnption: 1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

Time Pos. Expected Actions/Behavior Comments AOP-16 actions below:

RO (Step 1) Verify CHG flow adequate to cool RNO- close HV-8149 A, B and letdown C CHG FLOW Fl-122A LTDN HX OUTLET FLOW Fl-i 50 -

REGEN HX OUTLET TEMP TI-i 40 -

BOP (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level (Step 4) Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation

- P1-121 and ammeter for chg pump RO (Step 5) Check charging pump RUNNING RNO- start an available pump as follows:

- Check VCT level and pressure adequate

- Verify LCV-1 15 CIE OPEN OR LCV-1 15 BID OPEN

- Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB

- Check open miniflow isolation MOV81O9A or B and M0V8106, is open

- Verify FCV-122 and HIK 186 are closed

- Verify CCW pump in that train is running

- Start the selected Chg pump

- Adjust Seal injection flows RO (Step 6) Check Charging flow FK-i22 controlling in AUTO with flow indicated (Step 7) Check DE3 clear 6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 7 of 44 Event

Description:

1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

Time Pos. Expected Actions/Behavior Comments RO (Step 8) Determine Status of Letdown:

- Manually close charging FK-122

- Minimize seal injection between 6-13 gpm

- Direct Chemistry to shutdown the zinc addition system (ZAS)

RO (Step 9) If letdown removed from service, place letdown back in service by:

- Verify all letdown orifice isolation valves

- CLOSED

- Place LP LTDN PRESS PK 145 on service:

. Place controller in MANUAL

. Adjust demand signal to 50% or Less

- Place LTDN HX OUTLET TEMP TK 144 on service:

- Place controller in AUTO

Set to maintain temperature 90 to 115°F

- Verify VCT HI LVL DIVERT VLV LCV-1 15A alignment:

Position indicator VCT light LIT -

. Handswitch in AUTO

- Verify LTDN HI TEMP DIVERT VLV TCV143:

. DEMIN light LIT -

Handswitch in AUTO

- Verify LTDN LINE CTMT ISO HV8152 OPEN

- Verify LTDN LINE ISO valves -

OPEN LCV459 and LCV46O

- Initiate minimum charging flow:

. Verify CHG FLOW FK 122 in MAN

- Establish minimum charging flow based on orifices to be placed on service:

- Open HV-81 49B or C 7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 8 of 44 Event

Description:

1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

Time Pos. Expected Actions/Behavior Comments SRO (step 5 of EA3 ARP) Refer to Technical Specifications LCOs 3.5.2, and Technical Requirements TR 13.1.5.

3.5.2 mandatory LCO Condition A; since this pump is aligned to B Train and the swing pump is aligned to A Train. 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 13.1.5 admin LCO and mandatory LCO while swapping chci pumps from one train to the Condition A. Two charging pumps shall be operable and this is a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO.

TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

B Train ECCS is INOPERABLE until the lB chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1 B Chg pump to auto start CONDITION REQUIRED ACTION COMPL ETION TIME A. One or more A.1 Restore train(s) to 72 trains OPERABLE status. hours Inoperable AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

TECHNICAL SPECIFICATION 13.1.5, Charging Pumps Operating -

Two charging pumps shall be OPERABLE.

This is an admin LCO to start. When the lB chg pump is being placed on the B Train then this will be a mandatory LCO for that time period.

CONDITION REQUIRED ACTION COMPL ETION TIME A. One required A.1 Restore at least two 72 charging charging pumps to hours pump inoperable OPERABLE status.

8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 2 Page 9 of 44 Event

Description:

1C charging pump high lube oil temperature. This takes 3 minutes to get the first alarm.

SRO The actions to place 1 B Chg pump on service in the B train should be initiated here.

Direct the Radside SO, Rover and the SSS Plant to place the 1 B chg pump on B Train.

SRO Notify the Shift Manager SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

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

9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 3 Page 10 of 44 Event

Description:

1A SGFP controller failure HIGH The bypass FRVs open up as the 1A SGFP speed decreases to 3200 rpm. Due to the slow reaction time of the bypass valves if the operator does not take manual control of the SGFP, ALL SGWL5 will decrease and a reactor trip will occur at 28%. Also if a long time is taken to increase SGFP speed, the FRV bypass valves will be full open and when the SGFP speed is raised a high flow will result which will cause a transient on the system.

Indications Available:

Annunciators: Recognize indications of 1A SGFP controller

- 1A, 1B, 1C SG LVL DEV (JF1, JF2, JF3) failing:

- ALL FRV bypasses go open

- 1A SGFP will slow down

- ALL SG levels

- RxPower.J.

- RCS temp will Time Pos. Expected Actions/Behavior Comments A )P-100, Instrumentation Malfunction, version 9.0, section 1.4 (AOP-1 3 can be entered as well but it takes longer to take action.)

Team Check that steam and feed flows matched on all SGs (step 1) Take manual control of SGFP speed NOTE: Step 1 is an Immediate BOP by: Operator Action and a Place SK 509A or 509B in Manual and raise continuing action step demand as necessary.

Take manual control of all FRV bypass Bypass valves will need to be valves closed to prevent a large 1A SG BYPASS FLOW FK-479 cooldown on the RCS.

1 B SG BYPASS FLOW FK-489 1C SG_BYPASS_FLOW_FK-499 10

Argendix D ODerator Action Form ES-D-2 OP Test No.: FA2011301 Scenario # 6 Event # 3 Page 11 of 44 Event

Description:

1A SGFP controller failure HIGH Time Pos. Expected Actions/Behavior Comments (step 2) If adverse trends in the SG level SRO exists then establish trip criteria

- The SRO is in charge of monitoring SGWLs and directing action based on the level.

NOTE: if the SGFP trips at IF a loss of main feedwater occurs, THEN 82% level then the reactor perform the actions required by AOP-1 3.0, would be tripped at this point.

LOSS OF MAIN FEEDWATER If an automatic action is required or set points is approached:

Trip the reactor and go to EEP-0 BOP (step 3) There will not be a ramp in progress since the main turbine is not on line.

BOP (step 4) Adjust speed back to within the Determine the instrument normal operating range for the feed failure. The alarm is due to the flow/steam flow P required for the existing failure of the controller for 1A power level. SGFP.

Since the main turbine is off line, the SGFP Check Steam flow and Feed speed should be adjusted back to 50 psid. flow indicators.

BOP (step 5) Check Steam Dumps in the Tavg NOTE: steam dumps are in m ode STM PRESS mode.

jQ control stm dumps in auto or manual as required SRO (step 6) Notify the Shift Manager SRO (Step 8) Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator At the discretion of the Lead Examiner move to Event #4.

11

Appendix D Operator Action Form ES-D-2 OpTestNo.: FA2011301 Scenario# 6 Event# 4 Page 12 of 44 Event

Description:

PK-444D controller failure HIGH.

EA1 1, 1 A Przr heater breaker trips open.

PK-444D will open and can be closed in manual. When the spray valve opens, EA1 1, 1A Pzr Heater breaker, trips open. RO will place PK-444D in manual and close, then ensure all heaters are on.

Indications Available:

Annunciators: Recognize indications of spray valve failure and

- PRZR PRESS HI-LO (HC1) heater trip:

- PRZR PRESSREL VLV 445A OR B/U PK-444D demand t HTRS ON (HD1) Pzr pressure

- PRZR HTR BKR TRIPPED (HD5) Amber light above 1A Pzr Htr control Time Pos. Expected Actions/Behavior Comments I

AOP-100, Instrumentation Malfunction, version 9.0, section 1.1 SRO (step 1) Direct entry into AOP-100 Perform the lOAs of AOP-100 for RCS pressure.

BOP (step 1) Take manual control of PK-444D NOTE: Step 1 and 2 is an and close the controller. Immediate Operator Action

- Take manual control of Pzr heaters as necessary SRO (step 2) addresses a stuck open spray valve.

- This is not the case since PK-444D can be closed from the controller RO (step 3) There are no PORVs open so this step is skipped.

RO (step 4) Take manual control of Sprays, Heaters, PORVs and PORV isolation valves, as necessary (step 5) does not apply SRO (HD5) Refer to Tech Specs 3.4.1, DNBR limits and 3.4.9, Pressurizer.

12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event# 4 Page 13 of 44 Event

Description:

PK-444D controller failure HIGH.

EA1 1, 1 A Przr heater breaker trips open.

Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits If RCS pressure drops below 2209 psig then this TS applies. It is expected that pressure will drop below 2209 psig for this event.

CONDITION REQUIRED ACTION COMPL ETION TIME A. One or more A.1 Restore RCS DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months RCS DNB parameter(s) to within parameters not limit.

within limits.

TECHNICAL SPECIFICATION 3.4.9, Pressurizer The pressurizer shall be OPERABLE with:

a. Pressurizer water level <63.5% indicated; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group> 125 kW and capable of being powered from an emergency power supply.

1A Pzr Heater is a Tech Spec heater due to power supply.

CONDITION REQUIRED ACTION COMPL ETION TIME B. One required B.1 Restore required group 72 group of of pressurizer heaters to hours pressurizer OPERABLE status.

heaters inoperable.

SRO (step 7) Notify the Shift Manager SRO (Step 9) Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator When Tech Specs have been evaluated and the plant is under control and at the discretion of the Lead Examiner move to Event #5.

13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 5 Page 14 of 44 Event

Description:

GSSC Exhaust fan trips, causes a loss of vacuum.

The GSSC EXH fan trips to start this event causing main condenser vacuum to rise or get worse.

There is only one set of CT fans on service and one Circ water pump. AOP-8.0 has the crew start this equipment and then send people out to find the problem.

If the crew decides to ramp down to <5% power, the booth operator will trip the 1A SGFP at 6%

power.

Indications Available:

Annunciators: Recognize indications of VACUUM 600V BKR TRIPPED (LG3) PROBLEMS:

TURB COND VAC LO (KK1) (1.485 - Vacuum rising from 1.0 to 1.6 psia psia) - IPC alarm on GSSC brker open Time Pos. Expected Actions/Behavior Comments J

ARP -1.11, LG3, version 49 ARP-1.10, version 66 AOP-8.0, version 22 SRO Direct crew to reference LG3 to determine NOTE: There are 12 breakers reason it is in alarm. KK1 has information to listed in this ARP as to the transition to AOP-8.0. reason, among them is EQ21, Old Gland Steam exhauster The other GSSC EXH fan is not normally Manual; overcurrent; or lined up so that if the fan was started wlo undervoltage.

referencing the procedure, there would be no effect on condenser vacuum.

Step 6 of AOP-8 has SOP-28.4 used to place the fan on service.

SRO (step 1) Direct Monitoring Condenser pressure should be approx pressure. WHEN turbine power less than 1.485 PSIA and slowly rising 30%, THEN verify condenser pressure less than 1.7 psia (3.5 inHga)

SRO (step 2) Monitor trip criteria SRO (step 3) Stabilize condenser vacuum using any or all of the following actions based on plant conditions, and the rate at which vacuum is worsening 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 5 Page 15 of 44 Event

Description:

GSSC Exhaust fan trips, causes a loss of vacuum.

Time Pos. Expected Actions/Behavior Comments BOP (step 3)

- Start additional cooling tower fans call OSSO

- Verify proper operation of on service TBSO called SJAEs

- Start an addWonal CW PUMP (step 4) Dispatch personnel to check main turbine gland sealing steam pressures

- HP gland pressure On MCB check P1-406gB In the Turbine Bida:

LP gland seal pressure HP qland steam supply TBSO called SRO (step 5) Dispatch personnel to verify SJAE TBSO or SSS-Plant called steam supply regulator OPERATING PROPERLY. (155ft, TURB BLDG)

(step 6) verify on service GSSC EXH FAN -

OPERATING PROPERLY. (155 ft, TURB BLDG) This sten mv be done After report that GSSC EXH fan is tripped earlier since LG3 is in alarm then start standby GSSC EXH FAN using and the GSSC EXH fan will SOP-28.4, GLAND SEALING STEAM be found NOT RUNNING System SRO (step 7, 8 and 9) Dispatch personnel to TBSO or SSS-Plant called inspect the main condenser for leaks and to vent the main condenser BOP (step 10) Check Hotwell level less than 4 ft When GSSC EXH fan is running then go to next event by making loa-cfw049 set to 1000.

Go to event 6.

15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 6 Page 16 of 44 Event

Description:

Loss of vacuum.

Vacuum continues to get worse, 1 A SGFP Trips Trip the reactor lAW AOP-1 3.

Indications Available:

Annunciators: InrIirtinnq of BOTH SGFP TriDs

- 1A or lB SGFP Tripped (KC3) - SGFP Speed Decreasing toward 0 RPM

- SG LVL DEV (JF1, JF2, JF3) - Feed Flow Decreasing

- SG LO LVL (JA1, JA2, JA3) - FRV-controller FK-496, 497, 498 demand

- SG STM Flow> Feed Flow (JB1, JB2, increasing J B3) - SG Levels decreasing J .

- Pos.

I Expected ActionIBehavior Comments AOP-13, version 30 SRO Recognize LOSS of BOTH SGFPs Direct Step 2 of AOP-1 3

- Perform the lOAs of AOP-13 RO (Step 2) Check Rx power less than 5% NO >5% power SRO Direct Reactor trip RO Trip the reactor using handswitches Enter EEP-0, Reactor Trip or Safety Injection, version 38 SRO Reactor trip Direct the reactor trip and enter EEP-0 16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 6 Page 17 of 44 Event

Description:

Loss of vacuum.

Pos. Expected Actions/Behavior Comments RO/ (step 1) Immediate Operator actions of EEP Immediate Action steps of BOP 0 EEP-0 Check reactor trip. NOTE: CRITICAL TASK Check all reactor trip breakers and reactor RNO: Reactor is not tripped trip bypass breakers OPEN.

by RTBs but is tripped by opening the CRDM MG sets (step 2) Check turbine - TRIPPED.

TSLB2 14-1 thru 4 lit (step 3) Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F 41 60V bus) power available lights lit OR B Train (G 41 60V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 4) Check SI Status. RNO- go to ESP-0.1 Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[) MLB-1 1-1 lit

[1 MLB-1 1 1-1 lit ESP.0.1, Reactor Trip Response, version 30 actions below SRO SI is NOT required at this point, directs transition at step 4 of EEP-0 to ESP-0.1, REACTOR TRIP RESPONSE Directs actions in ESP-0.1 per RO/BOP Actions listed below 17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 6 Page 18 of 44 Event

Description:

Loss of vacuum.

Pos. Expected Actions/Behavior Comments RO (step 1) Check RCS temperature NOTE: this is a continuing

- Stable at or approaching 547°F action step

- TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[] TI 422D STM DUMP

[1 TI 432D GOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step status.

- Verify FRVs closed Will have to close the Bypass FRVs since P-4 is not present

- Defeat the MDFWP auto start on SGFP trip When ESP-O.1 entered then put in SGTR.

CRITICAL TASK When the foldout page criteria is met for a Safety Injection, <16°F SCMM or Pzr level <4%. Pzr level will be trending down and it is not necessary to wait until 4% to initiate the SI.

When SI is initiated, then go to event 7.

18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 19 of 44 Event

Description:

1A SGTR 300 gpm.

1A SGTR 300 gpm ramped in over 5 minutes after entry into ESP-0.1.

. AFW pumps will not start.

. FCV-3227A, 1A AFW FCV, will fail open 6.667 minutes after the SI occurs.

. 1C chg pump will auto start on the SI. If allowed to run and increase temperature to 170°F, then 1C chg pump will be tripped.

Indications Available:

Annunciators: Recognize indications of a SGTR on 1A SG:

- Various and many - 1A SG NR level t

- Pzr pressure .

- Pzr Level Enter EEP-0, Reactor Trip or Safety Injection, version 38 SRO Direct entry into EEP-0 RO! (step 1) Immediate Operator actions of EEP BOP 0 Check reactor trip.

Check all reactor trip breakers and reactor trip bypass breakers OPEN.

(step 2) Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit 19

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event# 7,8,9&10 Page 20 of 44 Event

Description:

1A SGTR 300 gpm.

RO/ (step 3) Check power to 4160 V ESF BOP busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F 41 60V bus) power available lights lit OR B Train (G 41 60V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 4) Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[1 MLB-1 1-1 lit

[1 MLB-1 1 1-1 lit 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 21 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected ActionslBehavior Comments SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to do attachment 2.

(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig RO (step 7) Announce Unit 1 reactor trip and safety injection.

RO (step 8) Check AFW status.

Check secondary heat sink Available o Check total AFW flow > 395 gpm

[j Fl 3229A

[] Fl 3229B

[1 Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level > 31% {48%}

WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.

WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 22 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[J A TRN reset

[1 B TRN reset MDAFWPTO lA/lB/iC SG BTRN

[1 FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR APPROACHING 547°F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[] TI 422D

[1 TI 432D 22

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 1301 Scenario # 6 Event # 7, 8, 9 & 10 Page 23 of 44 Event

Description:

1A SGTR 300 gpm.

Time PoS. Expeóted Actions!Behavior Comments RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column is not 547°F and falling, THEN perform the expected to be used for this following, scenario (step 9.1.1) Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB

[j Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG

[] Fl 3229A

[] Fl 3229B

[] Fl 3229C AFW TOTAL FLOW

[1 Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 NOTE: Will call TBSO to IF MSIVs are open, THEN isolate steam accomplish this task loads in the turbine building while continuing with RNO step 9.1 .5.

23

Appendix D Operator Action Form ESD-2 Op Test No.: FA2011301 Scenario # 6 Event# 7,8,9&10 Page 24 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected ActionslBehavior Comments RO (step 10) Check pressurizer PORVs and NOTE: [CA) step spray valves.

WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

Verify both PRZR PORV5 indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.

[1 PRT PRESS P1 472

[1 PRT LVL LI-470

[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray NOTE: [CA] step C) valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[]PK444C

[] PK 444D Check any PRZR PORV ISO OPEN -

RO (step 11) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 1 6°F{45°F}

SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <

Control charging pump miniflow valves 1300 psig.

based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[1 P1 403A 24

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 25 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. j Expected Actions/Behavior I Comments Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

SRO (step 13) Check SGs not faulted.

[] Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

(step 14) Check SGs not ruptured [] R-15

- Check secondary radiation indication -

[] 19 NORMAL. [] 23A and B

[] 15B and C,

- No SG rising in an uncontrolled manner [] 60 A, B, C, D EEP-3.0, SGTR, version 26, below.

RO (step 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication -> 16°F{45°F} SUBCOOLED IN CETC MODE.

BOP (step 2) Identify ruptured SG(s). NOTE: this is a continuing action step Check any SG level - RISING IN AN UNCONTROLLED MANNER 25

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 26 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments.

SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: this is a continuing RO THEN isolate flow from ruptured SG(s). action step Verify ruptured SG(s) atmospheric relief valve ALIGNED.

- PC3371A set 8.25 and in auto

- Verify 3371A is closed Isolate steam supply from ruptured SG(s)to Neither lB or 1C SG is TDAFWP: N/A ruptured CRITICAL TASK Verify blowdown from ruptured SG(s) - Closes 7614A ISOLATED.

CRITICAL TASK (step 3.7) Verify at least one SG MSIV on 1A Verifies MSIV 3369A or SG closed 3370A closed and bypass valves closed BOP (step 4) WHEN ruptured SG(s) NR level NOTE: this is a continuing greater than 31% THEN perform the action step following:

Isolate AFW flow to ruptured SG(s) using FCVs.

CRITICAI TASK FCV-227A will

- FCV 3227A in MOD, and closed fail open and must be isolated

- HV 3328A in MOD and closed lAW this step If AFW flow from MDAFWP(s) NOT isolated, THEN isolate flow to 1A SO by closing MOV 3764A OR E SRO (step 5) Check ruptured SG(s) pressure GREATER THAN 250 psig.

SRO (step 6) Evaluate performing an RCS cooldown.

Determine required CETCs for cooldown based on ruptured SG pressure.

26

Appendix D Operator Action Form ES-D-2 FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 27 of 44 Op Test No.:

Event

Description:

1A SGTR 300 gpm.

Comments Time Pos. J Expected ActionslBehavior RUPTURED REQUIRED SG CORE PRESSURE EXIT (psig) TEMPERATURE 1151 - 1200 536°F (522°F) 1101 1150 531°F (516°F) 1051 - 1100 525°F (510°F) 1001 - 1050 519°F (504°F) 951 - 1000 513°F (L98°F) 901 - 950 507°F (491°F) 851 - 900 500°F (484°F) 801 - 850 494°F (477°F) 151 - 800 487°F (469°F) 701 - 750 479°F (461°F) 651 - 700 471°F (453°F) 601 - 650 463°F (443°F) 551 - 600 454°F (434°F) 501 - 550 445°F (423°F) 451 - 500 434°F (41°F) 401 - 450 23°F (400°F) 351 - 400 411°F (386°F) 301 - 350 398°F (370°F) 251 - 300 383°F (353°F)

- 250 365°F (332°F)

This is a good place to terminate the scenario.

SRO Direct the STA to Display the hottest CETC page 1TC1 on plant computer.

This is normally selected by the STA and put on the control board display.

27

Appendix D Operator Action Form ES-D-2 FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 28 of 44 Op Test No.:

Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments SRO Will direct these steps:

(step 6.3 -6.4)

Begin RCS cooldown to cold shutdown.

Depending on RCS temperature the BOP will either start the cooldown and then bypass the stm dump interlock for P-12 or will bypass initially.

The Stm Dumps will be set up in the STM Press mode and the cooldown started at the maximum rate. This means the steam dumps are to be opened to approx. 20%.

28

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 29 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions!Behavior Comments BOP (step 6.3) WHEN P-12 light lit (543°F), THEN RNO: condenser may not be perform the following: available so the atmospherics for lB and 1C SGs will be Block low steam line pressure SI. opened.

Place handswitches for STM LINE PRESS SI BLOCK RESET

[] A TRN to BLOCK

[] B TRN to BLOCK Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

[1 TRAIN A BLOCKED light lit

[1 TRAIN B BLOCKED light lit Bypass the steam dump interlock.

STM DUMP INTERLOCK

[] A TRN to BYP INTLK

{j B TRN to BYP INTLK Adjust steam header pressure controller to maximize the cooldown rate STM HDR PRESS

{J PK 464 adjusted Use Stm dumps to cooldown since they are available.

(step 6.6) Stop the cooldown when the hottest CETC temperature is less than the required temperature (step 6.7) maintain CETCs at the required Temp.

29

Operator Action Form ES-D-2 Appendix D FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 30 of 44 Op Test No.:

Event Descnption: 1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments BOP (step 7) Check intact SG levels.

Check any intact SG narrow range level GREATER THAN 31%{48%}.

[CA) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31%-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[] B TRN reset MDAFWPTO lA/lB/iC SG BTRN

[] FCV 3227 in MOD Control TDAFW P flow.

TDAFWP FCV 3228

[} RESET reset TDAFWP SPEED CONT

[j SIC 3405 adjusted 30

Aendix D ODerator Action Form ES-D-2 FA2011301 Scenario # 6 Event# 7,8,9&1O Page 31 of 44 Op Test No.:

Event

Description:

1A SGTR 300 gpm.

Expected Actions/Behavior Comments____

Time Pos.

RO (step 8) Check pressurizer PORVs Check any PRZR PORV ISO power available

[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[1 PORV Temp TI-463 Check PRT parameters STABLE or FALLING.

[1 PRT PRESS P1 472

[] PRT LVL Ll-470

[] PRT TEMP Tl-471 Check at least one PRZR PORV ISO -

OPEN BOP (step 9) Verify SI RESET.

MLB-1 1-1 not lit (A TRN) and MLB-1 11-1 not lit (B TRN)

(step 10) Verify PHASE A CTMT ISO -

RESET.

MLB-2 1-1 not lit and MLB-2 11-1 not lit BOP (step 11) Check PHASE B CTMT ISO -

RESET.

31

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 32 of 44 Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments RO (step 12) IF instrument air available, THEN establish instrument air to containment.

Verify at least one air compressor started.

AIR COMPRESSOR

[j 1A

[1 1 B

[] 1C Check INST AIR PRESS P1 4004B greater than 85 psig.

Check instrument air to containment.

IA TO CTMT

[j MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO

[] Annunciator KD1 clear RO (step 13) [CA] Check if LHSI Pumps should be stopped.

Check RCS pressure GREATER THAN 275 psig{435 psig}

PT-402 AND 403 Check RCS pressure STABLE OR RISING

- RNO:Secure any running RHR pumps Verify the SI reset Take HS to stop.

SRO (step 14) Check if Cooldown should be stopped.

Check hottest core exit T/Cs - LESS THAN REQUIRED Temperature.

RNO Stop RCS cooldown Do NOT proceed until hottest Maintain core exit T/Cs LESS THAN core exit T/Cs LESS THAN REQUIRED TEMPERATURE. REQUIRED TEMPERATURE.

32

Operator Action Form ES-D-2 Appendix D FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 33 of 44 Op Test No.:

Event

Description:

1A SGTR 300 gpm.

Time Pos. Expected Actions/Behavior Comments SRO (step 15) Check ruptured SG(s) pressure -

STABLE OR RISING.

(step 16) Check SUB COOLED MARGIN MONITOR indication GREATER THAN 36°F{65°F} SUBCOOLED IN CETC MODE.

RO (step 17) Reduce RCS pressure to minimize break flow and refill pressurizer.

Open all available normal pressurizer spray valves.

1A(1B) LOOP SPRAY VLV

[]PK444C

[]PK444D SRO (step 18) Reduce RCS pressure until one of the following three conditions occurs, then stop RCS pressure reduction.

RCS pressure less than ruptured SG pressure AND pressurizer level greater than 1 3%{43%}

OR RCS pressure within 300 psi of ruptured SG(s) pressure AND Pzr level >43%{50%}

OR Pressurizer level greater than 73%{66%} Then verify the sprays are OR closed.

SCMM indication less than 16°F{45°F}

subcooled in CETC mode.

33

Operator Action Form ES-D-2 Appendix D FA2011301 Scenario # 6 Event # 7, 8, 9 & 10 Page 34 of 44 Op Test No.:

Event

Description:

1A SGTR 300 gpm.

Comments Time Pos. Expected Actions/Behavior SRO (step 20) Check SI termination criteria o Check SUB COOLED MARGIN MONITOR indication GREATER THAN 0 16°F{4 F } 5 SUBCOOLED IN CETC MODE.

o Check secondary heat sink available.

>395 gpm AFW flow

> 31%{48%} SGNR level o Check RCS pressure STABLE OR RISING o Check pressurizer level GREATER THAN_1 3%{43%}.

When cooldowri determined at step 6.1 and at the discretion of the Lead Examiner, terminate the scenario.

34

FA2011301 Scenario # 6 Event # 8 Page 35 of 44 Op Test No.:

Event

Description:

Attachment 2 of EEP-O.O Cue: BOP will accomplish when at step 5 of EEP-O A+thmnf 2 of EEP-O AUTOMATIC ACTIONS VERIFICATION Pos. Expected Actions/Behavior Comments Time (Step 1) Verify one CHG PUMP in each train STARTED.

BOP [j A train (1A or 1B) amps > 0

[1 B train (1 C or 1 B) amps > 0 BOP (Step 2) Verify RHR PUMPs STARTED. -

RHR PUMP

[1 1A amps> 0

[1 lBamps>.0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow GREATER THAN 0 gpm.

[1 Fl 943 BOP (Step 3.2) Check RCS pressure LESS -

THAN 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow greater than gpm 1.5 Xlo 3

[] 1A RHR HDR FLOW Fl-605A

[] lB RHR HDR FLOW Fl-6053 BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[JA train (1A,1B or 1C)

[] B train (1D,lEor 1C) 35

6 Event # 8 Page 36 of 44 Op Test No.: FA2011301 Scenario #

Event

Description:

Attachment 2 of EEP-O.O Pos. Expected ActionslBehavior Comments Time BOP (Step 5) Verify each train of CCW -

STARTED.

(Step 5.1) Verify one CCW PUMP in each train- STARTED.

A train HX 1 C or 1 B CCW FLOW

[j Fl 3043CA > 0 gpm OR

[] Fl 3043BA> 0 gpm B train HX 1A or lB CCW FLOW

[] Fl 3043AA> 0 gpm OR

[1 Fl 3043BA> 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[} Q1P16FI3009AA> 0 gpm

[] Qi P1 6F13009BA> 0 gpm

[] Qi P1 6F13009CA> 0 gpm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[] 1A

[] 1 B

[J 1C Check INST AIR PRESS P1 4004B greater than 85 psig.

36

FA2011301 Scenario# 6 Event# 8 Page 37 of 44 Op Test No.:

Event

Description:

Attachment 2 of EEP-O.O Expected Actions/Behavior Comments Time Pos.

BOP (step Verify containment ventilation 6) isolation.

Verify containment purge dampers -

CLOSED.

[]3197

[)3198D

[1 3198C

[] 3196

[1 31 98A

[] 3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-31 98A & 31 98D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[1 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 37

6 Event # 8 Page 38 of 44 Op Test No.: FA2011301 Scenario #

Event

Description:

Attachment 2 of EEP-O.O Expected Actions/Behavior Comments Time Pos.

BOP (step Verify containment fan cooler 7) alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[] 1A

[] 1 B B train

[] 1C

[J 1 D Verify associated emergency service water outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3O24A

[] Q1P16MOV3O24B

[] Q1P16MOV3O24C

[] Q1P16MOV3O24D BOP (step 8) Verify AFW Pumps- STARTED.

Verify both MDAFW Pumps STARTED

[] 1A MDAFW Pump amps> 0

[] lB MDAFW Pump amps> 0 AND

[] Fl-3229A indicates > 0 gpm

[] Fl-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

ECondition ETSLB ESetpoint ElCoincidenceE RCP Bus TSLB2 1-1 E2680 V 1/2 Detectors 1-2 1-3 on 2/3 Busses Undervoltacje Low Low SG TSLB4 28% 2/3 Detectors 4-1,4-2,4-3 on 2/3 SGs Water Level In Any 5-1,5-2,5-3 2/3SGs 6-1,6-2,6-3 38

Event # 8 Page 39 of 44 Op Test No.: FA2011301 Scenario # 6 Event

Description:

Attachment 2 of EEP-O.O Expected ActionslBehavior Comments Time Pos.

BOP (step 8.3) Verify TDAFWP started.

[1 MLB-4 1-3 lit

[1 MLB-4 2-3 lit

[] MLB-4 3-3 it TDAFWP SPEED

[]Sl 3411A>3900 rpm TDAFWP SPEED CONT

[1 SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SO.

TDAFWPTO 1A(1B1C) SG

[1 Q1N23HV3228A in MOD

[1 Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C) SO FLOW CONT

[] HIC 3228AA open

[j HIC 3228BA open

[] HIC 3228CA open 39

FA2011301 Scenario # 6 Event # 8 Page 40 of 44 Op Test No.:

Event

Description:

Attachment 2 of EEP-O.O Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

1A(1B,1C) SG FW FLOW

[1 FCV 478

[1 FCV 488

[1 FCV 498 Verify both SGFPs TRIPPED.

Verify SG blowdown ISOLATED.

1A(1B,1C) SGBD ISO

[] Qi G24HV761 4A closed

[1 Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[J MLB1 1 9-3 lit Qi P1 5HV3329 closed

[] MLB1 1 9-4 lit Qi P1 5HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

Sicinal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.

(Step 11 .1) Verify PHASE A CTMT ISO -

ACTUATED.

BOP [J MLB-2 1-1 lit

[1 MLB-2 11-1 lit 1 1.2 Check all MLB-2 lights LIT.

40

FA2011301 Scenario # 6 Event # 8 Page 41 of 44 Op Test No.:

Event

Description:

Attachment 2 of EEP-O.O Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[1 N1C11EOO5A

[1 N1C1IEOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[hA

[] 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[118 If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate Will call TBSO to pumps per FNP-O-SOP-O.O, APPENDIX B, accomplish this.

TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.

4].

FA2011301 Scenario # 6 Event # 8 Page 42 of 44 Op Test No.:

Event

Description:

Attachment 2 of EEP-O.0 Time Pos. Expected ActionslBehavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[j A TRAIN

[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[]810- OPEN

[] 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.

End of Attachment 2 42

FA2011301 Scenario# 6 Event# 8 Page 43 of 44 OpTestNo.:

Event

Description:

Attachment 4 of EEP-O.O Time Pos. Expected ActionsIBehavior Comments Attachment 4 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DFO1 closed

[J Verify DFO2 closed

[] Check DG15 closed

[J Verily DGO2 closed

[] Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.

[J Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21M0V8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[1 Q1E21MOVB130A

[]Q1E21MOV813OB

[] Q1E21MOV8131A

[J Q1E21MOVB131B 43

FA2011201 Scenario # 6 Event# 8 Page 44 of 44 Op Test No.:

Event

Description:

Attachment 4 of EEP-O.O Pos. Expected Actions/Behavior Comments Time (Step 1.7) Verify all post accident containment air mixing system fans STARTED. (GOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1 B

[] 1 C

[1 1 D RX CAV H2 DILUTION FAN

[1 1A

[} 1 B (Step 1.8) WHEN power restored to any de energized emergency bus, THEN verity alignment of associated equipment.

BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 44

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2O11-301 Page 1 of 2 Brief This simulator performance scenario is perfonried in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were intheMCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

Assign operating positions.

Ask for and answer questions.

Appendix D Turnover sheet Form ES-D-2

[X]Unit [ ]Unit2 Shift: Date 1

j Oft-going SS J Oncoming SS [ IN [ Xi D J Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, S, D, SW, X on key ring. SS Unit 4% power, UOP-1.2, viOl, completed thru step 5.57. 1209 ppm, MOL; 5000 MWD/mtu Status TARGET ZERo STPs/Evolutions: EVC Day. Eery Job Safely A Train On-Service A Train Ramp up to 12% power Protected i.0_; 109.1 Noadi.; 63.7; FSP-20,0 Status of Special Testing General Information

1. Reactor startup in progress, currently at 4% power. UOP-1 .2, completed thru step 5.57. Ready to perform step 5.58.

Ramp up to 12% power in preparation of placing the Main Turbine on service.

2. Half of the A, B, and C cooling tower fans are on service.

3. 1A CW pump only 0/S

4. Aux steam is from U-2.

5. 1A SGFP on service.

6. Current Risk Assessment is GREEN and projected is GREEN

7. Thunderstorm warnings in effect for southeast Alabama and Georgia.

8.

9.

10.

Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status

3 RHT On Service WGS secured; LCO Status Ready to enter Mode 1 Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X ] Yes [X I Yes [X I Yes [X]Yes [X]Yes [X] Yes

Appendix D Scenario Outline Form ES-D-1 Facility:

Examiners:

Farley Nuclear Plant

) Scenario No.:

Operators:

5 Op-Test No.: FA201 1 -301 SRO RO BOP Initial Conditions: 95% power, 59 ppm, EOL, ramping down at 2 MW/rn in Turnover:

. 1 -2A DG TIC for governor work. (OCS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

. MK5, SEISMIC PANEL ALARM,_actions are in progress.

. Current Risk Assessment is 3R and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

1 R (RO & Seismic event annunciator MK5 requires a reactor shutdown BOP) per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Increase ramp rate to 5 MW/mm and ramp down.

2 1 I (RO) PT-445 fails high. PORV can be closed, but leaks by; block valve must be shut.

TS (SRO) T.S. 3.4.11 Condition B and 3.4.1 Condition A 3 2 C (BOP) 1 E SW pump trips; requires starting the 1 C SW pump.

TS (SRO) TS 3.7.8 Condition A; 3.8.1 Condition B 4 3 I (BOP) FT-485, CH IV 1 B SG Steam Flow transmitter, fails low 5 4 C (RO) Approx. 125 gpm RCS leak develops. AOP-1.0 entered.

TS (SRO) T.S. 3.4.13 Condition A 6 C (AC) 1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP.

7 5 M (ALL) When 1A ACP is secured, a SBLOCA (400 gpm) occurs.

SI fails to automatically initiate and must be manually initiated.

6 C (AC) (CT) 8 7 C (RO) SW bus 1 L trips when SI occurs, requires emergency shutdown of 1 B DG per EEP-0, Attachment 1 or EPB posted operator aid.

9 8 C (BOP) MCV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Farley May 2011 exam Page 1 of 5

Appendix D Scenario Outline Form ES-D-1 Scenario may be terminated after transition to ES P-i .2 announced.

(N)ormal, (R)eactivity, (I)nstrument, (c)omponent, (M)ajor Farley May 2011 exam Page 2 of 5

Appendix D Scenario Pre-sets Form ES-D-1 0 0 Tag out lB EH pump

CMFmalf I cmshfpb_cp2 0 0 Block Phase A isolation train A

imf csftyinj_cc7 open 9 0 MOV81 00 does not close on Phase A isolation B Train:

imf cCVH100_d_cc8 open 9 0 HV81 52 does not close on Phase A isolation B Train:

lmf ccvhl52_d_ccl closed 9 0 HV3376 does not close on Phase A isolation B Train:

Imf chvh3376_d_ccl closed 0 0 Automatic SI blocked on both trains:

CMFmalf / cSFTYINJ_ccl I open CMFmalf / cSFTYINJ_ccl 1 I open 2 0 PORV 445 sticks at 10% after being demanded closed: Trigger 1 VLVS I RRC445A-S / 10 I trigger 1 7 0 A SB LOCA occurs when 1A RCP is secured: Trigger 2 MALF I R I MAL-RCS1 b / 400 / trigger 2 8 0 Breaker DGO2-1 for 1 L bus trips on SI: Trigger 3 CMFmalf / cBKl DGO2_col I trigger 3 3 0 1 D SW pmp has degraded head Trigger 1 mt_nncpswle-d_(1_0)_40 0 0 Tag 1 -2A DG output breakers for Unit 1 & 2

rack out 1-2A DG DFO8-1 rack out 1-2A DG DFO8-2 CMFremote I cbkldt08_d_cdl I open CMFremote I cbk2df08_d_cdl I open Triggers and Commands 2 0 Event Trigger 1 monitors P1-444 < 2210 psig trgset 1 p1444 < 2210 7 0 Event Trigger 2 monitors Fl-414 < 40%

trgset 2 fi414 < 40 8 0 Event trigger 3 monitors 8803a (for SI):

trgset 3 rsi88O3a > 0.1 Farley May 2011 exam Page 3 of 5

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 95% power, 59 ppm, EOL, ramping down at 2 MW/mm Turnover:

1 -2A DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump T/C for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

MK5, SEISMIC PANEL ALARM, actions are in progress.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 ARP for MK5 requires shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Verifiable actions: Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . RO will adjust rods or boron to control Tavg/Tref on program, BOP will set up ramp rate at 5 MW/rn in and continue the ramp on the Main Turbine.

Event 2 PT-445 fails high. Crew enters ACP-100.

Verifiable actions: close PORV 445. PORV 445 discovered to be leaking by (RCS pressure continues to decrease) and PCRV block valve must be closed. TS. 3.4.11 Condition B and 3.4.1 Condition A Event 3 1 E SW pump trips. AOP-10 or ARP for AE4 Verifiable actions: start 1C SW pump TS 3.7.8 Event 4 FT485, CH IV 1 B SG Steam Flow transmitter, fails low Verifiable actions: Take manual control of 1 B FRV and control SGWL before a Rx trip occurs.

Event 5 Small RCS leak develops. AOP-1 .0 entered. Leak will be large enough (approx.125 gpm) to have RO secure letdown and open LCV-115B/D.

Verifiable actions: Letdown will be secured and LCV-1 15B/D opened. Ramp will be increased to keep TavglTref on program TS 3.4.13 Condition A.

Event 6 1A RCP experiences high vibrations and requires a reactor trip and securing of the 1A RCP.

Event 7 When 1A RCP is secured, a SBLOCA (400 gpm) occurs.

The safety injection fails to automatically occur requires manual SI. (CT)

Event 8 When the SI occurs, 41 60V bus 1 L (SW bus) supply breaker trips. Results in loss of SW to 1 B DG and DG must be emergency shutdown.

Event 9 MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Scenario may be terminated after transition to ESP-1 .2 announced.

ARP for MK5/ AOP-1 0 / AOP-1 00/ AOP-1 .0 / ARP for HH4 / EEP-0 / EEP-1 / ESP-1 .2 Farley May 2011 exam Page 4 of 5

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-0 - - D)

Transition to any E-1 series procedure or

Transition to any FRP

Completion of step 9 in ESP-0.1

2. Close containment isolation valves such that at least one valve is closed on each critical phase A penetration before the end of the scenario: (WOG CT E-0 - - 0)

Close MOV-8100 or MOV-81 12, HV-8152 or HV-8149A, B and C and HV 3376 or HV-3377.

A Train Phase A does not work in Auto or manual.

SCENARIO 100% power, the crew is required to ramp down to mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

OBJECTIVE!

OVERVIEW: The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-1 00, AOP-1 .0, AOP-1 0.0, & Tech Specs

identify a SBLOCA, initiate a manual SI, shutdown a EDG that has no SW supplied

and then successfully enter EEP-1 .0 and transition to ESP-1 .2 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5B) 8

2. Malfunctions after EOP entry (12) 3

3. Abnormal events (24) 5

4. Major transients (12) 1

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 2 Farley May 2011 exam Page 5 of 5

Scenario #5 FA2O1 1301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #5 Validation time: 100 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approval: Gary Ohmstede Date: 2/11/2011 NRC Chief Examiner Ron AieIlo Date:

SOUTHERN COMPANY

Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: 2011 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 95% power, 59 ppm, EOL, ramping down at 2 MW/mm Turnover:

. 1 -2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

. MK5, SEISMIC PANEL ALARM, actions are in progress.

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 R (RO & Seismic event annunciator MK5 requires a reactor shutdown BOP) per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Increase ramp rate to 5 MW/mm and ramp down.

2 1 I (RO) PT-445 fails high. PORV can be closed, but leaks by; block valve must be shut.

TS (SRO) T.S. 3.4.1 1 Condition B and 3.4.1 Condition A 3 2 C (BOP) 1 E SW pump trips; requires starting the 1 C SW pump.

TS (SRO) TS 3.7.8 Condition A; 3.8.1 Condition B 4 3 I (BOP) FT-485, CH IV 1 B SG Steam Flow transmitter, fails low 5 4 C (RO) Approx. 125 gpm RCS leak develops. AOP-1.0 entered.

TS (SRO) T.S. 3.4.13 Condition A 6 C (RO) 1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP.

7 5 M (ALL) When 1A RCP is secured, a SBLOCA (400 gpm) occurs.

SI fails to automatically initiate and must be manually initiated.

6 C(RO) (CT) 8 7 C (RO) SW bus 1 L trips when SI occurs, requires emergency shutdown of 1 B DG per EEP-0, Attachment 1 or EPB posted operator aid.

9 8 C (BOP) MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Farley May 2011 exam Page 2 of 14

Appendix D Scenario #5 Outline Form ES-D-1 Scenario may be terminated after transition to ESP-1 .2 announced.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 3 of 14

Appendix D Scenario 5 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 EOL, B Train on service, B Train Protected IC-215 is written to start scenario with a ramp in progress at 95% power Boron = 59.31 ppm Load in IC-215 and sim IC snap directory IC-215 Base IC is IC-76 RUN -

-1.

DO NOT RUN THESE IF IC-215 IS USED 0 0 Generic setup:

bat generic_setup_HLT.txt 0 0 Quick setup (all items with are included):

bat 201 1 nrcexam_05.txt PRESETS 0 0 Tag out 1 B EH pump

CMFmalf I_cmshfpb_cp2 0 0 Block Phase A isolation train A imf_csftyinj_cc7_open 9 0 MOV81 00 does not close on Phase A isolation B Train:

imf_cCVH100_d_cc8_open 9 0 HV81 52 does not close on Phase A isolation B Train:

lmf_ccvhl52_d_ccl_closed 9 0 HV3376 does not close on Phase A isolation B Train:

lmf_chvh3376_d_ccl_closed 0 0 Automatic SI blocked on both trains:

CMFmalf / cSFTYINJ_ccl I open CMFm alt! cSFTYINJ_ccl 1_I open 2 0 PORV 445 sticks at 10% after being demanded closed: Trigger 1 VLVS_I_RRC445A-S_/_10_/_trigger_1 7 0 A SB LOCA occurs when 1A RCP is secured: Trigger 2 MALF!_R_/_MAL-RCS1 b_I_400_I_trigger_2 8 0 Breaker DGO2-1 for 1 L bus trips on SI: Trigger 3 CMFmalf / cBK1 DGO2col_I trigger_3 3 0 1DSW pmp has degraded head Trigger 1 mt_nncpswl e-d_(1_0)_40 0 0 Tag 1 -2A DG output breakers for Unit 1 & 2

rack out 1-2A DG DFO8-1 rack out 1 -2A DG DFO8-2 CMFremote I cbkldf08_d_cdl / open CMFremote_/_cbk2df08_dcdl_/ open Triggers_and_Commands 2 0 Event Trigger 1 monitors P1-444

< 2210 psig trgset_1_pi444_<_2210 7 0 Event Trigger 2 monitors Fl-414 < 40%

Farley May 2011 exam Page 4 of 14

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Appendix D Scenario 5 Simulator setup Form ES-D-l MCB setup Place 1 B EH pump HS to STOP and HOLD Tag on HS 1 HOLD tag HS to STOP 1 -2A DG Mode selector switch Place in Mode 3 Place HOLD Tag 1 -2A MSS 1 HOLD TAG Place HOLD Tag on 1 -2A DG output breakers 2 HOLD TAGS Place Unit 1 and unit 2 Bypass and inoperable panel Unit 1 A-Train lights to the up position (EMERGENCY POWER Unit 2 A Train SYSTEM)

DEH Clear DEH alarms IMPULSE LOOP is in service Select POWER OPS PRIMARY on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verity memory disks cleared Provide a marked up copy of UOP-3.1 version 106 UOP-3.1 copy and through step 8.11 complete and signed off UOP-2.1 UOP-2.1, version 69 Initial conditions signed off I

FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data -

collection:

Simview / sv DataCollection.uvl sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv simclock.uvl Seconds: clock(1 = 0 VERIFY MICROPHONES READY Batteries installed Farley May 2011 exam Page 6 of 14

Appendix D Scenario 5 Simulator setup Form ES-D-1 I TURNOVER SHEET AVAILABLE 1 Farley May 2011 exam Page 7 of 14

Appendix D Scenario 5 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam -

Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn Start of 1

exam Seismic event annunciator MK5 is in alarm.

Crew will start the ramp Ramp is in progress at 95% power and increase ramp rate 2 PT-445 fails high. imf PT445 2500 35 PORV can be closed but leaks by, block valve must be r

shut.

3 1 E SW pump trips; requires starting the 10 SW pump.

CMFmalf / cNCPSW1 F_d_col 4 FT-485, OH IV 1 B SG Steam Flow transmitter, fails low imtft485Ol5 NRC Approx 125 gpm RCS leak develops AOP 1 0 entered CUE p lmf mal-rcsla 125 200 6 1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP ANN / HH4 / failon 7 preset When 1A RCP is secured, a SBLOCA (400 gpm) occurs.

SI fails to automatically initiate and must be manually initiated.

Trigger 2 8 preset SW bus 1 L trips when SI occurs, requires emergency shutdown of 1 B DG per EEP-0, Attachment 1 or EPB Farley May 2011 exam Page 8 of 14

Appendix D Scenario 5 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND posted operator aid.

CM EmaIl I cBK1 DGO2_col Trigger 3 9 preset MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto.

Scenario may be terminated after transition to ESP-1 .2 announced.

End of Exam HORNSOFF EEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Farley May 2011 exam Page 9 of 14

Appendix D Scenario 5 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 IF REQUESTED RADSIDE:

Not expected to remove power CMFremote I cRC800A_d_cdl / open 3 IF REQUESTED Alignment of 1 C to auto-start for 1 E SW pump wil not take place during this exam.

IF REQUESTED Clear TURB BLDG MISC alarm 4 NONE REQUIRED 5 IF REQUESTED Clear Liq or WG panel alarm 6 WHEN REQUESTED Unit Two UO; RESET FIRE ALARM Mill ANN /MH1 failoff Fire alarm is reset fire alarm was 1A-22 in Unit One CTMT 7 NONE REQUIRED 8 NONE REQUIRED 9 NONE REQUIRED Farley May 2011 exam Page 10 of 14

Appendix D Scenario 5 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

IF REQUESTED SM:

I will contact Corporate Farley Plant Support and request the plant walk downs be conducted.

I will contact maintenance to perform FNP-O-MP-112.1 1 will get the condition reports required by the ARP generated.

2 IF REQUESTED RADSIDE:

Not expected to remove {After Local operator actions to open breaker FU-K4 are complete}

power I have opened breaker FU-K4 SM:

I understand we have an LCO for the PORV and that the block valve (8000A) had to be closed.

Work Week Co-ordinator I Understand there is a CR in Syncpower for PT-445 3 WHEN REQUESTED SSS/OUTSIDE:

1 E SW pump breaker DL-04 has an overcurrent flag. I do not see any obvious problems with pump or motor. Oil levels look good.

1 C SW pump appears to be operating normally TBSO:

The 1A TB chiller tripped alarm is in.

SSS:

I will coordinate with the Outside SO to align 1 C SW pump to auto start for 1 E SW pump. (SOP-24.OD checklist)

SM! DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

4 WHEN REQUESTED SSS-plant, SM and Dispatcher:

Recognize and repeat back FT-485 failure, CR in the cue and that type of communications.

SM:

I give you permission to place the FRV back in AUTO.

5 IFREQUESTED SM!DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

Farley May 2011 exam Page 11 of 14

Appendix D Scenario 5 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

WHEN REQUESTED RADSIDE:

The WHT level is in alarm.

6 WHEN REQUESTED SSS/RADSIDE:

1A RCP vertical shaft is reading 16.3 mils. Horizontal shaft is reading 16.5 mils. It appears that the shaft vibration rate of increase is approximately 1 mu every 5 minutes.

1A RCP frame vertical is reading 2.2 mils and the horizontal frame is reading 2.4. mils. The frame vibrations are stable and not changing.

7 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SM/SSS:

I will align backup cooling to the condensate pumps.

SM/SSS:

I will get someone to perform step 6 of EEP-1 ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling ROVER /SSS:

SW bus 1 L supply breaker DGO2-1 has an over current trip flag actuated on it.

Farley May 2011 exam Page 12 of 14

Scenario 5 detailed sum marsi Appendix D Form ES-D-1 sheet Initial Conditions: 95% power, 59 ppm, EOL, ramping down at 2 MW/mm Turnover:

1 -2A DG T/C for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

MK5, SEISMIC PANEL ALARM, actions are in progress.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 ARP for MK5 requires shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Verifiable actions: Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . RO will adjust rods or boron to control Tavg/Tref on program, BOP will set up ramp rate at 5 MW/mm and continue the ramp on the Main Turbine.

Event 2 PT-445 fails high. Crew enters AOP-100.

Verifiable actions: close PORV 445. PORV 445 discovered to be leaking by (RCS pressure continues to decrease) and PORV block valve must be closed. TS. 3.4.11 Condition B and 3.4.1 Condition A Event 3 1 E SW pump trips. AOP-1 0 or ARP for AE4 Verifiable actions: start 1 C SW pump TS 3.7.8 Event 4 FT485, CH IV 1 B SG Steam Flow transmitter, fails low Verifiable actions: Take manual control of 1 B FRV and control SGWL before a Rx trip occurs.

Event 5 Small RCS leak develops. AOP-1.0 entered. Leak will be large enough (approx.125 gpm) to have RO secure letdown and open LCV-1 1 5BID.

Verifiable actions: Letdown will be secured and LCV-115B/D opened. Ramp will be increased to keep Tavg/Tref on program TS 3.4.13 Condition A.

Event 6 1A RCP experiences high vibrations and requires a reactor trip and securing of the 1A RCP.

Event 7 When 1A RCP is secured, a SBLOCA (400 gpm) occurs.

The safety injection fails to automatically occur requires manual SI. (CT)

Event 8 When the SI occurs, 41 60V bus 1 L (SW bus) supply breaker trips. Results in loss of SW to 1 B DG and DG must be emergency shutdown.

Event 9 MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Scenario may be terminated after transition to ESP-1 .2 announced.

ARP for MK5/ AOP-1 0 / AOP-1 00/ AOP-1 .0 / ARP for HH4 / EEP-0 / EEP-1 I ESP-1 .2 Farley May 2011 exam Page 13 of 14

Scenario 5 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET

1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-0 - - D)

Transition to any E-1 series procedure or

Transition to any FRP

Completion of step 9 in ESP-0.1

2. Close containment isolation valves such that at least one valve is closed on each critical phase A penetration before the end of the scenario: (WOG CT E-0 - - 0)

Close MOV-8100 or MOV-8112, HV-8152 or HV-8149A, B and C and HV 3376 or HV-3377.

A Train Phase A does not work in Auto or manual.

SCENARIO 100% power, the crew is required to ramp down to mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

OBJECTIVE!

OVERVIEW: The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-100, AOP-1.0, AOP-10.0, & Tech Specs

identify a SBLOCA, initiate a manual SI, shutdown a EDG that has no SW supplied

and then successfully enter EEP-1 .0 and transition to ESP-1 .2 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 8

2. Malfunctions after EOP entry (12) 3

3. Abnormal events (24) 5

4. Major transients (12) 1

5. EOP5 entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 2 Farley May 2011 exam Page 14 of 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 1 Page 1 of 42 Event

Description:

Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

A ramp of 2 MW!min is in progress. The turnover sheet has the crew increase the ramp rate to 5 -

MW/mm and ramp off line lAW UOP-3.1 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Indications Available:

Annunciators: Other Indications:

- SEISMIC PANEL ALARM (MK5) will be NONE in alarm when the crew takes shift Time Pos. Expected Actions/Behavior Comments UOP-3.1, Power Operation, ver 109 step 8.3; Decrease reactor power to minimum load ARP-1.12, for MK5 version 59 ALL Re-commences Ramp by coordinating with the BOP to establish Main Turbine Target and ramp rate. A Ramp rate of at 5 MW!

mm will be required to ramp unit off per the turnover sheet.

UOP-3.1 actions here SROI At step 8.5 the following note explains how Flux is maintained +/- 5% from RO flux should be controlled: the target value NOTE: In the following step it is desirable to maintain axial flux difference within +/- 5%

from the target value to help ensure axial flux does not exceed limits specified in the COLR figure 3. During transients maintaining axial flux difference within the +/-

5% of the target value may not be possible.

BOP Begin lowering turbine load to 40 MW using NOTE: The ramp rate will be 5 the appropriate DEH controls MW!min.

. Ensure load rate increase is within required limitations.

. Verify the HOLD light is LIT.

. Depress the GO pushbutton and ensure the GO light is LIT.

. Ensure the Main Turbine starts to ramp down, GVs start to close.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 1 Page 2 of 42 Event Descripuon: Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Time Pos Expected Actions/Behavior Comments RO Verify rods are in AUTO or Manual and maintaining Tavg close to Tref.

RO (Step 1.0) Borating per SOP-2.3 appendix B Version 56

Set the boric acid integrator to the desired quantity NOTE: A continuous boration

. Adjust LTDN TO VCT FLOW LK 112 is allowed by appendix C setpoint as desired which maintains the BA

. M/U mode selector to STOP system lined up and the RO

MKUP MODE SEL SWITCH to BOR will take the MSS to START

. MKUP MODE CONT SWITCH to each time a boration is START. required.

(Step 1.6) Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B opens.

BORIC ACID TO BLENDER FCV113A opens.

Boric acid flow is displayed on Fl-i 13 MAKEUP FLOW TO CHGNCT.

RO (Step 1 .7) Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on FI-113 MAKEUP FLOW TO CHGNCT.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B closes.

BORIC ACID TO BLENDER FCV1 1 3A closes.

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

2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 2 Page 3 of 42 Event

Description:

FT-445 fails high. PORV can be closed, but leaks by; block valve must be shut.

Afterwards, PT-445 will fail high. The PORV will close but have significant leakby. The block valve must be closed and tech specs evaluated.

Indications Available:

Annunciators: Indications of PT-445 failing High:

- PRZR PORV TEMP HI (HA5) - P1-445 failing high

- PRZR SAFETY VLV TEMP HI (HA4) - PORV 445 indicating open

- REL VLV 444B\445A OPEN (HE1) - P1s 455;456;457, RCS Press

- PRZR PRESS RELVLV 445A OR BU HTRS - Pressurizer B/U heaters energizing ON (HD1) - TI-463 PORV Tailpiece temps I

- PRZR PRESS Hl-LO (HC1) - TI-465; Tl-467; TI-469 Code Safety Tailpiece_tern ps_I Time Pos. Expected Actions/Behavior Corn ments AOP-100 ver 10, Instrumentation Malfunction, section 1.1 SRO Direct entry into AOP-100 RO (step 1) Take manual control of the following Steps 1 and 2 are IOAs equipment as necessary:

- PORV445A

- Block valve MOV-8000A

- Pzr heaters (step 2) IF pressurizer pressure is *Spray valves verified decreasing due to a mechanically stuck open functioning properly (closed) spray valve PCV444C or PCV444D No actions required RO (step 3) If the PORV is open then close the NOTE: RNO actions PORV when RCS pressure is < 2310 psig. IF the PORV will not close, THEN perform the following:

IF pressurizer pressure is decreasing due to a Stuck open PORV, THEN close the associated PORV Block Valve.

IF PORV Block valve will not close, THEN trip the reactor and go to EEP-0.0, Reactor Trip or Safety Injection 3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 2 Page 4 of 42 Event

Description:

FT-445 fails high. PORV can be closed, but leaks by; block valve must be shut.

Time Pos. Expected Actions!Behavior Comments The above RNO actions may not be done here as the leak may not be noticed at this time.

RO (step 4) IF an alarm was caused by an Closes block valve 8000A CONTROL instrument (PT-444/445) OR component failure, THEN perform the following as required to restore RCS pressure to desired value.

- Take manual control of PORVs, Block valves, Pressurizer heaters and_spray.

SRO (step 5) Determine NO protection instrument failure occurred.

RO (step 6) References required Technical Specifications 3.4.1 for DNBR limits RCS pressure < 2209 psig CONDITION A 3.4.11 for PORVs Conditions A TECHNICAL SPECIFICATION 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified in the COLR. The minimum RCS total flow rate shall be 263,400 GPM when using the precision heat balance method, 264,200 GPM when using the elbow tap method, and the limit specified in the COLR SRO CONDITION REQUIRED ACTION COMPLETIO N TIME A. One or A.1 Restore RCS DNB more RCS parameter(s) to within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNB limit.

parameters not within limits.

TECHNICAL SPECIFICATION 3.4.11, Pressurizer Power Operated Relief Valves (PORVs)

Each PORV and associated block valve shall be OPERABLE 4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 2 Page 5 of 42 Event

Description:

FT-445 fails high. PORV can be closed, but leaks by; block valve must be shut.

Time Pos. Expected Actions/Behavior Comments SRO CONDITION REQUIRED ACTION COMPLETIO N TIME A. One or A.1 Close and maintain 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months more PORVs power to associated inoperable block valve.

and capable of being manually cycled.

SRO (step 7) Notify the Shift Manager SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO (step 10) IF the pressurizer PORVs operated, THEN perform the following:

. Refer to SOP-i .2, Reactor Coolant Pressure Relief System, for cooldown of the PRT

. Refer to SOP-O.O, General Instructions To Operations Personnel, for reporting requ rem ents At the discretion of the Lead Examiner move to Event #3.

5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 3 Page 6 of 42 Event

Description:

1 E SW pump trips.

1 E SW pump will trip. SW pressure will lower but remain operable. 1 C SW pump is available to start and then tech specs evaluated.

Indications Available:

Annunciators: Recognize indications 1 E SW PUMP TRIP

- SW PRESS B TRN LO (AD5) - Yellow flag above 1 E SW pump handswitch

- SW PUMP TRIPPED (AE4) - Pl-3001A/B SW TO CCW HX PRESS,

- SW TO AUX BLDG HDR PRESS A OR B reading low TRN LO_(AE5)

Time Pos. Expected Actions/Behavior Comments Annunciator Response Procedure ARP-1.1, version 59, AE4 BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP BOP (step 1) Check Indications and determine 1 E SW pump has a yellow trip which SW pump tripped flag BOP (step 2) Start the 1 C SW pump SRO (step 3) Direct entry into AOP-1O, version 15 SRO (step 4) Direct SSS entry into SOP-24.O step 4.6 to align 1C SW pump for auto start to_replace_the 1 E SW_pump BOP (step 5) Dispatch personnel to the 1 E SW Sends SSS and Outside SO pump and breaker DLO4 AOP-1O, Loss of service Water, version 15, actions BOP (step 1) Verify DFO2 and DGO2 are closed BOP (step 2) Start any available SW pump BOP (step 3) Check pressure in both SW trains

>60 psig, then go to procedure and step in affect.

6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 3 Page 7 of 42 Event

Description:

1 E SW pump trips.

Time Pos. Expected Actions/Behavior Comments SRO (step 7 of ARP AE4) Refer to tech spec 3.7.8 for LCO requirements TE : CHNICAL SPECIFICATION 3.7.8 Service Wa I:er System (SWS)

Two SWS trains shall be OPERABLE.

3.7.8 Condition A applies due to the 1 E SW pump being tripped and the 1C SW pump not being selected to auto start for the 1 E SW pump CONDITION REQUIRED COMPLETION ACTION TIME A. One SWS A.1 -NOTES 72 days train 1. Enter inoperable. applicable Conditions and Required Actions of LCO 3.8.1, AC Sources Operating, for emergency DG made inoperable by SwS.

Restore SWS train to OPERABLE status.

1 ECHNICAL SPECIFICATION 3.8.1 3 AC SourcesOperating SRO From 3.7.8 Condition A above, 3.8.1 has to be entered. Since the 1-2A DG is Tagged out and since the B Train SW is Inoperable, Condition E, Two DG sets INOP is required to be entered. The second statement applies to have one DG set restored in 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

SRO CONDITION REQUIRED COMPLETION ACTION TIME E. Two DG sets El Restore one 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months if all three inoperable DG set to DGs are inoperable OPERABLE OR status. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months if DG 1-2A l-2A DG is tagged out and lB DG and DG 1(2)B are inoperable is inoperable due to the SW OR system being inoperable.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months if DG 1C and DG 1(2)8 are inoperable 7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 3 Page 8 of 42 Event

Description:

I E SW pump trips.

Time Pos. Expected Actions/Behavior I Comments SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry After Tech Spec analysis and at the discretion of the Lead Examiner move to Event #4.

Tech Spec analysis may be done at the end of the scenario.

8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 4 Page 9 of 42 Event

Description:

FT-485, CH IV 1 B SG Steam Flow transmitter, fails low FT-485 will fail low. 1 B FRV will close and SG NR level will decrease.

Indications Available:

Annunciators: Recognize indications of FT-485 failing low:

- lB SG FEED FLOW > STM FLOW (JG2) - FT-485 fails low slowly meter slowly

- 1BSGLVLDEV(JF2) dropping to 0

- FRV position closing

- 1BSG NRlevelj.

Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, version 10 SRO Direct entry into AOP-100 and complete NOTE: Step 1 is an IDA step immediate operator actions RO (step 1) Maintain SG levels at 65%. NOTE: Step 1 is an Immediate IF required, THEN, take manual control of Operator Action and a SGFP speed control as necessary to restore continuing action step SG level to 65%

- SGFP master controller SK-509A OR

- SGFP individual controllers as needed.

[ 1 SK-509B

[ I SK-509C IF required, THEN take manual control of the affected feedwater regulating valves

[j 1A SG FW FLOW FK-478

[] 1 B SG FW FLOW FK-488

[j 1C SG FW FLOW FK-498 SRO If a loss of main feedwater occurs, then This should not result in a loss perform the actions of AOP-13, Loss of Main of MFW Feedwater 9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 4 Page 10 of 42 Event

Description:

FT-485, CH IV 1 B SG Steam Flow transmitter, fails low Time Pos. Expected Actions/Behavior Comments SRO (step 2) If an adverse trend in SG level Trip criteria expected:

exists, then establish Trip Criteria - Rx trip on low SG level 28%

- Main Turbine and Feed Pump Trip @ 82% SG level BOP (step 3) IF a ramp is in progress, THEN place Turbine on HOLD SRO/ (step 4) Determine if an instrument failure FT-485 has failed low BOP has occurred.

Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW SIG CH Ill CH IV CH Ill CH IV A S/G Fl-474 Fl-475 Fl-477 Fl-476 B S/G Fl-484 Fl-485 Fl-487 Fl-486 C SIG Fl-494 Fl-495 Fl-497 Fl-496 Check for failed or erroneous readings on the following SG pressure indicators S/G CHII CHIlI CHIV A S/G P1-474 P1-475 P1-476 B S/G P1-484 P1-485 P1-486 C S/G P1-494 P1-495 P1-496 S RO/ IF the alarm(s) was due to a SGWLC System BOP controlling channel failure, THEN select the unaffected channel and verify proper system response Places switches FS1488Z and FS/488Y for BOP will verify proper system lB SG in the III position: FT-484 (STM Flow) response

& FT-487 (FEED Flow)

SRO (step 5) Refer to Tech Specs 3.3.2 for any LCO requirements.

T.S. 3.3.2 Condition D applicable 10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 4 Page 11 of 42 Event

Description:

FT-485, CH IV lB SG Steam Flow transmitter, fails low Time Pos. Expected Actions/Behavior Comments I I TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 2e High steam flow in two steam lines coincident wI b-b Tavg Applicable in Modes 1, 2 and 3 with MSIVs open required channels 2 per stm line condition D CONDITION REQUIRED ACTION CQMPL ETION TIME D. One channel D.1 NOTE inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs SRO (step 6) Notify the Shift Manager (step 7) WHEN plant conditions permit, THEN return systems to automatic control.

SRO (step 8) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

At the discretion of the Lead Examiner move to Event #5.

11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 5 Page 12 of 42 Event

Description:

125 gpm RCS leak develops A 125 gpm RCS leak will develop. This will cause entry into AOP-1.O and take subsequest actions.

Indications Available:

Annunciators: Indications of an RCS leak:

- CHG HDR FLOW HI-LO (EA2) - Li-i 1 2B and 1 15, VCT LVL, decreasing

- RMS HI RAD (FH1) - Fl-122, CHG FLOW increasing

- LT-459, PRZR LEVEL, decerasing Time Pos. Expected Actions/Behavior Comments AOP-1.0, RCS LEAKAGE, ver. 2C .0 SRO Directs performance of ARP5

- A2, CHG HDR FLOW HI-LO

- FH1, RMS HI RAD (R-2, 7, & 12: CTMT radiation alarms_in)

BOP Closes minipurge supply and exhaust fan Per FH1 if R-i1 or 12 is in dampers and stops the ctmt minipurge fans. alarm RO Reports pressurizer level is dropping with charging maximum.

Should diagnose and announce ACS leak.

SRO Directs entry into AOP-i and directs actions per nO & BOP rows below:

RO (step 1) Maintain pressurizer level stable at NOTE: This is a continuing or near programmed level by: action step Control charging flow: Take manual control of OR charging flow Reduce letdown flow OR remove 1 orifice Isolating letdown remove all orifices 12

Appendix D Operator Action Form ES-D-2 Op Test No.: FP2O113O1 Scenario # 5 Event # 5 Page 13 of 42 Event

Description:

125 gpm RCS leak develops Time Pos. Expected Actions/Behavior Cornments RO (step 2) Maintain VCT level > 20% NOTE: This is a continuing action step

- Ensures Reactor makeup is in AUTOMATIC to maintain VCT level> NOTE: RMU is in AUTO 20%

- RNO- if VCT level cannot be maintained Q1E21LCV115B open

>20%, then align chg pump suctions to Q1E21LCV115D open RWST and Q1E21LCV115C closed Q1E21LCV115E closed RO (step 3) Determine leak rate based on flow balance (charging flow)

÷ (seal injection flow)

- (letdown flow)

- (#1 seal leakoff flow)

= (RCS leak rate)

SRO (step 4) Leak rate should be determined to NOTE: This is a continuing be greater than 120 gpm. action step

- Tech Spec 3.4.13 should be evaluated> 1 LCO 3.4.13 Cond. A identified gpm unidentified leakage. as a MANDATORY LCO.

SRO (step 5) Informs Shift Manager of Leak rate NOTE: This is a continuing for classification and notification per EIP-8 & action step EIP-9.0

. need for CTMT entry to look for leak source

- T.S. requires fix leak in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or shutdown in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SRO (step 6) Directs Unit 2 UO or extra plant operator or SSS to align 1 A & 1 B post LOCA containment hydrogen analyzers for service using Attachment 1 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 5 Page 14 of 42 Event

Description:

125 gpm RCS leak develops Time Pos. Expected Actions/Behavior Comments RO (step 7) Frequently monitor CVCS flow balance as the actions of steps 7.2 through 7.12 are taken.

RO (step 7.2) Check LCV-115A in the VCT position SRO (step 7.3) Check containment sump level -

NOT RISING EXCESSIVELY Consult Shift Manager to evaluate NOTE: This is an RNO step requirement for containment entry BOP (step 7.4) Check containment radiation NOTE: CTMT radiation will be NORMAL elevated BOP (step 7 RNO) Evaluate placing CTMT sump NOTE: This is an RNO step pump handswitches in PULL-TO-LOCK to prevent overfilling the WHT.

Verify containment ventilation isolation

- Stop MINI PURGE SUPP/EXH FAN.

Verify containment mini purge dampers -

CLOSED.

- CTMTPURGEDMPRS MINI-2866C & 2867C

- CTMTPURGEDMPRS MINI-2866D & 2867D BOP (step 7.5) Check auxiliary building radiation -

NORMAL.

BOP (step 7.6) Check no SG tube leakage

- Check Secondary radiation NORMAL BOP (step 7.7) Checks COW radiation monitors (R 17AIB)

SRO (step 8) WHEN the RCS leakage source NOTE: This is a continuing identified, THEN take appropriate actions to action step isolate the leak.

14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 5 Page 15 of 42 Event

Description:

125 gpm RCS leak develops Time Pos. Expected Actions/Behavior Corn ments LCO 3.4.13 Cond. A is a MANDATORY LCO This is classified as unidentified leakage TE HNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; SRO CONDITION REQUIRED ACTION COMPLETION TIME A. RCS A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months operational within limits.

LEAKAGE not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

WHEN letdown is secured, LCV-1 1 5B and D opened and the ramp is either restarted or ramp rate increased and under control, THEN at the discretion of the Lead Examiner move to Event #6.

15

Appendix D Operator Acfion Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 16 of 42 Event

Description:

1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP.

1A RCP will experience HIGH vibrations. The call made to the Radside SO will confirm the alarm. The ARP will have the reactor tripped and the RCP secured.

Indications Available:

Annunciators: Indications of RCP hich

- RCP VIB TRBL (HH4) - Alarm indication only Pos. Expected ActionslBehavior Comments nnunciator Response Procedure ARP-1.8, version 35, HH4 SRO Directs ARP HH4 referenced RO (step 1) Monitor RCS flow, subcooling conditions and RCP run current to determine if low NPSH conditions exist.

(step 2) Monitor seal injection flow to insure a seal problem is not causing the increased vibration.

(step 3) Monitor RCP bearing temperatures.

RO (step 4) Dispatch appropriate personnel to NOTE: call made to Radside the 139 EPR to observe vibration monitoring SO equipment to determine affected pump, vibration level, and rate of increase.

SRO (step 5) Notify Westinghouse of vibration problem.

SRO (step 6) Check if shaft vibration is 15 MILS Report from field: 1A RCP AND the rate of increase in vibration vertical shaft is reading 16.3 exceeds 1 MIL per hour QE shaft vibration mils. Horizontal shaft is under any conditions exceeds 20 MILS reading 16.5 mils. rate of increase is approx. 1 mu every 5 minutes.

WHEN ransitioning to EEP-O.O AND at the Shift Supervisors direction, it is ACCEPTABLE for one team member to complete the Immediate Operator Actions of EEP-O.O. While the other team member verifies a Reactor Trip, THEN trips the appropriate RCP(s) before finishing the Immediate Operator Actions of EEP-O.O. (Al 2004200019) 16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 17 of 42 Event

Description:

1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP.

Pos. I Expected Actions/Behavior Comments SRO Direct the reactor trip and enter EEP-0.

Direct securing the 1A RCP and pertorm the actions of AOP-4.O as applicable.

AOl Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor NOTE: Reactor will trip trip bypass breakers OPEN.

- automatically if setpoint Check nuclear power FALLING.

- reached.

check rod bottom lights LIT. -

GOP Secures the 1A RCP.

- Shut the spray valve PK-444C AOP-4.0 actions

- Control AFW flow to the 1 A SG to prevent overfilling (step 2) Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit (step 3) Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F 41 60V bus) power available lights NOTE: NO DGs will be running lit at this point if manual safety OR injection has not been initiated.

B Train (G 41 60V bus) power available lights lit NOTE: The auto SI is Verify operating diesel generators are being blocked. This is a CRITICAL supplied from at least one SW pump. TASK to initiate a SI when parameters call for the SI.

(step 4) Check SI Status.

Check any SI actuated indication. - Ctmt pressure > 4 psig BYP & PERMISSIVE SAFETY INJECTION - Pzr pressure LOW < 1850

[1 ACTUATED status light lit psig

[] MLB-1 11 lit

[1 MLB-1 11-1 lit 17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 18 of 42 Event

Description:

1A RCP experiences high vibrations requiring a reactor trip and securing of the RCP.

Pos. Expected Actions/Behavior I CRITICAL TASK: WHEN Pzr level decreases to 4%, the FO page of ESP-O.1 says to Comments manually actuate at least one train of SI or when a SI setpoint is exceeded.

The Small Break LOCA of 400 GPM occurs when the 1A RCP is secured.

There is no ramp.

If SI criteria is NOT met at this time, then ESP-0.1 will be entered SRO IF SI is NOT required at this point, directs transition to ESP-O.1, REACTOR TRIP

RESPONSE

ESP-O.1 step 1 action below:

RO (step 1) Check RCS temperature NOTE: this is a continuing

- Stable at or approaching 547°F action step

- TAVG 1A(IB,1C) RCS LOOP

[1 TI 41 2D

[1 TI 422D STM DUMP

[]_TI 432D 18

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 19 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

The Small Break LOCA will come in at 400 gpm. The crew should see Pzr level decreasing and RCS pressure decreasing. When the safety injection is intiated then DGO2-1 for the 1 L 41 60V bus will trip open. This will result in a loss of SW to the 1 B DG and it will require an emergency shutdown. A Train Phase A will not work and 3 isolation valves on B Train will not close so the BOP will have to isolate ctmt.

Indications Available:

Annunciators: Indications of SB LOCA

- Various and numerous - Pzr level 4.

- RCS pressure 4.

- Radiation monitor 4. (R-2/7/1 1/12)

Time Pos. Expected ActionslBehavior Comments

. I If the safety injection is required at step 4 then these steps will be done again.

RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

Check nuclear power FALLING.

check rod bottom lights LIT.

(step 2) Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit NOTE: 3 DGs will be running (step 3) Check power to 4160 V ESF when the SI is initated busses. manually.

4160 V ESF busses AT LEAST ONE

- OATC will check SW header ENERGIZED pressure, ctmt cooler flows and CCW Hx SW flows and SW A Train (F 41 60V bus) power available lights pump lights.

lit For this event 4160V bus 1L OR de-energizes due to a B Train (G 4160V bus) power available lights tripped breaker and the RNO lit column used to shut down the lB DG per Attachment 1 Verify operating diesel generators are being supplied from at least one SW pump.

19

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 20 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments Attachment 1 SECURING A DIESEL GENERATOR WITH A SAFETY INJECTION SIGNAL PRESENT (step 1.1) Verify SI reset NOTE: Since the SI just came

[] MLB1 1-1 not lit in this takes 60 seconds before

[]MLB-1 11-1 not lit it will reset (step 1 .2) Place the 1 B DG MODE SELECTOR SWITCH to MODE 2.

(step 1.3) Depress the 1 B DG DIESEL EM ERG START RESET pushbutton.

(step 1.4) Depress the 1 B DG STOP pushbutton.

[] DIESEL STOP light lit (step 1.5) Place the 1 B DG MODE SELECTOR SWITCH to MODE 3.

(step 1.6) Depress the 1 B DG DIESEL EM ERG START RESET pushbutton.

Resume EEP-O actions RO/ (step 4) Check SI Status.

BOP Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[]MLB-1 1-1 lit

[] MLB1 1 11 lit SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to do attachment 2. CRITICAL TASKs are in Attachment 2 (step 6) Check containment pressure- HAS NOTE: [CA] step For a SB RO REMAINED LESS THAN 27 psig LOCA it is not anticipated to rise >27 psig 20

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 21 of 42 Event

Description:

SBLOCA (400 gpm), 41 60V bus 1 L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments RO (step 7) Announce Unit 1 reactor trip and safety injection.

RO (step 8) Check AFW status.

Check secondary heat sink Available o Check total AFW flow> 395 gpm

[} Fl 3229A

[] Fl 3229B

[) Ft 3229C o Total Flow Fl 3229 OR Check any SG NR level > 31% {48%}

WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.

WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

RO (step 8.4) WHEN SG narrow range level greater than 31 %{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.

. Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[] B TRN reset MDAFWPTO 1AJ1B/1C SG BTRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[1 RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted 21

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 22 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time I_Pos. Expected Actions/Behavior Comments RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR APPROACHING 547°F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[j TI 422D

[] TI 432D RD (step 9 RNO) IF RCS temperature less than NOTE: RNO column since 547°F and falling, THEN perform the RCS temp will be <547°F following.

(step 9.1.1) verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB

[1 Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG

[1 Fl 3229A

[j Fl 3229B

[1 Fl 3229C AFW TOTAL FLOW

[] Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.6. accomplish this task 22

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 23 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior I Comments RO (step 10) Check pressurizer PORVs and spray valves.

WHEN pressurizer pressure less than 2335 NOTE: [CA] step psig, THEN verify both PRZR PORVs closed.

Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.

[j PRT PRESS P1 472

[] PRT LVL Ll-470

[] PRT TEMP Tl-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray NOTE: [CA] step valves closed OR in the process of closing.

1A(1 B) LOOP SPRAY VLV

[1 PK444C

[]PK444D Check any PRZR PORV ISO OPEN -

RO (step 1 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16OF{45 F}

0 SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <

Control charging pump miniflow valves 1300 and open when> 1900 based on RCS pressure. psig.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[] P1 403A 23

OpTestNo.: FA2011301 Scenario# 5 Event # 7, 8 and 9 Page 24 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected ActionslBehavior Comments Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

SRO (step 13) Check SGs not faulted.

[1 Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

SRO (step 14) Check SGs not ruptured.

[] Check secondary radiation indication -

NORMAL.

[] Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D

[1 No SG level rising in an uncontrolled manner.

SRO (step 15) Check RCS intact. NOTE: Ctmt pressure will be Check containment radiation - rising and radiation monitors in

[1 R-2 CTMT 155 ft alarm

[1 R-7 SEAL TABLE

[1 R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

Transition to EEP-1.0

[J Check containment pressure LESS THAN 3 psig.

[1 Check containment ECCS sump level LESS THAN 0.4 ft.

EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT.

RO (step 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

24

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 25 of 42 Event

Description:

SBLOCA (400 gpm), 41 60V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments BOP (step 2) Check SGs not faulted.

Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP (step 3) Check intact SG levels.

Check any intact SG narrow range level GREATER THAN 31%{48%}.

NOTE: [CA] step WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31 %-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[1 B TRN reset MDAFWPTO 1AI1B/1CSG BTRN

[1 FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[1 RESET reset TDAFWP SPEED CONT

[1 SIC 3405 adjusted BOP (step 4) Check secondary radiation [] R-1 5 indication - NORMAL. [] 19 Checks rad monitors [1 23A and B

[1 15B and C,

[J 60A,B,C,D 25

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 26 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work Time Pos. Expected Actions/Behavior Comments RO (step 5) Check pressurizer PORVs Check any PRZR PORV ISO power available NOTE: [CA] step WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

[J Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[1 PORV Temp TI-463 Check PRT parameters STABLE or FALLING.

[] PRT PRESS P1 472

[] PRT LVL Ll-470

[] PRT TEMP TI-471

[] Check at least one PRZR PORV ISO -

OPEN SRO (step 6) Perform the following within 1 NOTE: These steps will be hour of start of event, passed off to the Shift

[] Close recirculation valve disconnects using Manager ATTACHMENT 1.

[] Establish 1A and 1 B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

[1 Plot hydrogen concentration on FIGURE 1.

Check containment hydrogen concentration

[] LESS THAN 3.5%.

[1 Less than 0.5%

26

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 27 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments SRO (step 7) Evaluate SI termination criteria

[1 Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

Check secondary heat sink available.

[1 >395 gpm AFW flow OR

[] > 31%{48%} SGNR level

[] Check RCS pressure STABLE OR RISING

[] Check pressurizer level GREATER THAN 1 3%{43%}.

Continue to step 8 since a known LOCA exists RO (step 8) Check containment spray system. NOTE: [CA] step Check any CS PUMP STARTED.

Reset containment spray signals.

CS RESET

[]ATRN

[1 B TRN NOTE: [CA] step WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , AND containment pressure is less than 16 psig, THEN stop both CS PUMPs.

NOTE: To ensure proper SI flow to the reactor, the RHR pumps must be manually restarted if they are secured and RCS pressure falls below 275 psig{435 psig}. Continuing Action Step 27

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 28 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments RO (step 9) Check if LHSI Pumps should be NOTE: [CA] step stopped.

- Check RCS pressure GREATER THAN 275 psig{435 psig}

[] PT-402 AND 403

- Check RCS pressure stable or rising

- RESETtheSI

[] MLB-1 1-1 not lit (A TRN)

[] MLB-1 1 1-1 not lit (B TRN)

- Stop BOTH RHR Pumps BOP (step 10) Check no SG pressure FALLING -

IN AN UNCONTROLLED MANNER.

RO (step 11) Check RCS pressure NOTE: Since this is a SB

[] PT-402 AND 403 LOCA pressure will be rising but the intent of this step is to If pressure is rising then return to step 1. continue on in the procedure.

BOP (step 12) Perform Attachment 4 to Verify 4160 V busses energized.

Check DFO1 closed YES Verify DFO2 closed - YES Check DG15 closed - YES Vertiy DGO2 closed - YES Verify all RCP busses - ENERGIZED.

[] lA4l6OVbus- YES

[] lB4l6OVbus- YES

[j 1C 4160 V bus- YES Check 1 E 41 60V busENERGIZED-YES Check 1D 4160V bus- ENERGIZED-YES 28

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 29 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus 1L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Corn ments BOP (step 13) Check diesel generators. NOTE: [CA] step Monitor any loaded diesel generator for NOTE: Securing unloaded proper voltage, frequency and load. DGS will be accomplished by the extra operator or the BOP Secure any unloaded diesel generators using if time permits. This is FNP-O-SOP-38.O, DIESEL GENERATORS. generally not the case and the DGs will continue to run.

SRO (step 14) Begin evaluation of plant status. NOTE: This is Foldout page Verify cold leg recirculation capability - criteria as well AVAI LABLE.

Train A equipment available:

[] 1A RHR Pump

[] CTMT SUMP TO 1A RHR PUMP 01 Eli M0V881 1A

[] CTMT SUMP TO iA RHR PUMP Q1E1 1M0V8812A

[1 1ARHR HXTOCHG PUMP SUCT 01 Eli M0V8706A

[] CCWTO1ARHRHX Qi P1 7M0V31 85A OR Train B equipment available:

[] lB RHR Pump

[] CTMT SUMP TO 1 B RHR PUMP Q1E11MOV8811B

[1 CTMT SUMP TO lB RHR PUMP Q1E1 1MOV8812B

[jiB RHRHXTOCHG PUMP SUCT 01 Eli MOV87O6B

[1 CCWTO1BRHRHX 01 P1 7MOV31 85B SRO (step 14.2) Direct extra operator to begin taking ECCS logs.

29

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 30 of 42 Event

Description:

SBLOCA (400 gpm), 4160V bus IL trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments SRO (step 14.2) Evaluate RCS sampling Notifies SM requirements.

Consult TSC staff to evaluate need for RCS sampling.

IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-0-CCP-1 300, CHEMISTRY AND ENVIRONMENTAL ACTIVITIES DURING A RADIOLOGICAL ACCIDENT SRO (step 14.4) Check no intersystem LOCA [] R-3 RADIOCHEMISTRY BOP outside CTMT. LAB

[1 Check auxiliary building radiation - [1 R-4 1C CHG PUMP RM NORMAL. {] R-5 SFP RM

[] R-6 SAMPLE RM AREA

[] R-8 DRUMMING STATION

[] R-10 PRF

[] R-17A OR R-17B CCW BOP [] Check auxiliary building room sumps HI - (on the GOP)

LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO.

Will call Radside SO

[] Check WHT and FDT levels -

NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

RO Check PI600A(B) 1A(1B) RHR PUMP DISCH PRESS LESS THAN 450 psig.

BOP (step 14.5) Verify at least one train of PRF in operation using EN P-i -SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

RO (step 14.6) Verify VCT level GREATER THAN 5%.

30

Op Test No.: FA2011301 Scenario # 5 Event # 7, 8 and 9 Page 31 of 42 Event

Description:

SBLOCA (400 gpm), 41 60V bus 1 L trips and Phase A on A Train does not work.

Time Pos. Expected Actions/Behavior Comments RO (step 15) Check LHSI flow in progress RCS pressure will be >435 Check RCS pressure LESS THAN

- psig 275 psig (435 psig}.

1C(1A) LOOP RCS NR PRESS

[1 P1 402B

[1 P1 403B Verify both LHSI flows GREATER

- LHSI flows will be> 1500 THAN 1 .5x10 3 gpm. gpm 1A(1B) RHR HDR FLOW RNO to transition to ESP

[}F1605A 1.2

[1 Fl 605B When the decision to transfer to ESP-1.2 announced, then terminate the exam.

31

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 32 of 42 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-0 Attachment 2 of EEP-O AUTOMATIC ACTIONS VERIFICATION Ti me Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train STARTED.

BOP []Atrain(lAorlB)amps>0

[] B train (1C or 1B) amps > 0 BOP (Step 2) Verify RHR PUMPs STARTED.

RHR PUMP

[] 1A amps >0

[] lB amps> 0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow GREATER THAN 0 gpm.

{] Fl 943 BOP (Step 3.2) Check RCS pressure LESS -

THAN 275 psig{435 psig).

BOP (step 3.3) Check LHSI flow greater than 1 .5 Xl gpm

[] 1A RHR HDR FLOW Fl-605A

[1 lB RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[1 A train (1A,1B or 1C)

[1 B train (1D,lEor 1C) 32

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 33 of 42 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -

STARTED.

(Step 5.1) Verify one CCW PUMP in each train- STARTED.

A train HX 1 C or 1 B CCW FLOW

[1 Fl 3043CA > 0 gpm OR

[] Fl 3043BA> 0 gpm B train HX lAor lB CCW FLOW

[1 Fl 3043AA> 0 gpm OR

[] Fl 3043BA> 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[1 Qi P1 6F13009AA > 0 gpm

[1 Qi P1 6F13009BA> 0 gpm

[] Q1P16FI3009CA >0 gpm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[1 1A

[] 1 B

[1 1C Check INST AIR PRESS P1 4004B greater than 85 osig.

33

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 34 of 42 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[j 3196

[1 3198A

[] 3198B Verify containment mini purge dampers -

CLOS ED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[1 2866D

[1 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 34

OpTestNo.: FA2011301 Scenario# 5 Event# 6 Page 35 of 42 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions!Behavior Corn ments BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[J 1A

[] 1 B B train

[1 1C

[] 1 D Verify associated emergency service water outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[1 Qi P1 6M0V3024A

[1 Q1P16MOV3O24B

{] Qi P1 6M0V3024C

[] Qi P1 6M0V3024D BOP (step 8) Verify AFW Pumps STARTED.

Verify both MDAFW Pumps STARTED

[] 1A MDAFW Pump amps> 0

[1 lB MDAFW Pump amps>0 AND

[1 FI-3229A indicates > 0 gpm

[1 FI-3229B indicates > 0 gpm

[1 Fl-3229C indicates > 0 gpm 35

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 36 of 42 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Lr:flTfltS (Step 8.2) Check TDAFW Pump start required.

D Condition LZiTSLB ElSetioint ECoincidence E RCP Bus TSLB2 1-1 :2680 V 1/2 Detectors Undervoltacie 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1 ,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3 BOP (step 8.3) Verify TDAFWP started.

[1 MLB-4 1-3 lit

[1 MLB-4 2-3 lit

[1 MLB-4 3-3 lit TDAFWP SPEED

[1 SI 341 1A> 3900 rpm TDAFWP SPEED CONT

[1 SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[1 Q1N23HV3228A in MOD

[1 Q1N23HV3228B in MOD

[1 Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C) SG FLOW CONT

[1 HIC 3228AA open

[] HIC 3228BA open

[1 HIC 3228CA open 36

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 37 of 42 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Corn ments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

1A(1B,1C) SG FW FLOW

[1 FCV 478

[] FCV 488

[] FCV 498 Verify both SGFPs TRIPPED.

Verify SG blowdown ISOLATED.

1A(1B,1C) SGBD ISO

[1 Q1G24HV7614A closed

[] Q1024HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[1 MLB1 1 9-3 lit Qi P1 5HV3329 closed

[] MLB1 19-4 lit Q1 P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% /2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt_press_>16.2_psig 2/3 TSLB1_2-2,3,4 37

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 38 of 42 Event

Description:

Attachment 2 of EEP-O Ti me Pos. Expected Actions/Behavior Comments (Step 11) Verify PHASE A CTMT ISO. RNO (Step 11.1) Verify PHASE A CTMT ISO - Step 11.2 Verify PHASE A ACTUATED. CTMT ISO alignment using BOP [1 MLB-2 1-1 lit ATTACH 3, PHASE A CTMT

[] MLB-2 11-1 lit ISO CRITICAL TASK: to actuate 1 1.2 Check all MLB-2 lights - LIT. A Train phase A or close MO V-81 00, HV-8152 and HV 3376 BOP (step 12) Check all reactor trip and reactor trip bypass breakers OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11EOO5A

[1 N1C11EOO5B 38

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 39 of 42 Event

Description:

Attachment 2 of EEP-O Time p Expected Actions/Behavior Comments BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[1 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[1 1 B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO Actions Following A Reactor Trip Or accomplish this.

Safety Injection.

BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRAGS Mode Selector Switch

[] A TRAIN

[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator GOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810- OPEN

[j 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2 39

OpTestNo.: FA2011301 Scenario# 5 Event# 6 Page 40 of 42 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected ActionslBehavior Attachment 4 I Comments TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DFO1 closed

{] Verify DFO2 closed

[1 Check DG15 closed

[] Verfiy DGO2 closed

{] Verify two trains of battery chargers energized Amps > 0 (Step 1 .6) Verity two trains of ESF equipment aligned.

[1 Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

CHG PUMP D!SCH HDR ISO

[1 Q1E21MOV8132A

[j Q1E21MOV8132B

[1 Q1E21MOV8133A

[] Qi E21 MOV81 33B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV813OA

[] Q1E21MOV813OB

[J Q1E21MOV8131A

[] Q1E21MOV8131B 40

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 41 of 42 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected Actions/Behavior Comments (Step 1.7) Verify all post accident containment air mixing system fans STARTED. (BOP)

POST ACCIDENT MIXING FAN

[1 1A

[] lB

[1 1C

[] 1 D RX CAV H2 DILUTION FAN

[] 1A

[] lB (Step 1.8) WHEN power restored to any de energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 41

Op Test No.: FA2011301 Scenario # 5 Event # 6 Page 42 of 42 Event

Description:

Attachment 4 of EEP-1.O Time Pos. Expected Actions/Behavior I Comments Attachment 4 VERIFYING 4160 V BUSSES ENERGIZED (Step 1) Verify 4160 V busses energized.

[1 Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[1 Verfiy DGO2 closed

[] Verify ALL RCP busses energized

- 1A, 1B, 1C416OVBus

[] Verify 1 DIE busses energized (step 1.13) Verify instrument air aligned to containment. (BOP)

IATO PENE RM

[] N1P19HV3825 open

[] N1P19HV3885 open IA TO CTMT

{] Q1P19HV3611 open End of Attachment 4 42

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA201 1-30 1 Page 1 of 4 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

AssiQn ojeratinp Dositions.

Ask for and answer questions.

ADDendix D Crew Briefln sheet Form ES-D-2 Op-Test No.: FA2O1 1-30 1 Page 2 of 4

[X]Unitl [ JUnit2 Shift: Date Off-going SS I Oncoming SS j [ N [XID Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, 5, D, SW, X on key ring. SS Unit 95% power, 59 ppm Cb, EOL, 19,000 MWD/MTU Status Xenon is building in. Ramp is on HOLD for turnover.

STPs!Evolutions: I B Train On-Service B Train Protected 1.0_; 109.1 Noadj.; 63.7; FSP-20,0 Status of Special Testing General Information MK5 is in alarm. Aamp was in progress at 2 MW/mm. Increase the ramp rate to 5 MW/mm to be in mode 3 in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months oer the direction of the Shift Manaaer.

2. The Makeup line has water in it.

3. The crew is in UOP-3.1, ver 107, at step 8.3. The Impulse Loop is in service.

4. The seismic printout has been obtained and an ALERT assification has been declared. Emergency callout has just been performed. MK5 actions are in progress. The plant walk downs are complete and no equipment damage has been discovered.

5. 1 -2A DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

6. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

7. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia

8. Current Risk Assessment is and projected is GREEN 9.

Equipment Status 1-2A DG Tagged out lB EHC pump is tagged out Maintain VCT gas pressure 25-30 p5mg Reactivity Plan Waste Management Status 10 gallon borations as needed for reactivity control. #3 RHT On Service See reactivity sheet. WGS secured LCO Status 3.8.1 condition B, STP-27.1 completed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X]Yes [X]Yes [X]Yes [X]Yes [X]Yes [X]Yes

RESPONSE SPECTRA ANALYSIS FOR SAA-3 RECORDER A (S/N 31281) EVENT A001 EVENT DATE: 11/13/2001 17:38:32, FREEFIELD SELECTED EXCEEDANCE CRITERIA: OBE SV, CAV and OBE PSA SPECTRA CHANNEL 1: L=S Computed CAV = 0.0 17 g-s, CAV Design Limit = 0.000 g-s CAV EXCEEDED***

OBE Limit Value = 0.050 g, OBE SV Limit = 0.08 1 mIs. Damping = 0.050 Spectral acceleration exceeded OBE design criteria at 6 periods Spectral acceleration greater than 2/3 OBE design criteria at 1 periods Spectral velocity exceeded OBE design criteria at 0 periods.

CHANNEL 2: V=UP Computed CAV = 0.0 10 g-s, CAV Design Limit 0.000 g- s CAV EXCEEDED***

OBE Limit Value = 0.033 g, OBE SV Limit = 0.054m/s. Damping = 0.050 Spectral acceleration exceeded OBE design criteria at 7 periods Spectral acceleration greater than 2/3 OBE design criteria at 1 periods Spectral velocity exceeded OBE design criteria at 0 periods CHANNEL 3: T=W Computed CAV = 0.0 16 g-s, CAV Design Limit = 0.000 g-s CAV EXCEEDED***

OBE Limit Value = 0.050 g, OBE SV Limit = 0.08 1 rn/s. Damping = 0.050 Spectral acceleration exceeded OBE design criteria at 9 periods Spectral acceleration greater than 2/3 OBE design criteria at 1 periods Spectral velocity exceeded OBE design criteria at 0 periods

OBE CRITERIA HAS BEEN EXCEEDED *

Both CAV & at least one of OBE response spectral *

acceleration or spectral velocity criteria must be *

exceeded to trigger OBE alarm.

Spectral Acceleration Design Values vs. Measured Values (units=g)

indicates OBE design exceeded, + indicates >2/3 DEE design value Period Ch. 1 Ch. 2 Ch. 3 Ch. 4 (sec) Design Meas. Design Meas. Design Meas. Unused 0.030 0.050 Q773* 0.033 0.583* 0.050 0.963*

0.033 0.050 0.689* 0.033 0.461* 0.050 0.792*

0.040 0.050 0.289* 0.033 0.357* 0.050 Q334*

0.050 0.050 0.279* 0.033 0.267* 0.050 Q475*

0.067 0.050 0.190* 0.033 0.164* 0050 Q343*

0.083 0.053 0.138* 0.033 0.116* 0.053 0.248*

0.100 0.060 0.525* 0.044 0.210* 0.065 0.435*

0.125 0.085 0.471* 0.057 0.138* 0.085 0.343*

0.150 0.105 0.664* 0.070 0.088* 0.105 0.419*

0.200 0.105 0.606* 0.070 0.055+ 0.105 0.384*

0.250 0.105 0.753* 0.070 0.034 0.105 0.412*

0.333 0.105 0.730* 0.070 0.017 0.105 Q*435*

0.400 0.105 0.462* 0.070 0.018 0.105 0.277*

0.500 0.105 0.202* 0.070 0.008 0.105 0.137*

0.667 0.080 0.233* 0.054 0.004 0.080 0.172*

0.800 0.065 0.192* 0.044 0.004 0.065 0.124*

1.000 0.052 0.000 0.035 0.003 0.052 0.069*

Spectral Velocity OBE Design Values vs. Calculated Values (units = m/s)

indicates OBE design exceeded Period Ch. 1 Ch. 2 Ch. 3 Ch. 4 (sec) Design Design Design Meas. Unused Meas. Meas.

0.500 0.081 0.032 0.054 0.019 0.081 0.044 0.540 0.081 0.036 0.054 0.017 0.081 0.043 0.583 0.081 0.037 0.054 0.016 0.081 0.043 0.630 0.081 0.035 0.054 0.017 0.081 0.044 0.680 0.081 0.031 0.054 0.019 0.081 0.046 0.735 0.081 0.026 0.054 0.022 0.081 0.048 0.794 0.081 0.021 0.054 0.025 0.081 0.051 0.857 0.081 0.017 0.054 0.027 0.081 0.053 0.926 0.081 0.019 0.054 0.029 0.081 0.055 1.000 0.081 0.024 0.054 0.030 0.081 0.055

Appendix D Scenario Pre-sets Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: FA2O1 1-301 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 2C DG T/C for governor work. (QOS 2 days, ETR 4 hrs)

. 1 B EHC pump TIC for motor bearin replacement. (OOS 6 hrs, ETR 2 hrs)

. Current Risk Assessment is EE and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 1 I (RO) LT-1 15, VCT level controller, fails high.

2 2 I (RO) LT-460, pressurizer level, fails low, letdown secures TS (SRO) TS 3.3.1 N (PC) Restore Letdown 3 R (PC & Bus duct cooling alarm, NC5, ramp unit to <13,500 amps in 45 BOP) minutes. Fast ramp required AOP-17 entry 4 3 I (BOP) FT-495, selected steam Flow Transmitter for 1C SG fails high TS (SRO) Tech Spec 3.3.2.D 5 4 C (BOP) 1 B SGFP speed oscillation and subsequent controller failure, plant ramp down required to remove the 1 B SGFP from service.

6 5 1 B SGFP Trips when <540 MW M (ALL) 1A SGFP trips 180 seconds later, Man Rx trip required 7 6 C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. (CT)

The turbine will not trip in auto or manual, closing GVs in manual 7 C (BOP) required. (CT) 8 8 M (ALL) LBLOCA when Unit One Reactor Trip is announced Terminate in EEP-1 .0 when transition to ESP-1 .3 announced.

(N)ormal, (R)eactivity, (l)nstrunent, (C)omponent, (M)ajor Changes in BLUE Removed one critical task b/c it was not a critical task in this scenario.

Rearranged order of events 2, 3 and 4.

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: FA2OI 1 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 2C DG TIC for governor work. (DOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearin replacement. (005 6 hrs, ETR 2 hrs)

. Current Risk Assessment is G and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

1 1 I (RO) LT-1 15, VCT level controller, fails high.

2 2 I (RO) LT-460, pressurizer level, fails low, letdown secures TS 3.3.1 TS (SRO)

Restore Letdown N(RC) 3 P (AC & Bus duct cooling alarm, NC5, ramp unit to <13,500 amps in 45 minutes. Fast BOP) ramp required ACP-17 entry 4 3 I (BCP) FT-495, selected steam Flow Transmitter for 1 C SG fails high Tech Spec TS (SRO) 3.3.2.D 5 4 C (BOP) 1 B SGFP speed oscillation and subsequent controller failure, plant ramp down required to remove the 1 B SGFP from service.

6 5 1 B SGFP Trips when <540 MW M (ALL) 1A SGFP trips 180 seconds later, Man Rx trip required 7 6 C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. (CT)

The turbine will not trip in auto or manual, closing GVs in manual required. (CT) 7 C(BCP) 8 8 M (ALL) LBLCCA when Unit One Reactor Trip is announced Terminate in EEP-1 .0 when transition to ESP-1 .3 announced.

(N)ormal, (R)eactivity, (Dnstrument, (C)omponent, (M)ajor

Appendix D Scenario Pre-sets Form ES-D-1 0 0 Tag out 1 B EH pump CMFmalf I cmshfpb_cp2 0 0 1 a crdm set fails to trip:

CMFmalf I c52MGA_cr3 0 0 rx trp bkr a fails to open CMFmalf I cBKRXTRP_cc2l I closed 0 0 rx trp bkr b fails to open CMFmaIf I cbkrxtrp_cc22 closed 0 0 Prevent AUTO trip of main turbine MALF / T / MAL-TUR2 0 0 Prevent Manual trip of main turbine MALE I T / MAL-TUR24 0 0 1A SGFP trips when lB SGFP trips trigi 180 delay Trigger 1 MaIf I imf mal-fwml la (1 180) 0 0 1 B SGFP trips 80 seconds after reaching 540 MW Trigger 2 Malfl imf mal-fwml lb (2 80) 0 0 2C DG output breakers racked out CMFmalf I cBKl DJO6_d_cpl CMFmalf I cBK2DJO6_d_cpl Triggers and Commands 0 0 Event Trigger 1: trig 1 activates on 1 B SGFP trip

Event: jmfwmllb 0 0 Event Trigger 2: activate on 540 MW to trip the 1 B SGFP

Event: trgset 2 mw < 540

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 100% power, MOL, 10,000 MWD, RCS boron concentration is 812 ppm, and Eq. Xe (-2726 ppm)

Turnover:

2C DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is C and projected is

B Train On-Service B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-1 15, VCT level controller, fails high.

Verifiable actions: LCV-1 1 5A must be swapped to VCT position and Makeup will be in manual vs automatic.

Event 2 LT-460 fails low, letdown secures. AOP-1 00 TS 3.3.1 Verifiable actions: RO Must take manual control of Charging to maintain pressurizer level less than tech spec (63.5%). This is the action given credit for whether or not letdown is restored.

Event 3 Bus duct cooling alarm, NC5, ramp unit to <13,500 amps in 45 minutes (<63% power).

Fast ramp required AOP-17 entry. Normal 100% amperage is approx. 22,500 amps.

Verifiable actions: RO uses boration and/or rods, BOP operates DEH to set in ramp rate, target, initiate and stop ramp as necessary.

Event 4 FT-495, selected steam Flow transmitter for C SG fails high.

Verifiable actions: Take manual control of the 1C FRV and then select channel Ill instruments to control 1C SG functions. AOP-100, Tech Spec 3.3.2.D Event 5 During the ramp, lB SGFP develops a speed oscillation, its controller can be shifted to manual but it has no affect. The ramp down should continue to remove the lB SGFP from service. The controller will fail low after 3 minutes and AOP-13 entered to remove the SGFP from service. 1 B SGFP will trip when 540 MW is reached and the plant is stable.

Verifiable actions: place controllers for the 1A SGFP and/or FRV5 in manual as necessary to control SG Levels. Manual Fast action ramp to <540 MW to remove the 1 B SGFP from service. Trip the lB SGFP manually.

Event 6 The 1 B SGFP trips first. The team should use guidance of AC P-i 3 and attempt to reduce load to 540 MW.

Both SGFPs trip. The 1 A SGFP will trip requiring the crew to manually trip the reactor per AOP-i 3.

Event 7 The reactor does not trip using either Rx trip switch. The team should attempt to open MG set breakers. The 1A MG breaker will not open. The team should enter FRP-S.i and insert rods in manual or auto (RO) (CT)

The main turbine will not trip in auto or manual, so the team will close governor valves to trip the turbine (BOP) and then emergency borate (PC or BOP) (CT) (Within 10 minutes following attempts to insert control rods by opening CRDM MG breakers)

Event 8 LBLOCA when Unit One Reactor Trip is announced.

Terminate in EEP-i .0 when transition to ESP-1 .3 announced.

Farley May 2011 exam Page 3 of 5

Appendix D Scenario detailed summary sheet Form ES-D-1 ARP/ UOP-3.1/ AOP-1 00/ AOP-13/ AOP-1 7/ AOP-1 3/ FRP-S.1/ EEP-0/ EEP-1 .0 Farley May 2011 exam Page 4 of 5

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET Insert negative reactivity into the core by at least one of the following methods before completing the immediate action steps of FRP-S.1: (WOG CT FR-S.1 - - C) (PRA -

NR:16, 21,23,27)

Transition to FRP-S.1 and insert negative reactivity by:

(1) Insertion of rods in auto or manual at >= 48 SPM w/in 1 minute following attempts to insert control rods by using reactor trip hand switches or opening MG set breakers (2) Commencing an emergency boration w/in 10 minutes following attempts to insert control rods by using reactor trip hand switches or opening MG set breakers (NOTE: Negative reactivity insertion using control rods should begin within 6 minutes of start of event with MEW inservice > 40% power, and 1 minute of start of event with no MEW > 40% power, and within 10 minutes if < 40% power.)

2.

Isolate the main turbine from the SGs before plant and scenario specific criteria is exceeded: (WOG CT FR-S.1 - - A)

Manually trip main turbine prior to SGs boiling dry SCENARIO Normal plant operation, degraded grid, a loss of all SGFPs, ATWT, followed by an OBJECTIVE! LBLOCA.

OVERVIEW:

The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-5.2, AOP-13, AOP-16, AOP-17 and AOP-100

Recognize the symptoms of an ATWT and implement the steps of FRP-S.1, EEP-0.0 & EEP-1 .0 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 8

2. Malfunctions after EOP entry (12) 2

3. Abnormal events (24) 4

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 2 Farley May 2011 exam Page 5 of 5

Scenario #4 FA2011301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #4 Validation time: 100 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approvat: Gary Ohmstede Date: 2/7/20 1 1 NRC Chief Examiner Ron AieIIo Date:

SOUTHERN COMPANY

Appendix D Scenario #4 Outline Form ES-U-i Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: 2011-301 Examiners: Operators: SAD RD BOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 2C DG TIO for governor work. (OOS 2 days, ETA 4 hrs)

. 1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETA 2 hrs)

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event Maif. Event Type* Event Description No. No.

1 1 I (RO) LT-i 15, VCT level controller, tails high.

2 2 I (RO) TS LT-460, pressurizer level, fails low, letdown secures (SRO) TS 3.3.1 N (RO) Restore Letdown 3 R (RO & BOP) Bus duct cooling alarm, NC5, ramp unit to <13,500 amps in 45 minutes. Fast ramp required AOP-i7 entry 4 3 I (BOP) TS FT-495, selected steam Flow Transmitter for 1C SG fails high (SRO) Tech Spec 3.3.2.D 5 4 C (BOP) 1 B SGFP speed oscillation and subsequent controller failure, plant ramp down required to remove the 1 B SGFP from service.

6 5 1 B SGFP Trips when <540 MW M (ALL) 1A SGFP trips 180 seconds later, Man Rx trip required 7 6 C (ALL) Ax Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FAP-S.i will be entered. (CT)

The turbine will not trip in auto or manual, closing GVs in 7 C (BOP) manual required. (CT) 8 8 M (ALL) LBLOCA when Unit One Reactor Trip is announced Terminate in EEP-1 .0 when transition to ESP-i .3 announced.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 13

Appendix D Scenario 4 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Base IC-74 MOL 100% power B Train on service 812 ppm boron Exam lC-214 RUN RUN simulator 0 0 Generic setup:

bat generic_setup_H LT.txt 0 0 Quick setup (all items with

are included):

bat 201 1 nrcexam_04.txt iI 0 0 Tag out 1 B EH pump CMFmalf I cmshfpb_cp2 0 0 1 a crdm set fails to trip:

CMFmaIf I c52MGA_cr3 0 0 rx trp bkr a fails to open CMFmaIf I cBKRXTRP_cc2l / closed 0 0 rx trp bkr b fails to open CMFmalf / cbkrxtrp_cc22 closed 0 0 Prevent AUTO trip of main turbine MALE / T / MAL-TUR2 0 0 Prevent Manual trip of main turbine MALE IT I MAL-TUR24 0 0 lA SGEP trips when lB SGFP trips trigi 180 delay Trigger 1 Malf I imf mal-fwmlla (1 180) 0 0 1 B SGFP trips 80 seconds after reaching 540 MW Trigger 2 Malf/ imf mal-fwml lb (2 80) 0 0 2C DG output breakers racked out CMFmalf I cBK1 DJO6_d_cpl CMFmalf I cBK2DJO6_d_cpl Triggers_and_Commands 0 0 Event Trigger 1: trigl activates on 1 B SGFP trip Event: jmfwmllb 0 0 Event Trigger 2: activate on 540 MW to trip the 1 B SGFP Event: trgset 2 mw < 540 Farley May 2011 exam Page 3 of 13

Appendix D Scenario 4 Simulator setup Form ES-D-1 MCB setup Place 1 B EH pump HS to STOP and HOLD Tag on HS 1 HOLD tag HS to STOP 20 DG Mode selector switch Place in Mode 3 Place HOLD Tag 2C DG MSS 1 HOLD TAG Place HOLD Tag on 2C DG output breakers DJO6-1 and 2 HOLD TAGS DJO6-2 DEH Clear DEH alarms Select POWER OPS PRIMARY on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared Turn Horns ON/OFF ann horn FREE2E simulator p

Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview I sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv simclock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 4 of 13

Appendix D Scenario 4 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam Verify Horns ON: hornflag HORNS ON = TRUE Turn Horns ON/OFF ann horn 1 2 LT-1 15, VCT level controller, fails high.

minutes lmf ltll5 10035 2 NRC LT-460, pressurizer level, fails low, letdown secures CUE imflt460025 Restore Letdown NRC Bus duct cooling alarm, NC5, ramp unit to <13,500 amps CUE in 45 minutes. Fast ramp required AOP-17 entry lmf nc5 1 Put FT 495 selected Steam Flow Transmtter for 1 C SO fails when hih g

power imf ft495 575 0 NRC 1 B SGFP develops an oscillation in its speed, its controller CUE cant be controlled in manual Run CAEP file: cae 1 B SGFP Speed Oscillation.cae oats(2) 6 preset 1 B SGFP Trips when <540 MW Trigger 2 1 A SGFP trips 180 seconds later, Man Rx trip required Trigger 1 Farley May 2011 exam Page 5 of 13

AQpendix D Scenario 4 Booth Guide Form ES-D-1 preset Ax Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

The main turbine will not trip in auto or manual, closing GVs in manual required.

8 When Unit One Reactor Trip is announced, put in LB LOCA oi imf mal-rcs2a NRC Terminate in EEP-1 .0 when transition to ESP-1 .3 CUE announced.

End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv_DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

g rpX.txt NOTE: Substitute grpX with grpl, grp2, orgrp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Farley May 2011 exam Page 6 of 13

Appendix D Scenario 4 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 3 minutes after Locally open reactor trip breakers requested CMFmaIf / cBKRXTRP_cc2l / open CMFmalf / cBKRXTRP_cc22 / open 7 WHEN REQUESTED TBSO:

I have locally tripped the main turbine.

MALF / T / MAL-TUR2 / DELETE MALE / T / MAL-TUR1 7or8 IF REQUESTED TBSO:

I have opened the condenser vacuum breaker isolation valves N1N51 V518A and 518B.

REMOTE! N21 / LOA-CFW012! 100 /20 sec ramp Farley May 2011 exam Page 7 of 13

Appendix D Scenario 4 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 8 WHEN REQUESTED SSS/RADSIDE:

I have performed steps 1 and 2 of attachment 1 of EEP-1 and need you to perform step 3 of attachment 1.

CAE ECCS_disc_delayed.cae 8 WHEN REQUESTED Unit Two UO; RESET RRE ALARM MH1 ANN / MH1 failoff Farley May 2011 exam Page 8 of 13

Appendix D Scenario 4 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

1 NONE expected 2 WHEN REQUESTED Work Week Coordinator:

Ill get the CR on LT-460 planned and worked.

Ill get I & C to place bistables in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

3 WHEN REQUESTED TBSO:

The Bus Duct Cooling fan belt is broke and the fan is NOT running.

SM:

I recommend ramping down to the amp limits for any one phase and be there in the next 45 minutes.

4 WHEN REQUESTED Work Week Coordinator:

Ill get the CR on FT-495 planned and worked.

Ill get I & C to place bistables in trip within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

5 PROVIDEIFCREW SM:

DECIDES NOT TO I do not like the current situation, I recommend ramping down to a RAMP power level that the SGFP is not needed. Need to ramp to at least at 5 MW/rn in.

WHEN REQUESTED TBSO:

The B SGFP is speeding up and slowing down. I cant tell why from out here. I dont see any other apparent problems.

Work Week Coordinator:

Ill get the CR on B SGFP controller planned and worked.

SM:

Yes, go ahead and reset C-7A interlock.

6 NONE expected SEE LOCAL OPERATOR ACTION PAGE for actions taken and provide the below feedback when requested 7 3 MINUTES AFTER ROVER:

REUESTED

[ensure trip bkrs are opened via buttons above under Local operator actions prior to the report]:

I have locally Opened Unit one Reactor Trip breakers Farley May 2011 exam Page 9 of 13

Appendix D Scenario 4 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

IF REQUESTED [ensure main turbine actions are completed via buttons above under Local operator actions prior to the report]:

TBSO:

I have locally tripped the main turbine.

[ensure Condenser vacuum actions are completed via buttons above under Local operator actions prior to the report]:

IF REQUESTED TBSO:

I have opened the condenser vacuum breaker isolation valves N1N51V518A and 518B 8 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SMISSS:

I will get someone to perform step 6 of EEP-1 I will get an extra operator to secure the 1 B DG ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

Farley May 2011 exam Page 10 of 13

Scenario 4 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 100% power, MOL, 10,000 MWD, RCS boron concentration is 812 ppm, and Eq. Xe (-2726 ppm)

Turnover:

2C DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

18 EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is

B Train On-Service B Train Protected.

and projected is ,

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-1 15, VCT level controller, fails high.

Verifiable actions: LCV-1 15A must be swapped to VCT position and Makeup will be in manual vs automatic.

Event 2 LT-460 fails low, letdown secures. AOP-1 00 TS 3.3.1 Verifiable actions: RO Must take manual control of Charging to maintain pressurizer level less than tech spec (63.5%). This is the action given credit for whether or not letdown is restored.

Event 3 Bus duct cooling alarm, NC5, ramp unit to <13,500 amps in 45 minutes (<63% power).

Fast ramp required AOP-17 entry. Normal 100% amperage is approx. 22,500 amps.

Verifiable actions: RO uses boration and/or rods, BOP operates DEH to set in ramp rate, target, initiate and stop ramp as necessary.

Event 4 FT-495, selected steam Flow transmitter for C SG tails high.

Verifiable actions: Take manual control of the 1C FRV and then select channel Ill instruments to control 1 C SG functions. AOP-1 00, Tech Spec 3.3.2.D Event 5 During the ramp, 1 B SGFP develops a speed oscillation, its controller can be shifted to manual but it has no affect. The ramp down should continue to remove the 1 B SGFP from service. The controller will fail low after 3 minutes and AOP-13 entered to remove the SGFP from service. 1 B SGFP will trip when 540 MW is reached and the plant is stable.

Verifiable actions: place controllers for the 1A SGFP and/or FRVs in manual as necessary to control SG Levels. Manual Fast action ramp to <540 MW to remove the 1 B SGFP from service. Trip the lB SGFP manually.

Event 6 The 1 B SGFP trips first. The team should use guidance of AOP-13 and attempt to reduce load to 540 MW.

Both SGFPs trip. The 1A SGFP will trip requiring the crew to manually trip the reactor per AOP-13.

Event 7 The reactor does not trip using either Rx trip switch. The team should attempt to open MG set breakers. The 1A MG breaker will not open. The team should enter FRP-S.1 and insert rods in manual or auto (RO) (CT)

The main turbine will not trip in auto or manual, so the team will close governor valves to trip the turbine (BOP) and then emergency borate (RO or BOP) (CT) (Within 10 minutes following attempts to insert control rods by opening CRDM MG breakers)

Event 8 LBLOCA when Unit One Reactor Trip is announced.

Terminate in EEP-1 .0 when transition to ESP-1 .3 announced.

Farley May 2011 exam Page 11 of 13

Scenario 4 detailed summary Appendix D Form ES-D-1 sheet ARP/ UOP-3.1/ AOP-1 00/ AOP-1 3/ AOP-1 7/ AOP-i 3/ FRP-S.1/ EEP-0/ EEP-1 .0 FarleyMay 2011 exam Page 12 of 13

Appendix D Scenario 4 Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Insert negative reactivity into the core by at least one of the following methods before completing the immediate action steps of FRP-S.1: (WOG CT FR-S.1 - -

C) (PRA NR:16, 21,23,27)

Transition to FRP-S.1 and insert negative reactivity by:

(1) Insertion of rods in auto or manual at >= 48 SPM w/in 1 minute following attempts to insert control rods by using reactor trip hand switches or opening MG set breakers (2) Commencing an emergency boration w/in 10 minutes following attempts to insert control rods by using reactor trip hand switches or opening MG set breakers (NOTE: Negative reactivity insertion using control rods should begin within 6 minutes of start of event with MFW inservice > 40% power, and 1 minute of start of event with no MFW >40% power, and within 10 minutes if <40% power.)

2. Isolate the main turbine from the SGs before plant and scenario specific criteria is exceeded: (WOG CT FR-S.1 - - A)

Manually trip main turbine prior to SGs boiling dry SCENARIO Normal plant operation, degraded grid, a loss of all SGFPs, ATWT, followed by an OBJECTIVE! LBLOCA.

OVERVIEW:

The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-5.2, AOP-13, AOP-16, AOP-17 and AOP-100

Recognize the symptoms of an ATWT and implement the steps of FRP-S.1, EEP-0.0 & EEP-1 .0 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 8

2. Malfunctions after EOP entry (12) 3

3. Abnormal events (24) 4

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 2 Farley May 2011 exam Page 13 of 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 1 Page 1 of 45 Event

Description:

LT-115, VCT level transmitter, fails HIGH.

LT-1 15 will fail high. This will cause the VCT to divert to the RHTs and the VCT level will decrease. Auto makeup will not start to refill the VCT.

Indications Available:

Annunciators: Recognize indications of LT-i 15 failing HIGH

- LTDN DIVERTED TO RHT-VCT LVL HI - LI-i 12, VCT level, decreasing (DF2)

- VCT LVL HI-LO (DF3)

Time Pos. j Expected Actions/Behavior I Comments

. I ARP-1.4, Annunciator Response Procedure, version 51, DF2 and 3 Sf0 Directs RO to perform Actions of DF2 RO (Step 1) Determine if level is high or low as indicated by LI-i 15 and LI-i 12B on the MCB.

- RO determines LI-i 15 is failed HIGH, goes to step 5 (step 5)

- Places VCT divert valve 1 i 5A in the VCT mode.

- Manually makeup for VCT level control in accordance with S0P-23 IF LI-i 15 has failed, THEN initiate steps to have the instrumentation repaired.

The following automatic actions are inhibited:

1) Auto VCT/RCS makeup

2) Auto opening of RWST to charging pump suction on VCT low level

3) Auto VCT outlet isolations closing on Ic VCT level SRO - Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

- Notify the Shift Manager When the WWC and SM informed and at the discretion of the Lead Examiner move to event #2.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 2 Page 2 of 45 Event

Description:

LT-460, pressurizer level, fails LOW, letdown secures PT-460 will fail LOW. This LT is channel II and is the secondary channel selected since the PRZR LVL CONT SWITCH is selected to the I/Il position. This will cause letdown to secure and AOP-iOO actions to be taken. Letdown will be placed back in service using AOP-iOO.

Indications Available:

Annunciators: Indications of LT-460 failing LOW

- PRZR LVL LO HTRS OFF LTDN SEC - Ll-460 failing low (HA3) - Backup Heater Breakers open

- PRZR LVL DEV LO (HB2) - P1-i 45 Ltdn HX outlet pressure

- PRZR HTR CONT TRBL (HD4) - LI-459A and 461 t

- Fl-122 charging flow j.

- FK-122 demand

- Fl-i 50 letdown flow goes to 0 gpm

- LCV-460 goes closed

- Ll-ii2B&Ll ii5VCTLevefJ.

Pos. Expected Actions/Behavior Comments

. Al )P-100, Instrumentation Malfunction, version 10, section 1.2 SRO Direct BOP to reference ARP5 BOP Performs actions of ARP5 (most probably addresses ARPs by priority HA3 first)

Checks indications and determine actual pressurizer level and pressure

. Verifies automatic actions have occurred (LCV-460 closed)

Informs SRO if an Instrument Failure has Occurred ARP directs entry into AOP-i 00.

HB2 (step 1) Place the Turbine on hold SRO SRO will direct entry to AOP-i00.

RO Determines and reports LT-460 failure to SRO 2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 2 Page 3 of 45 Event

Description:

LT-460, pressurizer level, fails LOW, letdown secures Time Pos. Expected Actions/Behavior Comments RO (step 1) Checks pressurizer level on or trending to program value. (PRZR level increasing)

RNO: manual control of charging flow taken

- FK-1 22 in manual and charging flow reduced RO (Step 2) Check RCP seal injection flows

- Adjusts SI flow to 6-13 gpm SRO/ (step 3) Determine if a PRZR level Determines Ll-460 failed low RO transmitter! indicator loop has failed.

Ll-459, LI-460, or LI-461 SROI (Step 3) IF selected PRZR level control RO channel failed THEN select and unaffected channel.

Controlling channel I I II is affected

- RO directed to select channel I I Ill on LS-459Z IF required THEN select an unaffected Channel 459 selected no channel on the PRZR level recorder control action required switch LS-459Y SRO/ (step 4) Check letdown in service nO - Orifice isolation valves one or more open HV-81 49A,B,C

- Flow indicated on Fl-i 50 Letdown NOT in service 3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 2 Page 4 of 45 Event Descnption: LT-460, pressurizer level, fails LOW, letdown secures Time Pos. Expected Actions/Behavior Comments RO (step 4 RNO) Establish normal letdown as follows:

- Verify closed all letdown orifice isolation valves

. HV-8149A

. HV-8149B

. HV-8149C

- Verify LP LTDN PRESS PK 145 in manual and demand adjusted to 50% or less. Action not required IF necessary THEN open LTDN LINE PENE RM ISOs HV-81 75A and B from PRIP.

RO - Verify open LTDN LINE CTMT ISO HV 8152

- Verify open both LTDN LINE ISO LCV 459 and 460

- Verify FK-122 in Man and establish required minimum charging flow for one orifice to be placed on service. (18 GPM)

- Open LTDN CRlF ISO 60 GPM HV 8149B or C to establish approx. 60 gpm letdown flow RO (step 5) Check letdown flow established:

- Check letdown flow indicated Fl-i 50

- Place PK-145 in auto.

. Verify that PK-145 set between 4.3-7.5 to maintain 260-450 psig letdown pressure Checks these indicators:

. Place PK-145 in Auto TI-116 VCT Temp Verify LTDN HX outlet temp maintained TI-143 Divert letdown HX temp at approximately 100°F. TI-144 CCW letdown HX temp SRO (step 6) Refer to Tech Specs 3.3.1 & 3.3.3 determine any LCO requirements.

Tech Spec 3.3.1. Condition M 4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 2 Page 5 of 45 Event

Description:

LT-460, pressurizer level, fails LOW, letdown secures Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System (RTS) Instrumentation The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

Table 3.3.1-1 Reactor Trip System Instrumentation Function 9 Pressurizer Water Level High

- Applicable in Mode 1 >P-7 3 reciuired channels condition_M SRO CONDITION REQUIRED ACTION COMPLETION TIME M. One channel NOTE inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

M.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M.2 Reduce THERMAL 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months POWER to < P-7 SRO (step 7) Notify Shift Manager RO (step 8) WHEN plant conditions permit THEN restore components to automatic control as follows:

Restore charging flow control to automatic per SOP-2.1, Chemical and Volume Control System Plant Startup and Operation SOP-2.1, version 118 actions section 4.6.2 RO (step 4.6.2.1)

- Place LK-459F, PZR LVL Controller, in manual

- Verify Pzr level is w/l 3% of setpoint as indicated on LR-459

- Manually adjust the output meter on LK 459F to equal the position of the meter pointer on CHG FLOW Fl-122A

- Place LK-459F in AUTO

- Place FK-122 in AUTO 5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 2 Page 6 of 45 Event Descnption: LT-460, pressurizer level, fails LOW, letdown secures Time Pos. Expected Actions/Behavior Comments Continue AOP-100 actions here RO (step 8) Restore control of pressurizer heaters:

- 1A PRZR HTR GROUP BACKUP

- lB PRZR HTR GROUP BACKUP

- 1D PRZR HTR GROUP BACKUP

- 1E PRZR HTR GROUP BACKUP (ARP HD4 Actions)

- Places 1C PZR HTR switch in OFF and then back to the ON position SRO (step 9) Submit a Condition Report for failed channel and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the Condition Report.

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

6

Appendix D Operator Action Form ES-D-2 FA2011301 Op Test No.: Scenario # 4 Event # 3 Page 7 of 45 Event

Description:

Bus duct cooling alarm, NC5, fast ramp NC5, GEN BUS CLG ALARM, will come into alarm. The report from the TB SO will be that the belt for the bus duct cooling system has broken. The ARP response is to ramp the unit to 13,200 amps wfi 45 minutes, which is less than 63% power. Normal 100% amperage is approx. 22,500 amps.

Indications Available:

Annunciators: Annunciators:

GEN BUS CLG ALARM (NC5) - GEN BUS CLG ALARM (NC5)

Time Pos. Expected Actions/Behavior Comments ARP-1.13,_VERSION_18 SRO (step 1) Notify the Dispatcher (GENCOMM) of the problem Request the SM to call PCC via SYSTAT.

BOP (step 2) call TBSO to determine the cause of NOTE:

the alarm. When information received that the Bus Duct Cooling fan belt is broke and the fan is NOT running then continue to step 3 SRO (step 3) Directs ramp to approx. 63% power If forced cooling is lost from using AOP-17 and UOP-3.1. the bus duct cooling fan then ramp down to 13,200 amps (AM 4077, 4078, 4079) w/i 45

- Call SM and SRC to inform of ramp minutes AOP-17 version 22 actions below RO (step 13) Verify rods are in AUTO or MANUAL as desired SRO (step 14) Contact Rx Engineering for fast ramp recovery recommendations 7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 3 Page 8 of 45 Event

Description:

Bus duct cooling alarm, NC5, fast ramp Time Pos. Expected Actions/Behavior Comments BOP (step 15) Reduce turbine load at desired rate in OPERATOR AUTO (DEH)

- Desired rate will be between 7 and 10 MW/mm On the DEH panel:

- Press SETPOINT

- Set desired TARGET

- Select desired RATE

- Verify the HOLD light is LIT.

- Press the GO pushbutton and ensure the GO light is LIT

- Ensure the Main Turbine starts to ramp UP, GVs start to open.

RO (step 16) RO will maintain Tavg w/i +/-5°F of Continuing action step Tref by adjusting rod position or boron concentration.

(step 17) RO will adjust rod position to maintain Delta I wIl limits SOP-2.3 version 56, steps below RO (Step 1.0) Borating per SOP-2.3 appendix B Version 56

. Set the boric acid integrator to the desired quantity NOTE: A continuous boration

. Adjust LTDN TO VCT FLOW LK 1 12 is allowed by appendix C setpoint as desired which maintains the BA

. M/U mode selector to STOP system lined up and the RO

. MKUP MODE SEL SWITCH to BOR will take the MSS to START

. MKUP MODE CONT SWITCH to START. each time a boration is (Step 1.6) Verify proper boration operation by required.

observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B opens.

BORIC ACID TO BLENDER FCV1 1 3A opens.

Boric acid flow is displayed on Fl-113 MAKEUP FLOW TO CHG/VCT.

8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 3 Page 9 of 45 Event

Description:

Bus duct cooling alarm, NC5, fast ramp Time Pos. Expected ActionslBehavior Cornments BC PI (step 18) Control secondary parameters Continuing action step RO - SG NR levels maintained at 65%

- Pzr level trending to or maintained on program

- Pzr pressure = to 2235 psig SRO (step 19) Check parameters w/l limits for Continuing action step continued operation

- PZR level >15%

- Pzr press > 2100 psig

- SG NR levels 35-65%

- Tavg 541 580°F

- Control bank LO-LO position clear (FE2)

- Delta I w/l limits RO (step 20) when power reduction completed Continuing action step then restore Tavg to programmed value SRO (step 23) Notify SRC of load change and sample requirements When power reduction to approximately 95% or less and when determined to be enough for Lead Examiner move to Event #4.

9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 4 Page 10 of 45 Event Descnption: FT-495, selected steam Flow Transmitter for C SG fails HIGH FT-495, selected steam flow transmitter for 1 C SG fails high. The team should select channel III instruments to control 1C SG functions. Team is expected to perform actions of AOP-100.

Indications Available:

Annunciators: Indications of FT-495 failing HIGH:

- 1C SG Stm Flow> Feed Flow (JB3) - FI-494 Steam Flow t

- MS Line HI Stm Flow Alert (JB4) - TSLB 4 1 8-4 LIT

- 1C SG LVL DEV (JF3) - 1C FRV FK-498 Demand

- Fl-497 & 496 Feed Flow 1C SG t

- 1C SG level Ll-494, 495, 496 t

- A&BSGlevel.

- SGFP speed t

- SGFP suction pressure Time Pos. Expected Actions/Behavior Comments A )P-100, Instrumentation Malfunction, version 10, section 1.5 BOP Announces Receipt of MCB Alarms May notice Fl-495 Failed High and inform SRO.

SRO Instructs BOP/RO to perform Immediate Operator Actions of AC P-i 00 BOP (step 1) Maintain SG levels at 65%. NOTE: Step 1 is an Immediate IF required, THEN, take manual control of Operator Action and a SGFP speed control as necessary to restore continuing action step SG level to 65%

. SGFP master controller SK-509A OR

. SGFP individual controllers as needed.

[]SK-509B

[] SK-509C IF required, THEN take manual control of the affected feedwater regulating valves

[] 1 A SG FW FLOW FK-478

[1 1BSG FW FLOW FK-488

[1 1 C SG FW FLOW FK-498 10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 4 Page 11 of 45 Event

Description:

FT-495, selected steam Flow Transmitter for C SG fails HIGH Time Pos. Expected Actions/Behavior Comments SRO If a loss of main feedwater occurs, then This should not result in a loss perform the actions of AOP-13, Loss of Main of MFW Feedwater SRO (step 2) If an adverse trend in SG level Trip criteria expected:

exists, then establish Trip Criteria

Rx trip on low SG level 28%

. Main Turbine and Feed Pump Trip @ 82% SG level BOP (step 3) IF a ramp is in progress, THEN place Turbine on HOLD SRO/ (step 4) Determine if an instrument failure FT-495 has failed high BOP has occurred.

Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW S/G CHIlI CHIV CHIlI CHIV A SIG Fl-474 Fl-475 Fl-477 Fl-476 B S/G Fl-484 Fl-485 Fl-487 FI-486 C SIG Fl-494 FI-495 Fl-497 Fl-496 Check for failed or erroneous readings on the following SG pressure indicators S/G CHII CHIlI CHIV A S/G P1-474 P1-475 P1-476 B SIG P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496 SRO/ IF the alarm(s) was due to a SGWLC System BOP controlling channel failure, THEN select the unaffected channel and verify proper system response Places switches FS1498Z and FS/498Y for BOP will verify proper system 1C SG in the III position: FT-494 (STM Flow) response

& FT-497 (FEED Flow) 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 4 Page 12 of 45 Event

Description:

FT-495, selected steam Flow Transmitter for C SG fails HIGH Time Pos. Expected Actions/Behavior Comments SRO (step 5) Refer to Tech Specs 3.3.2 for any LCO requirements.

T.S. 3.3.2 Condition D applicable TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 2e High steam flow in two steam lines coincident wI b-b Tavg Applicable in Modes 1, 2 and 3 with MSIVs open required channels 2 per stm line condition D CONDITION REQUIRED ACTION COMPL ETION TIME D. One channel D.1 NOTE inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

Place channel in trip. 72 hrs OR D.2.1 Be in MODE 3. 78 hrs AND D.2.2 Be in MODE 4. 84 hrs SRO (step 6) Notify the Shift Manager (step 7) WHEN plant conditions permit, THEN return systems to automatic control.

SRO (step 8) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

At the discretion of the Lead Examiner move to Event #5.

12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 5 Page 13 of 45 Event Descnption: lB SGFP speed oscillation, fast ramp 1 B SGFP develops a speed oscillation and its controller cant be shifted to manuaL After 3 minutes the controller fails and the crew will enter AOP-13 and conduct a fast ramp to 540 MW to remove the 1 B SGFP from service.

Indications Available:

Annunciators: Indications of B SGFP Speed Oscillation

- 1A SG LVL DEV (JF1) - 1A & lB SGFP Speeds Oscillating

- lB SG LVL DEV (JF2) - SGFP Suction Pressure Oscillating

- 1C SG LVL DEV (JF3) - FRV-controller FK-496, 497, 498 demand oscillating

- FK-509A, B, C SGFP speed controllers demand_oscillating Time Pos. Expected Actions/Behavior Corn ments AOP-13, version 30, orAOP-100, version 9, v ill be entered SRO Directs RO or BOP to address ARPs as time permits

- 1A,1B,&1CSGLVLDEV (JF1,2&3)

SRO Directs entry into AOP-100, section 1.4, and performance of immediate actions, then directs subsequent actions 13

Appendix D Operator Action Form ES-D-2 FA2011301 Op Test No.: Scenario # 4 Event # 5 Page 14 of 45 Event

Description:

lB SGFP speed oscillation, fast ramp Time Pos. Expected Actions/Behavior Corn ments BOP (step 1) Maintain SG level at the referenced Step 1 is an Immediate level of 65%. Operator action Take manual control of SGFP speed control NOTE: Step 1 is a continuing SK-509C taken to manual action step This controller will NOT shift to manual IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

SGFP master controller SK-509A IF required, THEN take manual control of the affected feedwater regulating valves

[] 1 A SG FW FLOW FK-478

[] 1 B SG FW FLOW FK-488

[] 1 C SG FW FLOW FK-498 SRO (step 1.3) IF a loss of main feedwater has This is technically the case occurred, THEN perform the actions since the SGFP cannot be required by AOP-13.O, LOSS OF MAIN controlled and it is oscillating.

FEEDWATER. 1 B SOFP controller will fail low after 3 minutes SRO (step 2) Set manual trip criteria on SG level (high and low trip setpoints are 82% & 28%

respectively)

BOP (step 3) IE a ramp is in progress, THEN place turbine on HOLD.

The above actions are also the same actions as step 3 of AOP-1: . (Step 3.5 AOP-13) Verify adequate SGFP function restored NO RNO return to step 1 of AOP-13.Steps 1-1.3 are lOAs.

SRO (step 1) Check only one SGFP running This is an SRO decision only-one is running since the 1 B SGFP is not contributing flow to the SGs.

14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 5 Page 15 of 45 Event

Description:

lB SGFP speed oscillation, fast ramp Time Pos. Expected Actions/Behavior Comments BOP (step 1.1) Check generator load >540 MW NOTE: the answer is yes, we should be at 85-90% power SRO (step 1.2) Direct the crew to initiate a rapid load reduction BOP (step 1.3) Check DEH in OPERATOR AUTO

- Depress the SGFP SETPOINT button on the DEHC keypad

- Press P8 key

- Verify a TARGET of 540 MW and a RATE of 1200 MW/mm Depress GO BOP (step 1.4) Monitor DEH for correct response RO (step 1.5) Reduce reactor power to match turbine power using control rods and boron.

- Adjust control rods in MANUAL

- Manually borate or emergency borate RO Boratino ner SOP-2.3 appendix B 11111M1IJV ktrt IJJILJb per figure

Set the boric acid integrator to the desired 6 of SOP-2.3 quantity - Start a BAT pump

. Adjust LTDN TO VCT FLOW LK 1 12 - OPEN MOV-81 04 setpoint as desired - When the boration is

. M/U mode selector to STOP complete then s close

. MKUP MODE SEL SWITCH to BOR 8104 and secure the BAT

. MKUP MODE CONT SWITCH to START. pump (Step 1 .6) Verify proper boration operation by NOTE: A boration of 1 GAL observing the following: per reduced MW will limit rod

On service boric acid pump started. insertion and assist in

MKUP TO CHG PUMP SUCTION HDR maintaining Delta I.

FCV113B opens.

BORIC ACID TO BLENDER FCV113A opens.

Boric acid flow is displayed on Fl-I 13 MAKEUP FLOW TO CHGNCT.

15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 5 Page 16 ot 45 Event

Description:

1 B SGFP speed oscillation, fast ramp Time Pos. Expected Actions/Behavior Cornments BOP (step 1.6) Check for proper operation of the steam dumps (step 1.7) Check for proper operation of the FRVs BOP (step 1.8) Closely monitor steam generator narrow range levels.

- WHEN a SG NR level recovers to approx 55% then place all FRV controllers in MANUAL

- Match SF with FF

- Return FRV controllers to AUTOMATIC ALL Stabilize the plant SRO Notify the Shift Manager IF time permits SRO Submits a CR & Notifies the Work Week IF time permits Coordinator When lB SGFP trips, Event #6 (loss of BOTH SGFPs) will start 3 minutes later 16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 6 Page 17 of 45 Event

Description:

BOTH SGFPs trip, 1 A SGFP trips 3 minutes after 18 SGFP trips.

Both SGFPs trip. The lB SGFP trips first. 3 minutes after lB SGFP trips, lA SGFP will trip requiring the crew to manually trip the reactor per AOP-1 3.

Indications Available:

Annunciators: IA;+;, of BOTH S(Fp Trips

- 1A or lB SGFP Tripped (KC3) - SGFP Speed Decreasing toward 0 RPM

- SG LVL DEV (JF1, JF2, JF3) - Feed Flow Decreasing SG LO LVL (JA1, JA2, JA3) - FRV-controller FK-496, 497, 498 demand

- SG STM Flow> Feed Flow (JB1, JB2, increasing JB3) - SG Levels decreasing Pos. Expected Actions/Behavior I Comments AOP-13, version 30 SRO Recognize LOSS of BOTH SGFPs Direct Step 2 of AOP-13

- Perform_the_IOAs_of_AOP-13 RO (Step 2) Check Rx power less than 5% NO >5% power SRO Direct Reactor trip RO Trip the reactor using handswitches The RTBs will not open and the CRDM MG set breakers will not open. Go to event 7.

17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 18 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

When the crew tries to trip the reactor, the reactor trip breakers will not open and the CRDM MG set breakers will not open. The Main Turbine will not trip in auto or manual.

Indications Available:

Annunciators: Recognize indications of ATWT event

- Various and many . RTBs still closed

. Nis indicate full power

. Conditions warrant a reactor trip and one is not received Enter EEP-O, Reactor Trip or Safety Injection, version 38 SRO Reactor trip Direct the reactor trip and enter EEP-O RO/ Immediate Operator actions of EEP-O Immediate Action steps of BOP (step 1) Check reactor trip. EEP-O Check all reactor trip breakers and reactor NOTE: Reactor will NOT trip trip bypass breakers OPEN.

- FRP-S.1 entered at RNO steps Check nuclear power FALLING.

check rod bottom lights LIT. -

TRIP CRDM MG set supply breakers. RNO: Reactor is not tripped 1A(1 B) MG SET SUPP BKR by RTBs or CRDM MG sets.

[1 N1C11EOO5A

[1 N1C11EOO5B SRO Direct entry into FRP S.1 and complete Sten 1 and 2 are lOAs.

RO (step 1) IF reactor still NOT tripped, THEN Critical task perform the following: Insert negative reactivity Insert control rods in manual control.

OR Verify rods insert in AUTO at greater than 48 steps per minute.

3 minutes from this phone Dispatch an operator to locally trip the call RTBs will be opened reactor trip and bypass breakers. from BOOTH 18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 19 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

BOP (step 2) Check Main Turbine tripped Critical task Place MAIN TURB EM ERG TRIP switch to RNO:

TRIP for at least 5 seconds. Close GVs This action will not occur. TURBINE MANUAL depressed GV CLOSE depressed FAST ACTION depressed BOP (step 3) Verify AFW pumps running

- Both MDAFWPs amps > 0

- TDAFWP speed > 3900 rpm RO (step 4) Initiate Emergency Boration of the RCS.

- Verify at least one CHG PUMP -

RUNNING. Critical task

- Start a BAT pump Insert negative reactivity

- Open M0V8104

- Establish normal letdwn flow 8149A and either 8149B or C open

- Check RCS pressure less than 2335 psig

- Establish normal charging flow > 40 gpm

- Verify adequate emergency boration flow of>3ogpmon_Fl-lb 19

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 20 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

BOP (step 5) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[1 3197

[] 3198D

[1 3198C

[] 3196

[] 3198A

[] 3198B Verify containment mini purge dampers -

CLOS ED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-31 98A & 31 98D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[1 2866D

[] 2867D Will place HS to STOP Stop MINI PURGE SUPP/EXH FAN.

BOP (step 6) Check SI actuated BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit A safety injection may not have

[]MLB-1 11-1 lit occurred so Attachment 1 would not be done complete attachment 1 See attached sheets See Tab at end of scenario for for Attachment 1 of FRP-S.1 Attachment 1 actions.

RO (step 7)

Check ALL RTBs open Check Main Turbine tripped 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 21 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

RO (step 8) Check if reactor still critical. NOTE: This is a continuing action step If RTBs are open or power range indication is < 5% power OR IR SUR is negative, then go to EEP-0 step 1 If not continue in this procedure.

SRO Transition back to EEP-O RO/ Immediate Operator actions of EEP-O Immediate Action steps of BOP Check reactor trip. EEP-O Check all reactor trip breakers and reactor trip bypass breakers OPEN.

Check nuclear power FALLING.

check rod bottom lights LIT. -

Check turbine TRIPPED.

- EH pumps may be taken to TSLB2 14-1 thru 4 lit OFF here if it is decided the MT is not tripped. (intent is met Check power to 4160 V ESF busses. in FRP-S.1) 4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR NOTE: NO DGs will be B Train (G & L) power available lights lit running unless a SI has occurred.

Verify operating diesel generators are being supplied from at least one SW pump.

Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[} ACTUATED status light lit

[1 MLB-1 1-1 lit

[1 MLB-1 1 11 lit ESP.0.1, Reactor Trip Response, version 30 actions below 21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 22 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

SRO SI is NOT required at this point, directs transition at step 4 of EEP-O to ESP-O.1, REACTOR TRIP RESPONSE Directs actions in ESP-O.1 per RO/BOP Actions listed below RO (step 1) Check RCS temperature NOTE: this is a continuing

- Stable at or approaching 547°F action step

- TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[1 TI 422D STM DUMP

[] TI 432D BOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554° F, THEN verify feedwater action step status.

- Verify FRVs closed

- Defeat the MADFWP auto start on SGFP trip BOP (step 2.2) - MDAFWP AUTO/DEFEAT

[j 1A in DEFEAT

[] lB in DEFEAT

- Verify BOTH SGFPs tripped

- Verify total AFW flow to the SGs >395 gpm RO (step 3) Verify ALL RX TRIP breakers OPEN RO (step 4) Check emergency Boration not required

- All rods FULLY INSERTED

- RCS Tavg >525°F BOP (step 5) Announce Unit 1 Reactor Trip Put in Large Break LOCA at this point Return to EEP-O 22

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 23 of 45 Event Descnption: LB LOCA A LB LOCA has occured.

Indications Available:

Annunciators: Indications of LBLOCA

- Containment Rad monitors in alarm - RCS Pressure Rapidly Decreasing

- CTMT Pressure HI-i Rx Trip SI (GEl) - SI Actuation

- PRZR LO Press Rx Trip SI (GB4) - Containment Pressure Increasing

- CTMT Press HI-i Alert (EEl) - Numerous CTMT Rad Monitors alarming

- CTMT Press Hl-2 Alert (EE2)

- CTMT Press HI-3 Alert (EE3)

- CS Actuation (EE4)

- CTMT ISO PH B (EE5)

- RMS HI RAD (FF1)

Time Pos. Expected Actions/Behavior I ments t

,: I 23

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 24 of 45 Event

Description:

LB LOCA Time Pos. Expected Actions/Behavior Comments ALL Immediate Operator actions of EEP-0 Immediate Action steps of Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

Check nuclear power FALLING.

check rod bottom lights LIT.-

Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED NOTE: 3 DGs will be running since an SI has occurred.

A Train (F 41 60V bus) power available lights lit OR B Train (G 41 60V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[]MLB-1 11-1 lit SRO, Announces EEP-0 Fold out Page items in RO, effect, directs/takes actions required OR

Subcooling <16°F [45), stop all BOP RCPs

RCS Press < 1300 psig, close chg mini-flows

Ctmt pressure > 4 psig, use adverse numbers 24

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 25 of 45 Event Descnption: LB LOCA Time Pos. Expected Actions/Behavior Comments SRO Recognizes CSF Red Path FRP-P.1 RO BOP SRO Updates Team on FRP-P.1 Entry FRP-P.1, version 19 actions Check RCS pressure - > 275 psig{435 psig}. IF LHSI flow> 1 .5x103 gpm, 1C(1A) LOOP RCS NR PRESS THEN return to procedure and

[] P1 4028 step in effect.

[1 P1 4038 1A(1B) RHR HDR FLOW

[] Fl 605A

[] Fl 605B Return to EEP-O SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to do attachment 2.

(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig RO (step 7) Announce Unit 1 reactor trip and safety injection.

25

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 26 of 45 Event

Description:

LB LOCA Time Pos. Expected Actions/Behavior Comments RO (step 8) Check AFW status.

Check secondary heat sink Available o Check total AFW flow> 395 gpm

[] Fl 3229A

[1 Fl 3229B

[] Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level > 31% {48%}

WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.

WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[1 B TRN reset MDAFWPTO lA/lB/iC SG BTRN

[1 FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[1 RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted 26

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 27 of 45 Event

Description:

LB LOCA Time Pos. Expected ActionslBehavior Comments RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR APPROACHING 547°F.

TAVG 1A(1B,1C) RCS LOOP

[] TI 412D

[] TI 422D

[1 TI 432D RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column is not 547°F and falling, THEN perform the expected to be used for this following, scenario (step 9.1 .1) Verify steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB

[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG

[] Fl 3229A

[] Fl 3229B

[] Fl 3229C AFW TOTAL FLOW

[] Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 NOTE: Will call TBSO to IF MSIVs are open, THEN isolate steam accomplish this task loads in the turbine building while continuing with RNO step 9.1.5.

27

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 28 of 45 Event

Description:

LB LOCA Time Pos. Expected Actions/Behavior Comments RO (step 10) Check pressurizer PORVs and NOTE: [CA] step spray valves.

WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.

Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.

[] PRT PRESS P1 472

[] PRT LVL LI-470

[1 PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray NOTE: [CA] step valves closed OR in the process of closing.

1A(1 B) LOOP SPRAY VLV

[]PK444C

[]PK444D Check any PRZR PORV ISO OPEN -

RO (step 1 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 1 6OF{45 F}

0 SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <

Control charging pump miniflow valves 1300 psig.

based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[} P1 402A

[1 P1 403A 28

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 29 of 45 Event

Description:

LB LOCA Time Pos. Expected Actions/Behavior I Comments Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

SRO (step 13) Check SGs not faulted.

[] Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

(step 14) Check SGs not ruptured [j R-15

- Check secondary radiation indication -

[] 19 NORMAL. [j 23A and B

[] 15B and C,

- No SG rising in an uncontrolled manner [1 60 A, B, C, D SRO (step 15) Check RCS intact [] R-2

- Check ontainment radiation NORMAL [1 R-7

[1 R-27A

- Check CTMT pressure < 3 psig [1 R-27B

- Check ECCS sump level <0.4 feet Transition to EEP-1.O, version 2 9 RO (step 1) Checks RCP stopped due to insufficient subcooling (SCMM<45°F)

BOP (step 2) Check SGs not faulted

- no press falling uncontrolled

- none less than 50 psig BOP (step 3) Checks intact SG levels Verities any intact SG NP level > {48}

Controls MDAFW & TDAFW flows as necessary to maintain levels {48%-65%}

Stops TDAFW pump WHEN at least 2 SGs

>28%

29

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 30 of 45 Event

Description:

LB LOCA Time Pos. ExpectédActions/Behavior Comments BOP (step 4) Check SGs not ruptured [] R-15

- Check secondary radiation indication -

[1 19 NORMAL. [1 23A and B

[] 15B and C,

[] 60 A, B, C, D (step 5) Checks PORVs

- Iso valves open with power

- PORVs closed with no leakage

- no evidence of leak by via downstream temps & PRT parameters Sf0 (step 6) directs step 6 be performed (1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Fold out page from start of event requirements not- WHEN 12.5 Feet level in available to perform in simulator-SRO calls RWST, transitions to ES P-i .3, for SSS or an extra to perform) Cold Leg Recirc

- Close recirc disconnects

- Establish 1 A & 1 B post LOCA H2 analyzer on service per ATT 2

- Plot H2 on Fig 1

- Check and control H2 concentration in Ctmt SRO (step 7) Checks for SI termination criteria RO and continues on without terminating SI due to inadequate RCS pressure & Pzr level RO (step 8) Checks containment spray system

- Both CS pumps started

- Resets both trains of CS signals RO (step 9) Determines LHSI pumps should NOT be stopped due to RCS Pressure <

{435 psig}

- Establishes CCW to both RHR HXs by verifying open MOV 3185A & B BOP (step 12) Performs EEP-i ATT 4, See Tab at end of scenario for VERIFYING 4160 V BUSSES ENERGIZED Attachment 4 actions.

30

OpTestNo.: FA2011301 Scenario# 4 Event# 8 Page 31 of 45 Event

Description:

LB LOCA Time Pos. Expected Actions/Behavior Comments SRO (step 13) Directs securing Unloaded DGs (extra, Unit two UO, or BOP)

(step 14) Begins evaluation of plant status, Determines both trains of reciro equipment available

- Checks the following:

o BOTH RHR pumps o MOV-881 lA/B o MOV-8812A1B o MOV-8706A1B o CCW MOV-31 85A1B SRO (step 14.2) Directs Unit two UO to assist BOP taking ECCS logs (step 14.2) Directs TSC to evaluate need for RCS sampling (step 14.2) checks for no intersystem LOCA outside Ctmt

- Aux building radiation NORMAL

- Aux building no hi sump levels & pumps not running

- WHT and EDT levels not rising unexplained (step 14.2) Verify at least one train of PRF in operation using SOP-60.O, PRF System(Attached)

(step 15) Checks LHSI flow in progress by low RCS PRESSURE & LHSI flows >1 .5xE3 (step 16) when RWST level <12.5 feet then transition to ESP-l .3 When the decision is made to transfer to ESP-1 .3, terminate the scenario.

31

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 32 of 45 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-0 Attwhmnf of EEP-O I

AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comment&:

(Step 1) Verify one CHG PUMP in each train STARTED.

BOP []Atrain(lAorlB)amps>0

[1 B train (1 C or 1 B) amps > 0 BOP (Step 2) Verify RHR PUMPs STARTED.-

RHR PUMP

[1 1A amps >0

[] lBamps>0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow GREATER THAN 0 gpm.

[] Fl 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow greater than 1.5 Xl o gpm

[] 1A RHR HDR FLOW Fl-605A

[1 1 B RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[1 A train (1A,1B or 1C)

[] B train (1D,lEor 1C) 32

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 33 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -

STARTED.

(Step 2.1) Verify one CCW PUMP in each train- STARTED.

A train HX 1 C or 1 B CCW FLOW

[1 Fl 3043CA > 0 gpm OR

[j Fl 3043BA> 0 gpm B train HX lAor lB CCW FLOW

[J Fl 3043AA > 0 gpm OR

[1 Fl 3043BA > 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[] QIP16FI3009AA> 0 gpm

[] 01 P1 6F13009BA> 0 gpm

[1 Q1 P1 6F13009CA> 0 gpm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[1 1A

[1 1 B

{] 1C Check INST AIR PRESS P1 4004B greater than 85 psig.

33

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 34 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[1 3198D

[1 3198C

{] 3196

[j 3198A

[] 3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[J 2866D

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 34

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 35 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT Cl R FAN SI OW SPFPfl A train

[] 1A

{j 1 B B train

[1 1C

[1 1 D Verify associated emergency service water outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3O24A

[j Q1P16MOV3O24B

[1 Q1P16MOV3O24C

[1 Qi P1 6MOV3024D BOP (step 8) Verify AFW Pumps STARTED.

Verify both MDAFW Pumps STARTED-

[] 1A MDAFW Pump amps > 0

[] lB MDAFW Pump amps> 0 AND

[] Fl-3229A indicates > 0 gpm

[] Fl-3229B indicates > 0 gpm

[] FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

ZCondition ETSLB EiSetoint ECoincidence E RCP Bus TSLB2 1-1 D2680 V 1/2 Detectors Undervoltage 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1 ,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1 ,6-2,6-3 35

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 36 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior BOP (step 8.3) Verify TDAFWP started.

[1 MLB-4 1-3 lit

[] MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[]SI 3411A>3900 rpm TDAFWP SPEED CONT

[1 SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWPTO 1A(1B,1C) SG

[1 Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C) SG FLOW CONT

[1 HIC 3228AA open

[J HIC 3228BA open

[j HIC 3228CA open 36

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 37 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[1 FCV 488

[] FCV 498 Verify both SGFPs TRIPPED.

Verify SG blowdown ISOLATED.

1A(1B,1C) SGBD ISO

[1 Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[1 MLB1 1 9-2 lit Qi P1 5HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[1 MLB1 1 9-4 lit Qi P1 5HV3330 closed SOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.

(Step 11 .1) Verify PHASE A CTMT ISO -

ACTUATED.

SOP [1 MLB-2 1-1 lit

[] MLB-2 1 11 lit 1 1 .2 Check all MLB-2 lights - LIT.

37

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 38 of 45 Event

Description:

Attachment 2 of EEP-o Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[1 N1C11EOO5A

[] N1C11EOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[1 1A

[J 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[1 1A

[] 1 B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate Will call TBSO to pumps per FNP-O-SOP-O.O, APPENDIX B, accomplish this.

TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.

38

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 39 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[]A TRAIN

[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[1810- OPEN

[] 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.

End of Attachment 2 39

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 40 of 45 Event

Description:

Attachment 4 of EEP-O Time I Pos. Expected Actions/Behavior I Comments Attachment 4 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[1 Check DFO1 closed

[1 Verify DFO2 closed

[] Check DG15 closed

[] Verfiy DGO2 closed

[] Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.

[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOVS132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[1 Q1E21MOV813OA

[1 Q1E21MOV813OB

[] Q1E21MOV8131A

[] Q1E21MOV8131B 40

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 41 of 45 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected Actions/Behavior Comments (Step 1 .7) Verify all post accident containment air mixing system fans STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[J 1 B

{j 1C

[] 1 D RX CAV H2 DILUTION FAN

[] 1A

[] lB (Step 1 .8) WHEN power restored to any de energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 41

Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 42 of 45 Event

Description:

Attachment 1 of FRP-S.1 Time Position Applicants Action or Behavior Attachment 1 of FRP-S.1 AUTOMATIC SAFETY INJECTION VERIFICATION BOP (step 1) Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR B Train (G & L) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 2) Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

{] ACTUATED status light lit

[] MLB-1 11 lit

[] MLB-1 1 1-1 lit BOP (step 3) Verify MFW status

- Verify main FRVs and bypass valves valves CLOSED.

1A(1B,1C) SG STOP VLVFW FLOW

[1 FCV 478

[] FCV 488

[] FCV 498

- Verify both SGFP5 TRIPPED.

- Verify SGBD isolated HV 7614A, B C closed

- Verify SGBD sample valves closed by MLB-4 6-4, 7-4 and 8-4 LIT BOP (step 4) Verify Phase A actuated MLB-2 1-1 and 1 1-1 Lit all MLB-2 lights LIT BOP (step 5) Verify one CHG PUMP in each train - STARTED.

[] A train (1A or 1B) amps> 0

[] B train (1 C or 1 B) amps > 0 BOP (step 6) Verify RHR PUMPs STARTED.

RHR PUMP 1A and lB amps> 0 42

Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 43 of 45 Event

Description:

Attachment 1 of FRP-S.1 (step 7) Verify each train of CCW STARTED.

BOP Verify one CCW PUMP in each train- STARTED.

A train HX 1C or 1 B CCW FLOW

[1 Fl 3043CA > 0 gpm OR

[] Fl 3043BA > 0 gpm B train HX lAor lB CCW FLOW

[] Fl 3043AA > 0 gpm OR

[] Fl 3043BA > 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[1 Qi P16FI3009AA > 0 gpm

[1 01 P16FI3009BA> 0 gpm

[1 Qi P16FI3009CA > 0 gpm (step 8) Verify each SW train - HAS TWO SW PUMPs STARTED.

[]A train (1A,lBor 1C)

[] B train (1D,lEor 1C)

BOP (step 9) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED D A train

[] 1A

[] 1 B E B train

[1 1C

[] 1 D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C1D) CTMT CLR

[] Q1P16MOV3O24A

[1 Q1P16MOV3O24B

[1 Q1P16MOV3024C 43

Op Test No.: FA2011301 Scenario # 4 Event # 7 Page 44 of 45 Event

Description:

Attachment 1 of FRP-S.1

[] Q1P16MOV3O24D BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543° F 2/3 TSLB2 1 0-1 ,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 If a MSLI signal is present then close ALL MSIVs BOP (step 11) Check containment pressure -HAS REMAINED LESS THAN 27 psig.

End of attachment 1 of FRP-S.1 44

Op Test No.: FA2011301 Scenario # 4 Event # 8 Page 45 of 45 Event

Description:

Attachment 4 of EEP-1.0 Time Pos. Expected ActionslBehavior I Comments Attachment 4 VERIFYING 4160 V BUSSES ENERGIZED (Step 1) Verify 4160 V busses energized.

[J Check DFO1 closed

[1 Verify DFO2 closed

[1 Check DG15 closed

[j Verfiy DG02 closed

[1 Verify ALL RCP busses energized

- 1A, 1B, 1C4160V Bus

[] Verify 1 DIE busses energized (step 1.13) Verify instrument air aligned to containment. (BOP)

IA TO PENE RM

[] N1P19HV3825 open

[1 N1P19HV3885 open IA TO CTMT

[J Q1P19HV3611 open End of Attachment 4 45

Anendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2O1 1-30 1 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

Assign operating ijositions.

Ask for and answer questions.

Appendix D Turnover sheet Form ES-D-2 X] Unit 1 [1 Unit 2 Shift: Date I Off-goingSS I OncomingSS I [ IN [X]D I Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, 5, D, SW, X on key ring. SS Unit 100% power RTP, MOL, 812 ppm Cb, 10,000 MWD, Eq Xe, (-2928)

Status TAR(ET ZERo STPs/Evolutions: Y Day. Every Job Sa1lly B Train On-Service B Train Protected 1.0_; 109.1 Noadj.; 63.7; FSP-20,0 Status of Special Testing General Information

1. 2C DG TIC for Jacket Water leak repair (OCS 2 days, ETR 4 hrs)

2. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

3. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia

4. Current Risk Assessment is N and projected is GREEN 5.

6.

7.

8.

9.

Equipment Status 2C DG T/C for Jacket Water 1 B EHC pump is tagged out Maintain VCT gas pressure 25-30 psig leak repair Reactivity Plan Waste Management Status 20 Gallon Dilutions as required to maintain #3 RHT On Service temperature and power.

WGS secured LCO Status 2C DG (Admin)

Night Orders No New Night Orders Part II Review Shift Complement LCCs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X]Yes [XjYes [X]Yes [X]Yes [XjYes [X]Yes

Appendix D Scenario Outline Form ES-D-1 DRAFT SUBMITTAL Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SRO AG BOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 1 -2A DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearing replacement. (OCS 6 hrs, ETR 2 hrs)

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 1 (I) (RO) FT-122, charging flow transmitter, fails low 2 R (RO & BOP) 1 A SG tube leak 15 gpm over 3 mm and stabilizes 2

TS (SRO) TS 3.4.13 condition B 3 C (RO) PK-444A, Pzr pressure controller, fails high 4 C (BOP) CST rupture crane accident will place SW on AFW suctions TS (SRO) TS 3.7.6 condition A 5 5 (I) (BOP) PT-464, Stm header pressure transmitter, fails high.

6 6 M (ALL) Slow Loss of air will cause a Rx trip to be called for 7 C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set 7

breaker will not open. FRP-S.1 will be entered. (CT) 8 8 C (RO) PORV fails open can be isolated with MCB handswitch (CT) 9 M (ALL) 1A SGTR 500 gpm when RTBs are opened will cause EEP-3 9 entry. (or when FRP-S.1 exited) 10 (BOP) 1A SG MSIVs will not auto close 11 M (ALL) 1A SG fault upstream of 1A MSIV in MSVR when 1A MSIV is 10 closed at step 3.7 of EEP-3.0. Close all MSIVs and isolate AFW flow to the Faulted SG. (CT)

Terminate when ECP-3.1 is entered.

(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 WAFT MITTAL Changes in BLUE Removed the Mn turb will not trip (this was a critical task) to prevent prolonging the scenario.

SG water levels will already be low.

Event 9 and 10 modified to ensure the SGTR comes in properly and then SG fault comes in to drive the crew to ECP-3.l. SG pressures never dropped to <200 psig.

Farley May 2011 exam Page 2 of 6

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SRO PC SOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 1 -2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearing replacement. (QOS 6 hrs, ETR 2 hrs)

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 1 (I) (RO) FT-122, charging flow transmitter, fails low 2 A (RO & BOP) 1 A SG tube leak 15 gpm over 3 mm and stabilizes 2

TS (SRO) TS 3.4.13 condition B 3 C (AC) PK-444A, Pzr pressure controller, fails high 4 C (BOP) CST rupture crane accident will place SW on AFW suctions 4

TS (SRO) TS 3.7.6 condition A 5 5 (I) (BOP) PT-464, Stm header pressure transmitter, fails high.

6 6 M (ALL) Slow Loss of air will cause a Ax trip to be called for 7 C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set 7

breaker will not open. FRP-S.1 will be entered. (CT) 8 C (AC) PORV fails open PORV ISO can be isolated with MCB 8

handswitch (CT) 9 M (ALL) 1A SGTR 500 gpm when RTBs are opened will cause EEP-3 entry. (or when FRP-S.1 exited) 10 (SOP) 1A SG MSIVs will not auto close 11 M (ALL) 1A SO fault upstream of 1A MSIV in MSVR when 1A MSIV is 10 closed at step 3.7 of EEP-3.0. Close all MSIVs and isolate AFW flow to the Faulted SG. (CT)

Terminate when ECP-3.1 is entered.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 1 of 6

Appendix D Scenario Pre-sets Form ES-D-1 0 0 TagoutlBEHpump CMFmalf I_cmshfpb_cp2 6 0 1A condensate pump will not start in auto or manual lmf ccfcnla_cc8 open Imf ccfcnla_cc9 open Imf ccfcnla_cclO open lmf ccfcnla_opos3_open 6 0 Prevent 1 B Inst. A/C from starting from MCB.

CMFmalf / cmi5O40B_cr5 7 0 Fail RTB from opening on manual or auto trip CMFmalf I cBKRXTRP_cc2l/ closed CMFmalf / cBKRXTRP_cc22/ closed 7 0 1 A CRDM MG set breaker will not open CMFmalf I c52mga_cr3 10 0 1A MSIVs will not close on auto closure CMFmalf/ crsh00la_cc5 /open CMFmalf /_cmsh002a_d_cc5_/open 0 0 Tag 1 -2A DG output breakers for Unit 1 & 2 rack out 1-2A DG DFO8-1 rack out 1 -2A DG DFO8-2 CMFremote I cbkldfo8_d_cdl I open CMFremote I cbk2df08_d_cdl I open Triggers_and_Commands 8 0 Trigger 2 PORV-445a sticks 40% after opening

- > 20% There is a button to insert trgset 2 rrc445a> 0.2 3 is PORV 445a sticks at 40% show up in the IS summary trg 2 imf rrc445a-s 40 at this time 9 0 Trigger 3:1A SG 500 gpm SGTR ramped in over 60 seconds when Rx trip breakers open trgset 4 j52rtao && j52rtbo Corn mand: imf mal-rcs4a 500 60 4 0 Trigger 4: When CST level < 14.1 decrease CST toO feet over 300 seconds.

Event: bcfwl32b < 14.1 Command: irf loa-cfwOOl 0 300 Farley May 2011 exam Page 2 of 6

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 100% power. 855 ppm, MOL Turnover:

1 -2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is

B Train On-Service B Train Protected.

and projected is ,

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 FT-i 22 fails LOW AOP-16 entry.

Verifiable actions: Take manual control of FCV-122 before Pzr level exceeds Tech Spec limit and control Przr level.

Event 2 1A SG tube leak 15 gpm over 3 mm and stabilizes TS 3.4.13 (d) 150 gallons per day primary to secondary LEAKAGE through any one SG. Condition B Verifiable actions: Commence ramp off line need to make this a high enough leak to be at 50% in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and mode 3 in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . RO will adjust rods or boron to control TavglTref on program, BOP will set up and start a ramp on the Main Turbine.

Event 3 PK-444A fails high will have to react to rising RCS pressure AOP-100 entry Verifiable actions: take manual control of RCS pressure and use sprays and heaters to control RCS pressure during ramp down. (Cnh / imf pk444a-d / 0/ 45 manual and auto portion will not work)

Event 4 CST rupture crane accident TS 3.7.6 condition A Verifiable actions: place SW on AFW suctions Event 5 PT-464, Stm header pressure transmitter, fails high. SGFP speed increases.

Verifiable actions: take manual control of SGFP and FRVs and control SG water level < Hi Hi SGWL trip. If the crew does trip here event 6 will be entered when the crew tries to trip the reactor.

Event 6 Slow Loss of air will cause a Rx trip to be called for AOP-6 entry Verifiable actions: Trip Reactor Event 7 Rx Trip will not work.

Verifiable actions: FRP-S.1; Drive rods in the fastest mode possible. Establish emergency boration (CT)

Event 8 PORV fails open PORV ISO can be isolated with MCB handswitch (CT)

Event 9 1A SGTR 500 gpm when RTBs are opened will cause EEP-3 entry. (or when FRP-S.1 exited). 1A SG MSIVs will not auto close.

Farley May 2011 exam Page 3 of 5

Appendix D Scenario detailed summary sheet Form ES-D-1 Event 10 Step 3.7 of EEP-3.0 when 1A MSIVs are closed, 1A SG fault outside ctmt upsteam of MSIVs will occur.

ALL SGs isolated in EEP-2 when 1A SG is faulted. (CT)

Terminate when ECP-3.1 is entered.

AQP-16/AOP-2.0/AOP-100/ARP & SOP-22!AOP-100/AOP-6.0/ FRP-S.1/ EEP-0.0/ EEP-3.0I EEP 2.0/ EEP-3/ ECP-3.1 Farley May 2011 exam Page 4 of 5

Appendix D Scenario Critical Task Sheet Form ES-D-l CRITICAL TASK SHEET Insert negative reactivity into the core by at least one of the following methods before completing the immediate action steps of FRP-S.l: (WOG CT FR-S.1 - - C)

(PRA NR:16, 21, 23, 27)

De-energize the CRDM MG sets

Insert RCCAs

Establish emergency boration flow to the RCS (NOTE: Negative reactivity insertion using control rods should begin within 6 minutes of start of event with MEW inservice > 40% power, and 1 minute of start of event with no MFW >40% power, and within 10 minutes if < 40% power.)

2. Close the block MDV upstream of the stuck open Pzr PORV by completion of the first step in the ERG network that directs the crew to close the block MDV: (WOG CTE-0--M)

Close PORV ISO with MCB handswitch at or before EEP-0 at the step to Check pressurizer PORVs and spray valves [closed].

Isolate the faulted steam header prior to transition out of EEP-2: (WOG CT E-2 -A) -

SCENARIO The team should be able to:

OBJECTIVE!

Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-16, AOP-100, SOP-22, AOP-2.0 and AOP-6.0 and Tech Specs

Respond to a loss of air and then an ATWT event when the reactor will not trip, then isolate a failed open PORV.

The crew will have to evaluate a ruptured SG after exiting FRP-S.1 and then react to a faulted SG on the ruptured SG while in EEP-3.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 11

2. Malfunctions after EOP entry (12) 6

3. Abnormal events (24) 5

4. Major transients (12) 3

5. EOPs entered/requiring substantive actions (12) 2

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley May 2011 exam Page 5 of 5

Scenario #3 FA2011301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #3 Validation time: 127 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approval: Gary Ohmstede Date:

NRC Chief Examiner Ron Aiello Date:

SOUTHERN COMPANY

Appendix D Scenario #3 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: 201 1-301 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power. 812 ppm, MOL Turnover:

. 1 -2A DG TIO for governor work. (COS 2 days, ETR 4 hrs)

. 1 B EHC pump TIC for motor bearing replacement. (COS 6 hrs, ETR 2 hrs)

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 (I) (RO) FT-i 22, charging flow transmitter, fails low 2 R (AC & BOP) 1 A SG tube leak 15 gpm over 3 mm and stabilizes 2

TS (SRO) TS 3.4.13 condition B 3 C (RC) PK-444A, Pzr pressure controller, fails high 4 C (BOP) CST rupture crane accident will place SW on AFW TS (SRO) suctions TS 3.7.6 condition A 5 5 (I) (BCP) PT-464, Stm header pressure transmitter, fails high.

6 6 M (ALL) Slow Loss of air will cause a Rx trip to be called for 7 C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set 7

breaker will not open. FRP-S.i will be entered. (CT) 8 8 C (AC) PCRV fails open can be isolated with MCB handswitch (CT) 9 M (ALL) 1A SGTR 500 gpm when RTB5 are opened will cause EEP-3 entry. (or when FRP-S.1 exited) 10 (BOP) 1A SG MSIVs will not auto close 11 M (ALL) 1 A SG fault upstream of 1 A MSIV in MSVR when 1 A MSIV is 10 closed at step 3.7 of EEP-3.0. Close all MSIVs and isolate AFW flow to the Faulted SG. (CT)

Terminate when ECP-3.1 is entered.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 14

Appendix D Scenario 3 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 IC-213 MOL 100% power B Train on service 812 ppm boron Base_IC-74 RUN I

RUN simulator 0 0 Generic setup:

bat generic_setup_H LT.txt 0 0 Quick setup (all items with are included):

bat 201 1 nrcexam_03.txt PRESETS 0 0 Tag out 1 B EH pump CMFmaIf / cmshfpb_cp2 6 0 1A condensate pump will not start in auto or manual lmf ccfcnla_cc8 open Imf ccfcnla_cc9 open Imf ccfcnla_cclO open lmf ccfcnla_opos3 open 6 0 Prevent 1 B Inst. A/C from starting from MCB.

CMFmaIf / cmi5O4OB_cr5 7 0 Fail RTB from opening on manual or auto trip CMFmalf / cBKRXTRP_cc2l/ closed CMFmaIf I cBKRXTRP_cc221 closed 7 0 IA CRDM MG set breaker will not open CMFmaIf/ c52mga_cr3 10 0 1A MSIVs will not close on auto closure CMFmaIf/ crsh0ola_cc5 /open CMFmaIf / cmsh0o2a_d_cc5 /open 0 0 Tag 1 -2A DG output breakers for Unit 1 & 2 rack out 1 -2A DG DF08-1 rack out 1 -2A DG DFO8-2 CMFremote / cbkl dfO8_d_cdl / open CMFremote I cbk2df08_d_cdl I open Triggers_and_Commands 8 0 Trigger 2 - PORV-445a sticks 40% after opening > 20% There is a button to insert

,, trigger 2 in when event 3 is trgset 2 rrc445a > 0.2 complete. This will not Fancy May 2011 exam Page 3 of 14

Appendix D Scenario 3 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS PORV 445a sticks at 40% show up in the IS summary trg 2 mf rrc445a-s 40 at this time 9 0 Trigger 3:1A SG 500 gpm SGTR ramped in over 60 seconds when Rx trip breakers open trgset 4 j52rtao && j52rtbo Command: imf mal-rcs4a 500 60 4 0 Trigger 4: When CST level < 14.1 decrease CST to 0 feet over 300 seconds.

Event: bcfwl32b < 14.1 Command: irf loa-cfwOOl 0 300 Farley May 2011 exam Page 4 of 14

Appendix D Scenario 3 Simulator setup Form ES-D-1 MCB setup Place 1 B EH pump HS to STOP and HOLD Tag on HS 1 HOLD tag HS to STOP 1 -2A DG Mode selector switch Place in Mode 3 Place HOLD Taq 1 -2A MSS 1 HOLD TAG Place HOLD Tag on 1 -2A DG output breakers 2 HOLD TAGS Place Unit 1 and unit 2 Bypass and inoperable panel Unit 1 A-Train EMERGENCY POWER SYSTEM lights to the up Unit 2 A Train position DEH Clear DEH alarms Select POWER OPS PRIMARY on MOB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity sDreadsheet Drovided Recorders Verify memory disks cleared or Perform Booth Operators Setup Checklist Open Simview tile to be used for plant parameter data collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW / Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv simclock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 5 of 14

Appendix D Scenario 3 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam Fr Verify Horns ON: hornflag HORNS ON = TRUE Turn Horns ON/OFF ann horn FT-i 22, charging flow transmiffer, fails low Xmt/imfftl22 030 iA SG tube leak 15 gpm over 3 mm and stabilizes 2

MaIf / M / mal rcs4a / 15 /180 When .

ramp PK-444A, Pzr pressure controller, fails high- will have to starts put react to rising RCS pressure AOP-1 00 entry manual 3 in next control of RCS pressure. Manual and auto portion will event not work Cnh I pk444a-d /0/ 45 second ramp Insert trigger 2 here when event 3 is complete When CST rupture crane accident lOAs of CST level will trend down to 14 feet over 5 mm Remote / N21 / loa-cfwOOl /14 / 300 second ramp put in CST Note: (CST level rate of change is automatically rupture adjusted on trigger 4. Button is backup)

CST level will drop to 0 over a slower time frame when Trigger 4 the CST level reaches 14.1 Remote / N21 / loa-cfwOOl / 0 I 300 second ramp.

preset bcfwl 32b Farley May 2011 exam Page 6 of 14

Appendix D Scenario 3 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND PT-464, Stm header pressure transmitter, fails high.

Xmt1pt4641000120 NRC Loss of air on turbine building essential IA header will CUE or cause a Rx trip to be called for AOP-6 entry when Malf I A / Mal-auxi a / 80 / 60 sec ramp.

the crew 6 tries to trip the Put in if crew trips the reactor 1 = open 0 = closed TB AOV reactor on the previous event Preset Rx Trip will not work in auto or manual, and one CRDM 7 MG set breaker will not open. Drive rods in the fastest mode possible. Establish emergency boration 8 Preset PORV fails open can be isolated with MCB handswitch Trigger 2 Preset 1A SGTR 500 gpm Set to come in when RTBs are opened or manually when FRP-S.1 is exited.

MaIf I R I mal-rcs4a / 500 I 60 9 Trigger 3 If this does not come in, activate button at step 1 of EEP-0 1A SG MSIVs will not auto close Step 3.7 1A SG fault upstream of 1A MSIV in MSVR.

30 10 lA MSIV Insert at step 3.7 of EEP-3.O when 1A MSIVs are 4J closed closed.

lmf mal-mss2a 1 50 Terminate when ECP3.1 entered.

End of Exam HORNS OFF simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

grpX.txt Farley May 2011 exam Page 7 of 14

Appendix D Scenario 3 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND NOTE: Substitute grpX with grp 1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Farley May 2011 exam Page 8 of 14

Appendix D Scenario 3 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 3 minutes after Locally open reactor breakers requested NOTE: when RTBs are CMFmaIf / cBKRXTRP cc2l / open opened check that trigger 3 tired CMFmaIf / cBKRXTRP_cc22 / open 8 NONE REQUIRED 9 NONE REQUIRED 10 WHEN REQUESTED Fire alarm communications 1A 106 is in alarm MSVR RESET MH1 imf fail off Close vOl7A iii Ioa-afw006 0 10 Farley May 2011 exam Page 9 of 14

Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

1 WHEN REQUESTED Radside SO:

The charging pump and FCV-1 22 look fine.

DISPATCH ER:

- Acknowledges when informed that the CR is in the queue.

2 WHEN REQUESTED AOP-2.O communications-counting room (SRC), HP and shift chemist CCP-31 Appendix C, grab samples and CCP-201, STP-746 samples to be drawn.

SM will all be notified.

Unit2UO:

I will perform STP-9.O.

DISPATCHER:

I will place SJAE filtration on service.

Radside SO:

I will secure SGBD.

3 WHEN REQUESTED DISPATCHER:

- Acknowledges when informed that the CR is in the queue.

4 When the CST low level DBSO:

alarm comes in report: A crane has fallen on top of the CST and sliced the tank open from top to bottom.

SM:

I will make notifications as required.

5 WHEN REQUESTED DISPATCHER:

- Acknowledges when informed that the CR is in the queue.

6 WHEN REQUESTED TBSO:

There is a large pipe rupture in the Turbine Building Instrument air piping.

7 3 minutes open the ROVER:

RTBs and then report: See Local Operator Actions section for opening trip breakers The RTBs are open on UNIT 1 Farley May 2011 exam Page 10 of 14

Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

8 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

ANY CALL TO SHIFT RADIO CHEMIST:

I am doing dose assessment and CCP-645 10 WHEN REQUESTED Rover. DBSO or security:

There is steam coming out of the grating of the MSVR.

IF REQUESTED HP report:

The is high activity outside the UNIT 1 MSVR Farley May 2011 exam Page 11 of 14

Scenario 3 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 100% power. 855 ppm, MOL Turnover:

1 -2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is N and projected is

B Train On-Service B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 FT-122 fails LOW AOP-16 entry.

Verifiable actions: Take manual control of FCV-122 before Pzr level exceeds Tech Spec limit and control Przr level.

Event 2 1A SG tube leak 15 gpm over 3 mm and stabilizes TS 3.4.13 (d) 150 gallons per day primary to secondary LEAKAGE through any one SG. Condition B Verifiable actions: Commence ramp off line need to make this a high enough leak to be at 50% in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and mode 3 in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . RO will adjust rods or boron to control Tavg/Tref on program, BOP will set up and start a ramp on the Main Turbine.

Event 3 PK-444A fails high will have to react to rising RCS pressure AOP-100 entry Verifiable actions: take manual control of RCS pressure and use sprays and heaters to control RCS pressure during ramp down. (Cnh I imf pk444a-d I 0/ 45 manual and auto portion will not work)

Event 4 CST rupture crane accident TS 3.7.6 condition A Verifiable actions: place SW on AFW suctions Event 5 PT-464, Stm header pressure transmitter, fails high. SGFP speed increases.

Verifiable actions: take manual control of SGFP and FRVs and control SG water level < Hi Hi SGWL trip, If the crew does trip here event 6 will be entered when the crew tries to trip the reactor.

Event 6 Slow Loss of air will cause a Rx trip to be called for AOP-6 entry Verifiable actions: Trip Reactor Event 7 Rx Trip will not work.

Verifiable actions: FRP-S.1; Drive rods in the fastest mode possible. Establish emergency boration (CT)

Event 8 PORV fails open PORV ISO can be isolated with MCB handswitch (CT)

Event 9 1A SGTR 500 gpm when RTBs are opened will cause EEP-3 entry. (or when FRP-S.1 exited). 1A SG MSIVs will not auto close.

Farley May 2011 exam Page 12 of 14

Scenario 3 detailed summari Appendix D Form ES-D-1 sheet Event 10 Step 3.7 of EEP-3.0 when 1A MSIVs are closed, 1A SG fault outside ctmt upsteam of MSIVs will occur.

ALL SGs isolated in EEP-2 when 1A SG is faulted. (CT)

Terminate when ECP-3.1 is entered.

AOP-16/ AOP-2.0/ AOP-l00I ARP & SOP-221 AOP-100/ AOP-6.0/ FRP-S.1/ EEP-0.0/ EEP-3.0/ EEP 2.0/ EEP-3/ ECP-3.1 Farley May 2011 exam Page 13 of 14

Appendix D Scenario 3 Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET Insert negative reactivity into the core by at least one of the following methods before completing the immediate action steps of FRP-S.1: (WOG CT FR-S.1 - -

C) (PRA NR:16, 21, 23, 27)

De-energize the CRDM MG sets

Insert RCCAs

Establish emergency boration flow to the RCS (NOTE: Negative reactivity insertion using control rods should begin within 6 minutes of start of event with MFW inservice > 40% power, and 1 minute of start of event with no MEW > 40% power, and within 10 minutes if <40% power.)

2. Close the block MOV upstream of the stuck open Pzr PORV by completion of the first step in the ERG network that directs the crew to close the block MOV: (WOG CTE-0--M)

Close PORV iso with MCB handswitch at or before EEP-0 at the step to Check pressurizer PORVs and spray valves [closed].

Isolate the faulted steam header prior to transition out of EEP-2: (WOG CT E-2 - -

A)

SCENARIO The team should be able to:

OBJECTIVE?

Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-16, AOP-100, SOP-22, AOP-2.0 and AOP-6.0 and Tech Specs

Respond to a loss of air and then an ATWT event when the reactor will not trip, then isolate a failed open PORV.

The crew will have to evaluate a ruptured SG after exiting FRP-S.1 and then react to a faulted SG on the ruptured SG while in EEP-3.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 11

2. Malfunctions after EOP entry (12) 6

3. Abnormal events (24) 5

4. Major transients (12) 3

5. EOPs entered/requiring substantive actions (12) 2

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley May 2011 exam Page 14 of 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 1 Page 1 of 43 Event Descnption: FT-i 22, Charging Flow Transmitter, fails LOW FT-122 will fail high. This will cause FCV-122 to open fully but the indication to show 0 gpm. The crew will use AOP-1 6 to restore control of Charging flow and charging will remain in manual for the entire scenario.

Indications Available:

Annunciators: Recognize indications of FT-122 FAILING

- CHG HDR FLOW HI-LO (EA2) LOW

- REGEN HX LTDN FLOW DISCH TEMP - FT-122 will indicate >0 gpm (pegged low)

HI (DEl) (possible if not discovered in a - VCT level will timely manner) - Przr level will slowly

- FK-122 demand will go to approx. 0

- LK-459F will slowly Time Pos. Expected ActionslBehavior Comments AOP-16.0, version 17, CVCS Malfunction SRO Determine a charging system malfunction is occurring and direct entry into AOP-16.

RO (Step 1) Verify CHG flow adequate to cool Flow will be adequate letdown CHG FLOW FI-122A LTDN HX OUTLET FLOW FI-150 -

REGEN HX OUTLET TEMP Tl-140 -

BOP (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level (Step 4) Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging NOTE: Actual amps will be pump operation lower than normal

- P1-121 and ammeter for chg pump RO (Step 5) Check charging pump RUNNING YES 1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # I Page 2 of 43 Event Descnption: FT-i 22, Charging Flow Transmitter, fails LOW Time Pos. Expected Actions/Behavior Comments RO (Step 6) Check Charging flow FK-122 NOTE: There will be flow controlling in AUTO with flow indicated indicated and FK-122 in AUTO

- Seal inj flow will decrease FK- 122 is taken to manual control RNO due to FCV-122 going open.

Adjust SEAL WTR INJECTION HIK-i 86 as required to maintain RCP seal injection flow 6-13 gpm.

RO (Step 7) Check DE3 clear YES (Step 8) Determine Status of Normal Since there is flow, go to Letdown: RNO to go to step 18 on page LTDN HX OUTLET FLOW, Fl-i 50 4 below

- NO FLOW INDICATED SRO (step 18) Determine charging status

- Check charging flow controlled in

(_

Manual RO (step 19) Check VCT outlet MOVs open

- LCV-ii5DandE (step 20) Verify charging pump suction aligned

- MOVs813OA&B

- MOVs8131A&B RO (step 21) Verify charging pump discharge aligned

- MOVs8132A&B

- MOVs8133A&B

- MOVs81O7&8i08 SRO (step 22) Direct maintaining Pzr level between 20 and 60%

SRO (steps 23 25) check charging and letdown in service 2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event# 1 Page 3 of 43 Event Descnption: FT-i 22, Charging Flow Transmitter, fails LOW Time Pos. Expected ActionsIBehavior Comments SRO - Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

- Notify the Shift Manager Go to event 2 when FCV-i 22 is in manual and Przr level is being controlled. The next event takes approx. 4 minutes to ramp in.

3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 4 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes 1C SG tube leak will start and ramp in over 3 minutes.

Indications Available:

Annunciators: Recognize indications of SG TUBE LEAK

- SG TUBE LEAK ABOVE SETPT (FG1) - R-15, 19 AND 23 IN ALARM

- RMS HI RAD (FH1) - R-70A READING > 1000 GPD

- SGBD PROC PNL TRBL (JB5)

Time Pos. Expected Actions/Behavior Comments AR P-i .6 version 67, Annunciator response procedure,_FGI_and_FH1_actions BOP Reference ARP and check R-70s to determine SG in alarm.

SRO - Notify Chemistry of the alarm condition

- Direct entry into AOP-2.0, version 33 BOP Check ARP FH1 for actions as Rad monitors come into alarm.

- Do not allow personnel to enter the affected area without the approval of the Health_Physics_Department.

SRO IF R-15 alarms AND remains above the alarm setpoint (not a momentary spike),

THEN pertorm the following:

- IF high effluent activity is possible, THEN implement EIP-9.0, ACTIONS.

- Notify the Counting Room to immediately Call Counting Room sample the SGs per CCP-31 to determine the leak rate.

- Notify the Operations Shift Manager. Call SM IF R-19 alarms refer to SOP-45.0 for guidance in sampling SGs with R-19 in alarm.

IF R-23A OR R-23B alarms, contact the RAD man to verify SGBD secured.

4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 5 of 43 Event Desciiption: 1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected Actions!Behavior Comments SRO Direct entry into AOP-2.0 RO (step 1) Maintain pressurizer level stable at NOTE: This is a continuing normal programmed value by: action step

- Control charging FK-122 adjusted as required

- Reduce letdown close HV-8149 A, B, C close one or more orifice isol.

valves

- Determine leak rate, if possible RO (step 2) Maintain VCT level greater than NOTE: This is a continuing 20%. by: action step Verify RMW system in AUTO RNO is to trip the Rx and OR actuate an SI Manually control makeup as required by using SOP-2.3 BOP (step 3) Check that the Continuous Radiation Monitoring System is operable Either R-1 5- OPERABLE OR R-70s- OPERABLE SRO (step 4) Check reactor power conditions:

- Check NO power ascension in progress

- Check NO power reduction in progress

- Check reactor power greater than 20%

BOP (step 5) Monitor primary to secondary NOTE: This is a continuing leakage action step Check R-70s or R-15 for increasing count rate Begin trending R-70A and R-15 using the Chemistry will acknowledge plant computer and Data sheet 1. CCP-31 app C BOP (step 6) Call TBSO to place SJAE filtration on service.

5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 6 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected ActionslBehavior Comments SRO (step 7) Direct chemistry to perform grab samples and leak rate determinations.

CCP-201 Table 55 NOTE: This is a continuing (step 8) Notify SM of leak rate action step (step 9) Continue to monitor R-70s, r-15 or NOTE: This is a continuing CHM/HP leak rate input for primary to action step secondary leak rate and rate of change using Data sheet 1.

(step 10) Evaluate Table to determine appropriate response:

- ACTION LEVEL 4 30 gpd/hr rate of increase fjQ 75 gpd Proceed to step 1 1 leak in any SG BOP (Step 11) Check any two of the following rad monitors trending in the same direction:

- R-70s/R-15 OR R-70s/R-23A(B) OR R-1 5/R-23A(B) trending in the same direction with the same order of magnitude SRO Direct reducing power to 50% rated Use AOP-1 7 for rapid ramp >5 thermal power within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and place the MW/mm Unit in Mode 3 within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months . (3 hrs total)

- Identify the correct leaking SG 1C SG has a 15 gpm tube leak Using R-70s, R-60s and level rise in any SG BOP - Commence the ramp to <50% power in This may be 6 10 MW/mm the next 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months (STP-746) and AOP-1 7 would be entered.

- Calculates ramp speed RO (step 13) Verify rods are in AUTO or MANUAL as desired 6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 7 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected Actions/Behavior Comments SRO (step 14) Contact Rx Engineering for fast ramp recovery recommendations BOP (step 15) Reduce turbine load at desired rate in OPERATOR AUTO (DEH)

- Desired rate will be between 7 and 10 MW/rn in On the DEH panel:

- Press SETPOINT

- Set desired TARGET

- Select desired RATE

- Verify the HOLD light is LIT.

- Press the GO pushbutton and ensure the GO light is LIT

- Ensure the Main Turbine starts to ramp UP, GVs start to open.

RO (step 16) RO will maintain Tavg w/i +/-5°F of Continuing action step Tref by adjusting rod position or boron concentration.

(step 17) RO will adjust rod position to maintain Delta I w/l limits SOP-2.3 version 56, steps below 7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 8 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected Actions/Behavior Comments RO (Step 1.0) Borating per SOP-2.3 appendix B Version 56

. Set the boric acid integrator to the desired quantity NOTE: A continuous boration

. Adjust LTDN TO VCT FLOW LK 112 is allowed by appendix C setpoint as desired which maintains the BA

. M/U mode selector to STOP system lined up and the RO

. MKUP MODE SEL SWITCH to BOR will take the MSS to START

. MKUP MODE CONT SWITCH to START. each time a boration is (Step 1.6) Verify proper boration operation by required.

observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B opens.

BORIC ACID TO BLENDER FCV1 13A opens.

Boric acid flow is displayed on Fl-i 13 MAKEUP FLOW TO CHGNCT.

BOP! (step 18) Control secondary parameters Continuing action step RO - SG NR levels maintained at 65%

- Pzr level trending to or maintained on program

- Pzr pressure = to 2235 psig SRO (step 19) Check parameters w/l limits for Continuing action step continued operation

- PZRlevel>15%

- Pzr press > 2100 psig

- SG NR levels 35-65%

- Tavg 541 580° F

- Control bank LO-LO position clear (FE2)

- Delta I w/l limits RO (step 20) when power reduction completed Continuing action step then restore Tavg to programmed value SRO (step 23) Notify SRC of load change and sample requirements

.OP-2.0_here 8

Appendix D Operator Action Form ES-D-2 OpTestNo.: FA2011301 Scenario# 3 Event# 2 Page 9 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected Ans/Behavior Comments SRO (step 1 1.7) Call SM to evaluate emergency classifications per EIP-8.0 or EIP-9.0 SRO (step 16) Direct Chemistry to monitor the turbine building sump for activity SRO (step 17) Refer to FNP-0-AOP-2.1; Contingency Plan For Minimizing And Controlling Contaminated Secondary Condensate.

BOP (step 18) Verify affected SG(s) identified.

Check any SG level RISING IN AN UNEXPLAINED MANNER.

OR Check any SG radiation indication HIGH R-70 A, B, C and R-60 A, BC BOP (STEP 19) Verify affected SG(s) atmospheric relief valve-ALIGNED

- 8.25 and in AUTO BOP (STEP 20) Check affected SG atmospheric relief valve CLOSED (STEP 21) if TDAFWP is running or required then direct the counting room to perform CC P-645 (STEP 22) Isolate steam supply from affected SG(s) to TDAFWP from 1C SG by directing ROVER to do the following:

- Establish LOCAL control from HSD Panel AND Isolate TDAFNP steam supply from 1C SG by taking HV3235B in LOCAL and then to STOP BOP (STEP 23) Verify SGBD isolated from the 1 A SG- 7614A closed (STEP 24) Check AS supplied from Unit 2 Call SSS to align AS 9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 2 Page 10 of 43 Event

Description:

1A SG tube leak 15 gpm over 3 mm and stabilizes Time Pos. Expected Actions/Behavior Comments SRO (step 7 of ARP FG1) Evaluate Tech Specs 3.4.13 mandatory LCD RCS operational LEAKAGE shall be limited to:

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

Condition B- be in mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

TECHNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKAGE shall be limited to:

d. 150 gallons per day primary to secondary LEAKAGE through any one SG.

CONDITION REQUIRED ACTION COMPL ETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and AND associated B.2 Be in MODE 5. 36 Completion hours Time of Condition A not met.

OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

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

10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 3 Page 11 of 43 Event

Description:

PK-444A, Pzr pressure controller, fails HIGH PK-444A will go to 100% demand, Sprays will close and all heaters will be demanded ON. Actual pressure will increase, but the sprays and PORV-444B will not respond. If manual control of individual components is not taken, PORV-445A will open. Manual control of PK-444A is not possible due to the failure.

Indications Available:

Annunciators: Recognize indications of PK-444A FAILING

- PRZR PRESS REL 445A OR B/U HTRS HIGH ON (HD1) - PK-444A demand t

- All BU Htrs ON

- P05 pressure t Time Pos. Expected Actions/Behavior Comments A C )P-100, Instrumentation Malfunction, version 10, section 1.1 SRO Check RCS pressure stable or rising RCS pressure I Set control band for RCS pressure.

SRO SRO will direct entry to AOP-100.

RO (step 1) Verify RCS pressure is stable. NOTE: Step 1 and 2 are immediate operator action Take manual control of the PK-444A. Due to steps the failure mode, the RO can NOT take manual control of PK-444A

. Take manual control of the spray valves

. Take manual control heaters Control PRZR pressure Step 2 and 3 do not apply 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 3 Page 12 of 43 Event Descnption: PK-444A, Pzr pressure controller, fails HIGH Time Pos. Expected Actions/Behavior Comments RO (step 4) IF an alarm was caused by a component failure, THEN perform the following as required to restore RCS pressure to desired value.

Take manual control of the following as Required:

. PORVs

. Heaters

Spray valves Steps 5 and 6 do not apply SRO (step 7) Inform the SM of the failure.

SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO (step 10) IF the pressurizer PORVs operated, THEN perform the following:

. Refer to SOP-i .2, REACTOR COOLANT PRESSURE RELIEF SYSTEM, for cooldown of the PRT

. Refer to SOP-0.0, General Instructions To Operations Personnel, for reporting requirements.

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

12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 4 Page 13 of 43 Event

Description:

CST rupture crane accident CST level will decrease over a 5 mm time frame to 14 feet. The first alarm comes in at 16 feet so if the crew does not notice the decreasing level, the first alarm will be at about the 4 minute mark.

The DBSO will be sent out to look for the problem and then a report will be given about a crane accident.

Indications Available:

Annunciators: Recognize indications of CST LEVEL

- CST LVL HI-LO (JE5) Decreasing:

- CST LVL LO-LO A TRN and B TRN (JD4 - Ll-4005 B decreasing and JE4) - Computer alarms Time Pos. Expected Actions/Behavior Corn ments 150,000 gallons = 12 feet JE5, JD4, JE4, ARP-1 .9, Annunciator Response Frocedure, ver 46.

SRO Direct ARP reference (JE5) and a call to the DBSO to look for problems.

BOP (JE5 step 2) manually close CP-4055F hotwell fill controller, to avoid collapsing tank diaphragm.

BOP (JE5 step 3) Call Radside SO and have SGBD secured BOP (JE5 step 7) Direct DBSO to commence filling the tank (Unless report of rupture has come in)

SRO (JE4.JD4 step 1) Monitor condensate storage tank level on Ll-4005B, Ll-4132A and Ll-4132B to verify validity of alarm Direct BOP to monitor this issue 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 4 Page 14 of 43 Event

Description:

CST rupture crane accident Time Pos. Expected Actions/Behavior Comments (JE4.JD4 step 2) dttq to do thA See below for SOP-22, version followinci: 64, section 4.7 actions IF Auxiliary Feedwater is required and Tank Level if < 5.3 feet, THEN shift Auxiliary Feed Pump Suctions to the Service Water System per SOP-22.O, AUXILIARY FEEDWATER SYSTEM.

With no ramp down in progress, this will be a hard decision to make.

SRO (JE4.JD4 step 9) Evaluate Tech Specs 3.7.6 condition A Verify by administrative means OPERABLILITY of backup water supply wIl 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and restore the CST to OPERABLE status w/I 7 days See below for Tech specs TEC HNICAL SPECIFICATION 3.7.6, Condensate Storage Tank (CST)

The CST shall be OPERABLE. (> 150,000 GAL)

SRO CONDITION REQUIRED ACTION COMPLETION TIME A. CST A.1 Verify by administrative 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable. means OPERABILITY of AND backup water supply. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND thereafter A.2 Restore CST to OPERABLE status. 7 days SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO Inform the SM of the failure and Tech Spec entry 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 4 Page 15 of 43 Event Descnption: CST rupture crane accident Time Pos. Expected Actions/Behavior Comments SOP-22, version 65, section 4.7 actions SOP (step 4.7.1) Notify Shift Chemist that SW will be added to the SGs.

(step 4.7.2) Verify service water is in operation per SOP-24.O, SERVICE WATER SYSTEM maintaining proper SW pressure.

(step 4.7.3) Open MDAFWP SW SUPP:

(BOP key operated switches)

M0V3209A

M0V3209B (step 4.7.4) Open: (SOP)

MDAFWP SW SUPP MOV321OA

MDAFWP SW SUPP MOV321OB

TDAFWP SW SUPP M0V321 6.

(step 4.7.5) Place AFW system in operation per section 4.1 or 4.3 of this SOP.

When SW is aligned to the AFW pumps and Tech Specs have been evaluated then move to Event #5.

15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 5 Page 16 of 43 Event

Description:

PT-464, Stm header pressure transmitter, fails HIGH PT-464 will fail high. SGFP speed will increase causing FRVs to close down due to higher Feed flow than steam flow. SG NR levels will increase to a trip setpoint if SGFP speed is not controlled in a timely manner.

Indications Available:

Annunciators: Indications of PT-464 failure:

- 1A SG LVL DEV (JF1) - Pl-464A increasing to 1200 psig

- lB SG LVL DEV (JF2) - Rx power increasing

- 1C SG LVL DEV (JF3) - SGFP speed increasing Time Pos. Expected Actions/Behavior Comments AOP-100, version 10, section 1.4, will be entered SRO Directs RO or BOP to address ARP5 as time permits

. 1A,1B,&1CSGLVLDEV (JF1,2

& 3)

CHG HDR FLOW HI-LO (EA2)

SRO Directs entry into AOP-100, section 1.4, and performance of immediate actions, then directs subsequent actions BOP (step 1) Maintain SG level at the referenced Step 1 is an Immediate level of 65%. Operator action Take manual control of SGFP speed control NOTE: Step 1 is a continuing SK-509A taken to manual and decreases action step speed SRO (step 1 .3) IF a loss of main feedwater has occurred, THEN perform the actions required by AOP-1 3.0, LOSS OF MAIN FEEDWATER.

SRO (step 2) Set manual trip criteria on SG level (high and low trip setpoints are 82% & 28%

respectively)

BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.

16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 5 Page 17 of 43 Event

Description:

PT-464, Stm header pressure transmitter, fails HIGH Time Pos. Expected Actions/Behavior Comments BOP (step 4) Adjust speed of SGFPs to maintain approximate DP for the existing power level Unit 1 NO LOAD AP is 150 psid for 80%.

Approximate txP can be determined from the following MCB indications.

o SGFP DISCH PRESS P1-4003 o SG Pressure indications:

S/G CH H CH III CH IV A SIG P1-474 P1-475 P1-476 B S/G P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496

Unit 1 NO LOAD tiP is 50 psid from 0-28.1%. PROGRAM tiP is linear from 50-1 90 psid from 28.1% to 100%. TABLE 1 provides approximate tiP values for varying power levels.

%POWER QE 30 54psid 40 73 psid 50 93 psid 60 ll2psid 70 132 psid 80 151 psid 90 171 psid BOP (step 5) Check Stm Dumps in the Tavg mode SRO (step 6) Notifies Shift Manager SRO (step 8) Submits a CR & Notifies the Work Week Coordinator At the discretion of the Lead Examiner move to Event #6.

17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 6 Page 18 of 43 Event Desctlption: Slow Loss of air will cause a Rx trip to be called for This loss of IA is placed such that SA will isolate, and Essential air to the TB will isolate and IA to the Penetration rooms and ctmt will be unaffected. This will cause FRVs to lose air and slowly go go closed. The stby condensate pump will not auto start or manually start so as SGWLs decrease, the crew may increase SGFP speed but this will drop suction pressure to the SGFPs and cause a SGFP trip. This will prompt a reactor trip.

Indications Available:

Annunciators: Recognize indications of LOSS OF IA:

- IA PRESS LO (KD2) - P14001 A and B

- SA PRESS LO (KD3) - Various valve and indication erratic Eventually SGWLs will be affected

- 1A, 1B, 1C SG LVL DEV (JF1/2/3)

- 1A, 1B, IC SG STM FLOW> FEED FLOW_(JB1/2/3)

Pos. Expected ActionslBehavior Comments AOP-6.O, Loss of Instrument Air, version 38 SRO Notice loss of air and check IA compressors running and Direct entry to AOP-6 if the reactor is tripped due to a loss of instrument air, THEN the actions of this procedure should be implemented in conjunction with ESP-0.1, REACTOR TRIP RESPONSE SRO (step 1) WHEN the reactor is critical AND NOTE: SGFP suction pressure control of critical AOVs becomes erratic, will be very low or SG water THEN trip the reactor and go to levels will decrease to a low EEP-0, Reactor Trip Or Safety Injection. trip setpoint.

BOP (step 2) Start any available air compressor BOP (step 3) Direct TBSO to locate and isolate leaks in air header.

SRO Direct Reactor trip The RTBs will not open and the CRDM MG set breakers will not open. Go to event 7.

18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 19 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1A SGTR 500 gpm.

When the crew tries to trip the reactor, the reactor trip breakers will not open and the CRDM MG set breakers will not open. When PORV 445A opens, it will stick open. 1 A SG will rupture when the reactor trip breakers are opened. The crew may not see the SGTR at diagnostics due to RCS pressure so low. As RCS pressure increases when the PORV is isolated then the SGTR will be more evident. The crew may go to ESP-1 .1 if the SGTR is not identified at this point in the procedure.

Indications Available:

Annunciators: Recognize indications of ATWT event Various and many - RTBs still closed

- Nis indicate full power

- Conditions warrant a reactor trip and one is not received Enter EEP-O, Reactor Trip or Safety Injection, version 38 SRO Reactor trip Direct the reactor trip and enter EEP-O.

ROI Immediate Operator actions of EEP-O Immediate Action steps of BOP (step 1) Check reactor trip. EEP-O Check all reactor trip breakers and reactor NOTE: Reactor will NOT trip trip bypass breakers OPEN.

- FRP-S.1 entered at RNO steps Check nuclear power FALLING.

check rod bottom lights LIT. -

TRIP CRDM MG set supply breakers. RNO: Reactor is not tripped 1A(1 B) MG SET SUPP BKR by RTBs or CRDM MG sets.

[1 N1C11EOO5A

[] N1C11EOO5B SRO Direct entry into FRP S.1 and complete SteD 1 and 2 are IOA steos lOAs.

19

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 20 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CROM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1 A SGTR 500 gpm.

RO (step 1) IF reactor still NOT tripped, THEN Critical task perform the following: Insert negative reactivity Insert control rods in manual control.

OR Verify rods insert in AUTO at greater than 48 steps per minute.

3 minutes from this phone Dispatch an operator to locally trip the call RTBs will be opened reactor trip and bypass breakers. from BOOTH. The 1 A SGTR will occur when the RTBs are opened BOP (step 2) Check Main Turbine tripped BOP (step 3) Verify AFW pumps running

- Both MDAFWPs amps >0

- TDAFWP speed > 3900 rpm RO (step 4) Initiate Emergency Boration of the RCS.

- Verify at least one CHG PUMP -

RUNNING. Critical task

- Start a BAT pump Insert negative reactivity

- Open MOV81O4

- Establish normal letdwn flow 8149A and either 8149B or C open

- Check RCS pressure less than 2335 psig

- Establish normal charging flow > 40 gpm

- Verify adequate emergency boration flow of>3ogpmon_Fl-HO 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 21 of 43 Event Descnption: Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1 A SGTR 500 gpm.

BOP (step 5) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[J 3196

[1 3198A

[] 3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[] 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[j 2867D Will place HS to STOP Stop MINI PURGE SUPP/EXH FAN.

BOP (step 6) Check SI actuated BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB1 1-1 lit

[] MLB-1 1 1-1 lit See Tab at end of scenario for complete attachment 1 See attached sheets Attachment 1 actions.

for Attachment 1 of FRP-S.1 RO (step 7)

Check ALL RTBs open Check Main Turbine tripped 21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 22 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1A SGTR 500 gpm.

RO (step 8) Check if reactor still critical. NOTE: This is a continuing action step If RTBs are open or power range indication is < 5% power OR IR SUR is negative, then go to EEP-0 step 1 If not continue in this procedure.

SRO Transition back to EEP-0 RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

Check nuclear power FALLING.

check rod bottom lights LIT. -

Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED NOTE: 3 DGs will be running due to the SI signal A Train (F 41 60V bus) power available lights OATC will check SW header lit pressure, ctmt cooler flows and OR CCW Hx SW flows and SW B Train (G 4160V bus) power available lights pump lights lit Verify operating diesel generators are being supplied from at least one SW pump.

Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[j ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB1 111 lit 22

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 23 of 43 Event Descnption: Rx Trip will not work in auto or manual, and one CROM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1A SGTR 500 gpm.

SRO (step 5) Directs continuing into EEP-O at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the SOP to do attachment 2.

RO (step 6) Check containment pressure- HAS NOTE: [CA) step REMAINED LESS THAN 27 psig RO (step 7) Announce Unit 1 reactor trip and safety injection.

RO (step 8) Check AFW status.

Check secondary heat sink Available o Check total AFW flow> 395 gpm

[] Fl 3229A

[1 Fl 3229 B

[1 Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level > 31% {48%}

WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.

WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

23

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 24 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1 A SGTR 500 9pm.

RO (step 8.4) WHEN SO narrow range level greater than 31%{48%), THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[] B TRN reset MDAFWPTO lA/lB/iC SO BTRN

[1 FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR APPROACHING 547°F.

TAVG 1A(1B,1C) RCS LOOP

[1 TI 412D

[j TI 422D

[1 TI 432D 24

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 25 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1A SGTR 500 gpm.

RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column since 547°F and falling, THEN perform the RCS temp will be <5470 F following.

(step 9.1.1) Verify steam dumps closed. MSIVs may be closed by this STM DUMP INTERLOCK time in the procedure and this

[1 A TRN in OFF RESET RNO would not be done.

[1 B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB

[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG

[] Fl 3229A

[1 Fl 3229B

[1 Fl 3229C AFW TOTAL FLOW

[J Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.5. accomplish this task BOP (step 9.1 .6) If the cooldown continues then The cooldown will continue but close the MSIVs. is due to the AFW flow.

25

Appendix D Operator Action Form ES-D2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 26 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1 A SGTR 500 gpm.

RO (step 10) Check pressurizer PORVs and NOTE: [CA] step spray valves.

WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed. Critical task Verify both PRZR PORVs indicate CLOSED PORV 445A is open, close PORV ISO Valve, MOV-8000B Check PRZR PORV temperature STABLE (step 10.1 RNO) If any PORV OR FALLING. can NOT be closed then close

[] PORV Temp TI-463 the PZR PORV ISO Check PRT parameters STABLE or FALLING.

[1 PRT PRESS P1 472

[] PRT LVL LI-470

{] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C NOTE: [CA] step

[]PK444D Check any PRZR PORV ISO - OPEN RO (step 1 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <

Control charging pump miniflow valves 1300 and open when> 1900 based on RCS pressure. psig.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[1 P1 403A 26

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 3 Event # 7, 8 and 9 Page 27 of 43 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. PORV-445A will open and remain open and cause Pzr pressure to decrease. 1 A SGTR 500 gpm.

Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

SRO (step 13) Check SGs not faulted.

[1 Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psi .

9 ver_26.0 RO (step 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication -> 16°F{45°F} SUBCOOLED IN CETC MODE.

BOP (step 2) Identify ruptured SG(s). NOTE: this is a continuing action step Check any SG level RISING IN AN UNCONTROLLED MANNER SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: this is a continuing RO THEN isolate flow from ruptured SG(s). action step Verify ruptured SG(s) atmospheric relief valve ALIGNED.

- PC3371A set 8.25 and in auto

- Verify 3371A is closed Isolate steam supply from ruptured SO(s) to Neither lB or 1C SG is TDAFWP: N/A ruptured Verify blowdown from ruptured SG(s) - Closes 761 4A ISOLATED.

Verifies MSIV 3369A or 3370A (step 3.7) Verify at least one SO MSIV on 1A closed and bypass valves SG closed closed The steam fault will be put in at this point. FO page requirements send the operator to EEP-2.0 27

Op Test No.: FA2011301 Scenario # 3 Event # 10 Page 28 of 43 Event Descnption: 1A SG Fault outside containment and upsteam of MSIVs 1A SG has a SGTR and is NOW faulted.

EEP-2.0, Faulted SG Isolation, version 15, below.

Indications Available:

Annunciators: Recognize indications of SGTR with a fault:

- Rad monitors in alarm Recognize indications of SGTR

- Przr level falling rapidly

- RCS pressure dropping rapidly

- 1 A SG pressure stabilizes at a low pressure.

- When the 1A SG is isolated the SG water level will never decrease to 0 gpm.

Time Pos. Expected Actions/Behavior Comments Begin EEP- 2.0, version 14 actions here BOP (step 1) Verify all MSIV and bypass valves Critical task

- CLOSED. CLOSE MSIVs.

Place handswitches for all MSIVs to the CLOSED position (6 total)

BOP (step 2) Check if any SG not faulted. Only 1A SG will be blowing Check pressure in at least one SG STABLE

- down once the MSIVs are OR RISING. closed (step 3) Identify the faulted SG 1A SG 28

OpTestNo.: FA2011301 Scenario# 3 Event# 10 Page 29 of 43 Event Descnption: 1A SG Fault outside containment and upsteam of MSIVs Time Pos. Expected Actions/Behavior Comments BOP (step 4) Isolate all faulted SGs. PC3371A, B, C minimum

- Verify ALL ARVs closed - demand

- Verify ALL Feed stop valves closed M0V3232A, B, C

- Verify blowdown from all faulted SGs HV 7614A

- ISOLATED.

o Isolate TDAFWP steam supply from lB SG.

The TDAFW pump should IF TDAFWP NOT required, THEN isolate not be required.

TDAFWP steam supply from 1 B SG at HSD panel. This will be called to the TDAFWP STM SUPP FROM 1 B SG booth to be completed by

[] Q1N12HV3235A/26 in LOCAL the extra operator (HSDP- F)

TDAFWPSTM SUPP FROM 1BSG

[1 Q1N12HV3235A126 to STOP (HSDP-D)

BOP (step 4.6) Verify SG blowdown sample ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE ISO

[1 MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed BOP (step 5) Isolate AFW flow to all faulted Critical task SGs.

Close MDAFWP isolation valves to all faulted SGs. (BOP)

Close TDAFWP flow control valves to all Critical task faulted SGs. AFW isolated by either this TDAFWP FCV 3228 step or vOl7A called for.

[1 RESET 29

Op Test No.: FA2011301 Scenario # 3 Event # 10 Page 30 of 43 Event

Description:

1A SG Fault outside containment and upsteam of MSIVs Time Pos. Expected Actions/Behavior Comments SRO Call to SSS-P or TSC to have 01 N23V01 7A key Z-1 39 closed in the MSVR BOP (step 6) Check CST level greater than 5.3 [] R-1 5 feet [1 19

[1 23A and B (step 7) Check secondary radiation [1 15B and C, indication NORMAL.

[] 60 A, B, C, D SRO Direct transition to EEP-3, SGTR.

The intent of Step 7 is to transition to EEP-3 if a known SGTR ex sts. Since there is a Rx trip and SI at this point the secondary radiation monitors will not indicate a SGTR. However, the 1A SG has a Fault and a Tube rupture and should be identified and EEP-3 entered.

beiow BOP (step 4) WHEN ruptured SG(s) NR level NOTE: this is a continuing greater than 31% THEN perform the action step following:

Isolate AFW flow to ruptured SG(s) using FCVs.

- FCV 3227A in MOD, and closed

- HV 3328A in MOD and closed SRO (step 5) Check ruptured SG(s) pressure Go to ECP-3.1 transition at GREATER THAN 250 psig. this step When the 1 A MSIVs and the AFW flow to the 1 A SG is isolated, then terminate the exam.

30

Op Test No: FA2011301 Scenario # 3 Event # 7 Page 31 of 43 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-0 Atthmønt 9 of EEP-O AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train STARTED.

BOP [}Atrain(lAorlB)amps>0

[1 B train (1 C or 1 B) amps> 0 BOP (Step 2) Verify RHR PUMPs STARTED.-

RHR PUMP

[1 1A amps > 0

[] lB amps >0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow GREATER THAN 0 gpm.

[] Fl 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow greater than 1.5 XlO gpm 3

[] 1A RHR HDR FLOW Fl-605A

[1 lB RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[1 A train (1A,1B or 1C)

[1 B train (1D,lEor 1C) 31

Op Test No.: FA2011301 Scenario # 3 Event# 7 Page 32 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -

STARTED.

(Step 2.1) Verify one CCW PUMP in each train- STARTED.

A train HX 1 C or 1 B CCW FLOW

[J Fl 3043CA > 0 gpm OR

[1 Fl 3043BA >0 gpm B train HX 1A or lB CCW FLOW

[1 Fl 3043AA> 0 gpm OR

[1 Fl 3043BA > 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA >0 gpm

[1 Q1 P1 6F13009BA > 0 gpm

{] Q1 P1 6F13009CA > 0 gpm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[1 1A

[1 1 B

[1 1C Check INST AIR PRESS P1 4004B greater than 85 psig.

32

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 33 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[} 3198D

[1 3198C

[] 3196

[] 3198A

[] 3198B Verify containment mini purge dampers -

C LOS ED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[1 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[1 2866D

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 33

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 34 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train

[1 1A

[] 1 B B train

[1 1C

[] 1 D Verify associated emergency service water outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] 01 P1 6MOV3024A

[1 Q1P16MOV3O24B

[] Q1 P1 6M0V3024C

[1 Q1 P1 6MOV3024D BOP (step 8) Verify AFW Pumps STARTED.

Verify both MDAFW Pumps STARTED-

[] 1A MDAFW Pump amps >0

[1 lB MDAFW Pump amps >0 AND

[1 Fl-3229A indicates > 0 gpm

[J FI-3229B indicates > 0 gpm

[j FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

ECondition ETSLB E1Setoint ECoincidence D RCP Bus TSLB2 1-1 L12680 V 1/2 Detectors Undervoltacie 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1 4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1 6-2,6-3 34

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 35 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 8.3) Verify TDAFWP started.

[] MLB-4 1-3 lit

[] MLB-4 2-3 lit

[1 MLB-4 3-3 lit TDAFWP SPEED

[151 3411A>3900 rpm TDAFWP SPEED CONT

[1 SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWPTO 1A(1B,1C) SG

[1 Q1N23HV3228A in MOD

[] Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C)SG FLOW CONT

[1 HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open 35

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 36 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

1A(1B,1C) SG FW FLOW

{] FCV 478

[1 FCV 488

[1 FCV 498 Verify both SGFPs TRIPPED.

Verify SG blowdown ISOLATED.

1A(1B,1C) SGBD ISO

[] Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[1 MLB1 1 9-2 lit Q1 P1 5HV3328 closed

[1 MLB1 19-3 lit 01 P1 5HV3329 closed

[1 MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 213 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.

(Step 11.1) Verify PHASE A CTMT ISO -

ACTUATED.

BOP [1 MLB-2 1-1 lit

[1 MLB-2 1 1-1 lit 1 1 .2 Check all MLB-2 lights LIT.

36

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 37 of 43 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11EOO5A

[1 N1C11EOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[1 1A

[1 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[1 1A

[1 lB If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate Will call TBSO to pumps per FNP-O-SOP-O.O, APPENDIX B, accomplish this.

TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.

37

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 38 of 43 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[1 A TRAIN

{] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810- OPEN

[] 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.

End of Attachment 2 38

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 39 of 43 Event

Description:

Attachment 4 of EEP-O Timel Pos. Expected ActionslBehavior I Comments Attachment 4 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DFO1 closed

[J Verify DFO2 closed

[1 Check DG15 closed

[] Verfiy DGO2 closed

[j Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.

[J Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[j Q1E21MOV8132B

[1 Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[]Q1E21MOV813OA

[] Q1E21MOV813OB

[] Q1E21MOV8131A

[]Q1E21MOV8131B 39

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 40 of 43 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected Actions/Behavior Comments (Step 1.7) Verify all post accident containment air mixing system fans STARTED. (BOP)

POST ACCIDENT MIXING FAN

[]1A

[j 1 B

[j1C

[]1 D RX CAV H2 DILUTION FAN

[1 1A

[]1B (Step 1.8) WHEN power restored to any de energized emergency bus, THEN verify alignment of associated equipment.

GOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 40

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 41 of 43 Event

Description:

Attachment 1 of FRP-S.1 Time Position Applicants Action or Behavior Attachment 1 of FRP-S.1 AUTOMATIC SAFETY INJECTION VERIFICATION BOP (step 1) Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR B Train (G & L) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 2) Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[jMLB-1 1-1 lit

[] MLB-1 1 1-1 lit BOP (step 3) Verify MEW status

- Verify main ERVs and bypass valves - valves CLOSED.

1A(1B,1C) SG STOP VLVFW FLOW

[] FCV 478

[1 FCV 488

[1 FCV 498

- Verify both SGFPs TRIPPED.

- Verify SGBD isolated HV 7614A, B C closed

- Verify SGBD sample valves closed by MLB-4 6-4, 7-4 and 8-4 LIT BOP (step 4) Verify Phase A actuated MLB-2 1-1 and 1 1-1 Lit all MLB-2 lights LIT BOP (step 5) Verify one CHG PUMP in each train - STARTED.

[J A train (1A or 1 B) amps > 0

[1 B train (1C or 16) amps > 0 BOP (step 6) Verify RHR PUMPs STARTED.

RHR PUMP lAandlBamps>0 41

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 42 of 43 Event

Description:

Attachment 1 of FRP-S.1 (step 7) Verify each train of CCW STARTED.

BOP Verify one CCW PUMP in each train- STARTED.

A train HX 1C or lB CCW FLOW

[1 Fl 3043CA> 0 gpm OR

[1 Fl 3043BA> 0 gpm B train HX 1A or lB CCW FLOW

[] Fl 3043AA> 0 gpm OR

[] Fl 3043BA > 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[] Qi P16FI3009AA > 0 gpm

[] Qi P16FI3009BA >0 gpm

[] Q1P16FI3009CA> 0 gpm (step 8) Verify each SW train - HAS TWO SW PUMPs STARTED.

[]A train (1A,lBor 1C)

[lB train (1D,lEor 1C)

BOP (step 9) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED D A train

[1 1A

[1 1 B E B train

[] 1C

[] 1 D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C1D) CTMT CLR

[1 Qi P1 6M0V3024A

[] Q1P16MOV3O24B

[1 Q1P16MOV3O24C 42

Op Test No.: FA2011301 Scenario # 3 Event # 7 Page 43 of 43 Event

Description:

Attachment 1 of FRP-S.1

[] Q1P16MOV3O24D BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 If a MSLI signal is present then close ALL MSIVs BOP (step 11) Check containment pressure -HAS REMAINED LESS THAN 27 psi 9

End of attachment 1 of FRP-S.1 43

Appendix D Crew Briefln2 sheet Form ES-D-2 Op-Test No.: FA2O1 1-30 1 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

Assign operating positions.

Ask for and answer questions.

Aupendix I) Turnover shett Form ES-D-2 FXlUnitl F lUnit2 Shift: Date I Off-going SS I Oncoming SS I [ ]N [ X] D Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, S, D, SW, X on key ring SS Unit 100% power RTP, MOL, 812 ppm Cb, 10,000 MWD, Eq Xe, (-2928)

Status TARGET ZERo STPs/Evolutions: Day. Every luh Sately B Train On-Service B Train Protected 1.0; 109.1 Noadi.; 63.7; FSP-20,0 Status of Special Testing General Information

1. 1 -2A DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

2. 1 B EHC pump TIO for motor bearing replacement. (OCS 6 hrs, ETR 2 hrs)

3. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia

4. Current Risk Assessment is GREEN and projected is 5.

6.

7.

8.

9.

Equipment Status 1 -2A DG Tagged out 1 B EHC pump is tagged out Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status 20 Gallon Dilutions as required to maintain #3 RHT On Service temperature and power.

WGS secured LCO Status 3.8.1 condition B, STP-27.1 completed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X] Yes [X I Yes [X] Yes [X]Yes [X]Yes [X] Yes

I Appendix D Scenario Outline Form ES-D-1 tRZ SUBM1TTA Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA201 1 -301 Examiners: Operators: SAC RO BOP Initial Conditions: 65% power, ramping down to MODE 3 due to Hurricane warnings in effect.

Winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 838 ppm, Xe

(-2939 pcm), MOL Turnover:

. l&C is working on PT-457 which failed low last shift.

. 1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETA 2 hrs)

. AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected.

- SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

1 R (RO & BOP) Ramp down at 5 MW/rn in 2 1 I (BOP) PT-508, Feedwater header pressure, fails high.

2 C (BOP) 1 C CCW pump trips (A Train CCW which is supplying CCW to 3 the on service Chg pump and is not the on service train).

TS (SRO) TS 3.7.7 3 C (RO) 1 A inverter fails and does not automatically transfer to the TS (SRO) bypass source. TS 3.8.7 and 3.8.9 4 C (RO) Letdown leak inside ctmt. This is an isolable leak by securing 5

letdown.

5 M (ALL) LOSP for BOTH units The 1A Vital panel will de-energize when the LOSP occurs.

6 spurious SI due to PT-457 failed low and all bistables tripped per Tech Specs.

6 C (RO) 1 C Chg pump does not auto start. Will have to manually start 7 either 1C or lB Chg pump (CT) and secure the 1A Chg pump which has no CCW flow to it.

7 M (ALL) When ESP-1 .1 or EEP-1 .0 entered then:

8 1A SG develops a large steam line break inside CTMT.

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 1 SUBMITTAL 8 C (BOP) 1 B CS pump does not auto start. (CT) 9 MOV 8820A does not open. (CT) 9 FRP-Z.1 orange path entry required with the conditions given if the 1 B CS pump is NOT started from the MCB prior to FRP-Z.1 entry.

10 Selected Ctmt coolers do not auto start. (CT) 11 C (BOP) 1 B MSIVs do not auto close. BOP will have to manually close one MSIV. (CT)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Changes in BLUE Removed the dropped rod due to exam overlap.

Farley May 2011 exam Page 2 of 6

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA2O1 1-301 Examiners: Operators: SAC RO BOP Initial Conditions: 65% power, ramping down to MODE 3 due to Hurricane warnings in effect.

Winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 838 ppm, Xe

(-2939 pcm), MOL Turnover:

l&C is working on PT-457 which failed low last shift.

1 B EHC pump T/O for motor bearing replacement. (QOS 6 hrs, ETR 2 hrs)

AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 A (RO & BOP) Ramp down at 5 MW/rn in 2 1 I (BOP) PT-508, Feedwater header pressure, fails high.

2 C (BOP) 1 C CCW pump trips (A Train CCW which is supplying COW to 3 the on service Chg pump and is not the on service train).

TS (SRO) TS 3.7.7 3 C (RO) 1 A inverter fails and does not automatically transfer to the 4

TS (SRO) bypass source. TS 3.8.7 and 3.8.9 4 C (RO) Letdown leak inside ctrnt. This is an isolable leak by securing letdown.

5 M (ALL) LOSP for BOTH units The 1A Vital panel will de-energize when the LOSP occurs.

6 spurious SI due to PT-457 failed low and all bistables tripped per Tech Specs.

6 C (RO) 1 C Chg pump does not auto start. Will have to manually start 7 either 10 or 18 Chg pump (CT) and secure the 1A Ohg pump which has no COW flow to it.

7 M (ALL) When ESP-1.1 or EEP-1.0 entered then:

8 1A SG develops a large steam line break inside CTMT.

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 8 C (BOP) 1 B CS pump does not auto start. (CT) 9 MOV 8820A does not open. (CT) 9 FRP-Z.1 orange path entry required with the conditions given if the 1 B CS pump is NOT started from the MCB prior to FRP-Z.1 entry.

10 Selected Ctmt coolers do not auto start. (CT) 11 C (BOP) 1 B MSIVs do not auto close. BOP will have to manually close one MSIV. (CT)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 6

Appendix D Scenario Pre-sets Form ES-D-1 6 0 Block reactor trip A and B Train

CMFmalf I cBKRXTRP_cc5 I open CMFmalf I cBKRXTRP_cc6 I open 0 0 Tag out 1 B EH pump

CMFmalt I cmshfpb_cp2 9 0 1 B CS pump does not auto start will start from MCB CMFmalf/ cbkpOlb_d_cc5/ open 9 0 1 B MSIVs will not close on the auto closure

CMFm alt! crshool b_cc5 / open CMFmalf I cmsh0o2b_d_cc5 I open 4 0 1A Inverter static xfer switch failure

Malt I E I mt mal-eps-invsa 0 0 PT-457 low

XMT/pt457! 1700 7 0 1 C Chg pump does not auto start

imf cCVPO1C_d_cc6 open imf cCVPO1C_dcc3 open 9 0 1 D ctmt coolers do not auto start

CMFmalf I cchfldl_d_cc3 / open CMFmalf I cchf 1 dl_d_cc4 / open 9 0 1 B ctmt cooler trips when steam leak comes in Trigger 2 CMFmalf! cchf 1 bl_d_col (2 0) I Trigger 2 9 0 MOV 8820A does not open on phase B

CMFmalf I cbk882Oa_d_cc5 / open 0 0 trip pt457 hi press bistable Trip bistables for PT457 imf jpb457a-o tripped trip p1 1 bistable associated with pt457 imf jpb457b-o tripped trip otdt rod stop for 457 mt jtb432c2-o tripped trip otdt trip for 457 imf jtb432cl -o tripped Defeat PT457 input to B tm ICCMS irt loa-iccbo9 true 6 0 1 A vital panel de-energizes Trigger 4 LOA-BK1 021 FALSE I Trigger 4 Triggers and Commands 9 0 Trigger 2 monitors ctmt pressure. P1951 > 10 Event: pi951 > 10 6 0 Trigger 4 Rx trip breakers open Event: j52rtao && j52rtbo Farley May 2011 exam Page 3 of 6

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 65% power, ramping down to MODE 3 due to Hurricane warnings in effect.

Winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 838 ppm, Xe

(-2939 pcm), MOL Turnover:

l&C is working on PT-457 which failed low last shift.

1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

Event 1 Ramp down in power at 5 MW/mm to be off line in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Verifiable actions: RO will adjust rods or boron to control TavgiTref on program, BOP will set up and start a ramp on the Main Turbine.

Event 2 PT-508 fails high. Enter AOP-100.

Verifiable actions: Take manual control of the SGFP speed as SGFP speed decrease.

SG water level will start to decrease.

Event 3 1C CCW pump trips. Enter AOP-9.O. TS 3.7.7 Verifiable actions: In the split train alignment the 1A CHG pump will be running. The 1A Chg pump will be secured and the 1 C Chg pump will be started.

Event 4 1A inverter fails and does not automatically transfer to the bypass source. The control room will have the Rover transfer to the bypass manually. TS 3.8.7 and 3.8.9.

(All RMW pumps will start, all BAT pumps will start, TCV-143 will shift to the VCT and LCV-1 15A will shift letdown to the RHT.)

Verifiable actions: LCV-1 15A will be returned to the VCT position, the BAT pumps secured, RMW pump secured, TCV-143 addressed.

Event 5 Letdown leak inside ctmt on letdown line between LCV-459 and orifice isolation vaklves.

Verifiable actions: Isolate the leak by closing LCV-459/460 and HV 81 49A, B and C. If the crew elects to trip the reactor during this event, then event 6 will not be used and event 7 entered directly.

Event 6 Dual unit LOSP. 1 -2A and 1 B DGs auto start to restore power.

1A Vital panel will de-energize when the LOSP occurs which will cause a spurious SI.

Event 7 1 C Chg pump does not auto start. Will have to manually start either 1C or 1 B Chg pump (CT) and secure the 1A Chg pump which has no CCW flow to it.

Event 8 When ESP-1 .1 entered (step 6) or EEP-1 .0 entered, the following event occurs:

1A SG develops a large steam line break inside ctmt.

Event 9 1 B CS pump does not start and MOV-8820A does not open.

Farley May 2011 exam Page4of6

Appendix D Scenario detailed summary sheet Form ES-D-1 Transition will have to be made to EEP-2 (FRP-Z.1) to isolate the faulted SG (CT) The selected ctmt cooler (1 D) does not auto start in slow speed and 1 B ctmt cooler trips when the Steam fault comes in (10 psig in ctmt).

FRP-Z.1 may be entered. A Train Phase B and Safety Injection will not automatically work due to the 1A vital panel; however, all components can be manipulated manually.

The 1 B CS pump does not start, the 1 A CS pump does not start due to the loss of the vital panel and MOV-8820A does not open. 1 B CS pump may be started at any time and M0V8820A opened (CT) and if done prior to FRP-Z.1 entry, then Z.1 does NOT have to be entered.

The 1 B MSIVs do not auto close on any auto signal. 1 B MSIV manual isolation is required (CT)

Terminate the scenario when ESP-1 .1 entered after either EEP-2.0 or EEP-1 .0.

UOP-3.1/AOP-1 00/ AOP-1 .0/ AOP-9/ ARP-WD1/ EEP-0/ESP-1 .1 or EEP-1 .0/ EEP 2(FRP-Z.1)/ ESP-1 .1 OR EEP-1 .0 then ESP-1 .1.

Farley May 2011 exam Page 5 of 6

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Establish flow from at least one HHSI pump before transition out of E-0 (start the 1C or 1 B Chg pump). (WOG CT E-0 - - I)

2. Manually actuate at least the minimum required complement of containment cooling equipment before an extreme (red-path) challenge develops to the containment CSF.

(WOG CT E-0 - - E)

Start the 1 B CS pump and/or open MOV-8820A and/or start 1 ctmt cooler in slow with emergency SW aligned after Containment pressure is/has been>

27 psig, and prior to a Red Path on FRP-Z.1 (54 psig).

Requirement is 1 ctmt cooler fan and 1 CS pump or 2 CS pumps.

3. Isolate the 1 A SG (Feed flow and steam flow) and isolate the 1 B SG steam flow (WOG CT E-2 - - A)

SCENARIO Ramp down in progress.

OBJECTIVE! The team should be able to:

Respond to a failed equipment and instruments and complete the appropriate OIER,IEAI.

V VI VY.

ARPs, AOP-1 00, AOP-9 & Tech Specs

Identify a spurious SI and then respond to a faulted SG inside ctmt, reinitiate SI flow, recognize that 1A Chg pump did not autostart and start the 1A or lB Chg pump as required per EEP-O. Then transition properly to ESP-1 .1 or EEP-1 .0, FRP-Z.1 (as required) and EEP-2, then back to ESP-1 .1.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 11

2. Malfunctions after EOP entry (12) 6

3. Abnormal events (24) 4

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 1 possible

7. Critical tasks (23) 3 Farley May 2011 exam Page 6 of 6

Scenario #2 FA2O1 1301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #2 Validation time: 105 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approval: Gary Ohmstede Date: 2/7/201 1 NRC Chief Examiner Ron AieIlo Date:

SOUTHERN AL COMPANY

Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: 2011 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 65% power, ramping down to MODE 3 due to Hurricane warnings in effect.

Winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 838 ppm, Xe

(-2939 pcm), MOL Turnover:

l&C is working on PT-457 which failed low last shift.

1 B EHC pump TIC for motor bearing replacement. (OCS 6 hrs, ETA 2 his)

AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

SPLIT TRAIN ALIGNMENT Event Malt. Event Type* Event Description No. No.

1 R (RO & BOP) Ramp down at 5 MW/mm 2 1 I (BOP) PT-508, Feedwater header pressure, fails high.

2 C (BOP) 1 C CCW pump trips (A Train CCW which is supplying CCW to 3 the on service Chg pump and is not the on service train).

TS (SRO) TS 3.7.7 3 C (AC) 1 A inverter fails and does not automatically transfer to the TS (SRO) bypass source. TS 3.8.7 and 3.8.9 4 C (RO) Letdown leak inside ctmt. This is an isolable leak by securing letdown.

5 M (ALL) LOSP for BOTH units The 1 A Vital panel will de-energize when the LOSP occurs.

6 spurious SI due to PT-457 failed low and all bistables tripped per Tech Specs.

6 C (AC) 1 C Chg pump does not auto start. Will have to manually start 7 either 10 or 1 B Chg pump (CT) and secure the 1 A Chg pump which has no COW flow to it.

7 M (ALL) When ESP-1.1 or EEP-1.O entered then:

8 1A SG develops a large steam line break inside CTMT.

FarleyMay2Oll exam Page2ofl5

Appendix D Scenario #2 Outline Form ES-D-1 8 C (BOP) 1 B CS pump does not auto start. (CT) 9 MOV 8820A does not open. (CT) 9 FRP-Z.1 orange path entry required with the conditions given if the 1 B CS pump is NOT started from the MCB prior to FRP-Z.1 entry.

10 Selected Ctmt coolers do not auto start. (CT) 11 C (BOP) 1 B MSIVs do not auto close. BOP will have to manually close one MSIV. (CT)

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 3 of 15

Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Base IC-214 65% RTP. MOL, B Train 0/S B Train protected Cb=838 ppm, Xe (-2939 pcm)

UOP-3.1, v.106.0 at step 8.10 RUN

[

RUN simulator 0 0 Generic setup:

bat generic_setup_H LT.txt 0 0 Quick setup (all items with

are included):

bat 201 1 nrcexam_02.txt Defeat PT455 input to B train ICCMS:

REMOTE/B14/LOA ICCAO9/True JICCBOO9 This is part of the setup below and is a check to make sure it is defeated PRESETS 6 0 Block reactor trip A and B Train CMFmalf I cBKRXTRP_cc5 / open CMFmalf I cBKRXTRP_cc6 / open 0 0 Tag out lB EH pump

CMFmalf I cmshfpb_cp2 9 0 1 B CS pump does not auto start will start from MOB CMFmalf I cbkpOlb_d_cc5/ open 9 0 18 MSIVs will not close on the auto closure

OMFmalf / crshoOl b_cc5 / open CMFmalf I cmshOO2b_d_cc5 / open 4 0 1A Inverter static xfer switch failure

Malf / E / imf mal-eps-invsa 0 0 PT-457 low

XMT / pt457 /1700 7 0 10 Chg pump does not auto start

imf cCVPO1C_d_cc6 open imf cCVPO1C_d_cc3 open 9 0 1 D ctmt coolers do not auto start

CMFmalf / cchf 1 dl_d_cc3 / open CMFmalf / cchf 1 dl_d_cc4 / open 9 0 1 B ctmt cooler trips when steam leak comes in Trigger 2 CMFmalf / cchf 1 bl_d_col (2 0) I Trigger 2 9 0 MOV 8820A does not open on phase B

CMFmalf / cbk882Oa_d_cc5 / open 0 0 trip pt457 hi press bistable Trip bistables for PT457 imf jpb457a-o tripped Farley May 2011 exam Page 4 of 15

Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS trij 11 1 bistable associated with rt457 imf jpb457b-o tripped trij otdt rod stoD for 457 imf jtb432c2-o tripped trir otdt trilD for 457 imf jtb432cl -o tripped Defeat PT457 inrut to B tm ICCMS iii Ioa-iccbO9 true 6 0 1 A vital panel de-energizes Trigger 4 LOA-BK1 021 FALSE I Trigger 4 Triggers_and_Commands 9 0 Trigger 2 monitors ctmt pressure. P195 1 > 10

Event: pi951 > 10 6 0 Trigger4

trgset 4 egenwebb < 0.8 Farley May 2011 exam Page 5 of 15

Appendix D Scenario 2 Simulator setup Form ES-D-1 MCB setup Set up DEH 40 MW target /5 MW/mm ramp rate DEH Pimp loop in service per step 8.2 1 B EH pump handswitch Place in OFF and TAG 1 HOLD tag Verify ctmt coolers are selected to 1 B and 1 D Switch check Ensure Pimp loop is in DEH Pimp loop is in DEH Clear DEH alarms Select POWER OPS PRIMARY on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared Provide a marked up copy of UOP-3.1 version 109 UOP-3.1 and AOP-21.0 through step 8.10 complete and signed off and AOP copy 21.0 version 29, Appendix III marked up through step

12. Step 12.1 should be circled to show that this step is in progress.

FE -

Perform Booth Onerators Setup Checklist Open Simview file to be used for plant parameter data :S collection:

Simview / sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 Seconds: clock(1) = 0 sv sim_clock.uvl VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 6 of 15

Appendix D Scenario 2 Booth Guide Form ES-D-l EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview tile On DataCollection.uvl tile press DATA for drop down_and_then_COLLECT_to_start_collecting_data 0 Begin Exam RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1 0 Ramp down at 5 MW/rn in 2 NRC PT-508, Feedwater header pressure, fails high.

CUE Xmt / pt508 /1400 / 85 second ramp 3 NRC 1C CCW pump trips CUE Cmfmalf/cccpolc_d_col 4 NRC 1A inverter fails and does not automatically transfer to CUE the bypass source.

Malf/ E / mal-eps-inva 5 NRC Letdown leak inside ctmt.

CUE Mal / mal-cvco2 13060 6 NRC LOSPforBOTH units CUE Malf/ E I imf mal-epsi / 1 The 1A Vital panel will de-energize when the LOSP occurs. spurious SI due to PT-457 failed low IRF LOA-BK1O21 FALSE/Trigger 4 Farley May 2011 exam Page 7 of 15

Appendix D Scenario 2 Booth Guide Form ES-D-l 7 preset 1 C Chg pump does not auto start No failure action See local operator action page to monitor and trip the 1A chci pump 8 At step When ESP-1 .1 step 6 read OR EEP-1 .0 step 1 read:

6 of THEN insert 1A SG develops a large steam line break ESP- inside CTMT.

1.1 MaIf / M / mal-mssl a I 10 / 180 9 preset 1 B CS pump does not auto start.

MOV 8820A does not open.

1 D Ctmt cooler does not auto start. 1 B Ctmt cooler trips at 10 psig in ctmt (trigger 2) preset 1 B MSIVs do not auto close. BOP will have to manually No failure action close one MSIV.

End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

g rpX.txt NOTE: Substitute grpX with grp 1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Verify ctmt coolers are selected to 1 A and 1 C Switch check AFTER THE LAST SCENARIO Farley May 2011 exam Page 8 of 15

Appendix D Scenario 2 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 When the 1A Chg pump We will not place 1 B CCW pump on B Train starts, watch 1A Chg pump temperature and trip the pump at 175°F Cmf malf/imf ccvpOl a_dco1 trip on high oil temp if required tchspoil(1) 4 WHEN REQUESTED Transfer 1A Inverter to the bypass source Remote /R21 I loa-epsOOl / true 5or8 IFREQUESTED MK4 LIQ PANEL alarm Clear MH1 Ann I MH1 I fail off imf mhl 2 6 WHEN REQUESTED 7 NONE REQUIRED Farley May 2011 exam Page 9 of 15

Appendix D Scenario 2 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 8 When the 1A Chg pump Use the button in event 3 to monitor and trip the 1A CHG PUMP.

starts, watch 1A Chg pump temperature and trip the pump at 175°F 9 5 minutes after Close VO17A requested Remote / loa-afwOO6 / 0 /20 second ramp Farley May 2011 exam Page 10 of 15

Appendix D Scenario 2 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

NONE REQUIRED 2 WHEN REQUESTED SSS-plant, SM and Dispatcher:

Recognize and repeat back PT-508 failure, CR in the cue and that type of communications.

3 WHEN REQUESTED ROVER:

The 1 C CCW pump breaker, DFO4, has an overcurrent trip flag.

There is a strong burnt insulation smell near the 1 C CCW pump.

SM! DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

4 WHEN REQUESTED ROVER and SSS-plant:

Reports

The inverter did not swap to the Bypass source.

The BYPASS SOURCE AVAILABLE light is LIT.

If asked to check breakers to power up Inverter say, All the breakers are closed.

Use event 4 LOA pane to transfer the inverter to the bypass source Report back that the lnverter is on the Bypass source when re energized.

5 WHEN REQUESTED Extra Operator:

The fire alarm is 1A-22 and I have acknowledged it on the fire alarm panel.

Radside SO:

The WHT high level alarm is in.

6 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SM/SSS:

I will get an extra operator to secure the running DGs ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

7 NONE REQUIRED FarleyMay 2011 exam Page 11 of 15

Appendix D Scenario 2 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

8 WHEN REQUESTED ROVER:

I will unlock and close Qi N23V017A key Z-139 FarleyMay 2011 exam Page 12 of 15

Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 65% power, ramping down to MODE 3 due to Hurricane warnings in effect.

Winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . 838 ppm, Xe

(-2939 pcm), MOL Turnover:

l&C is working on PT-457 which failed low last shift.

1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected.

Event 1 Ramp down in power at 5 MW/mm to be off line in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

Verifiable actions: RD will adjust rods or boron to control Tavg/Tref on program, BOP will set up and start a ramp on the Main Turbine.

Event 2 PT-508 fails high. Enter AOP-100.

Verifiable actions: Take manual control of the SGFP speed as SGFP speed decrease.

SG water level will start to decrease.

Event 3 1 C CCW pump trips. Enter AOP-9.O. TS 3.7.7 Verifiable actions: In the split train alignment the IA CHG pump will be running. The 1A Chg pump will be secured and the 1C Chg pump will be started.

Event 4 1A inverter fails and does not automatically transfer to the bypass source. The control room will have the Rover transfer to the bypass manually. TS 3.8.7 and 3.8.9.

(All RMW pumps will start, all BAT pumps will start, TCV-143 will shift to the VCT and LCV-1 1 5A will shift letdown to the RHT.)

Verifiable actions: LCV-1 1 5A will be returned to the VCT position, the BAT pumps secured, RMW pump secured, TCV-143 addressed.

Event 5 Letdown leak inside ctmt on letdown line between LCV-459 and orifice isolation vaklves.

Verifiable actions: Isolate the leak by closing LCV-459/460 and HV 81 49A, B and C. If the crew elects to trip the reactor during this event, then event 6 will not be used and event 7 entered directly.

Event 6 Dual unit LOSP. 1 -2A and 1 B DGs auto start to restore power.

1A Vital panel will de-energize when the LOSP occurs which will cause a spurious SI.

Event 7 1C Chg pump does not auto start. Will have to manually start either 1C or 1 B Chg pump (CT) and secure the 1A Chg pump which has no CCW flow to it.

Event 8 When ESP-1 .1 entered (step 6) or EEP-1 .0 entered, the following event occurs:

1A SG develops a large steam line break inside ctmt.

Event 9 1 B CS pump does start and MOV-8820A does not open.

Farley May 2011 exam Page 13 of 15

Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Transition will have to be made to EEP-2 (FRP-Z.1) to isolate the faulted SG (CT) The selected ctmt cooler (1 D) does not auto start in slow speed and 1 B ctmt cooler trips when the Steam fault comes in (10 psig in ctmt).

FRP-Z.1 may be entered. A Train Phase B and Safety Injection will not automatically work due to the 1A vital panel; however, all components can be manipulated manually.

The 1 B CS pump does not start, the 1 A CS pump does not start due to the loss of the vital panel and MOV-8820A does not open. 1 B CS pump may be started at any time and M0V8820A opened (CT) and if done prior to FRP-Z.1 entry, then Z.1 does NOT have to be entered.

The 1 B MSIVs do not auto close on any auto signal. 18 MSIV manual isolation is required (CT)

Terminate the scenario when ESP-1.1 entered after either EEP-2.0 or EEP-1.0.

UOP-3.1/AOP-1 00/ AOP-1 .0/ AOP-9/ ARP-WD1/ EEP-0/ESP-1 .1 or EEP-1 .0/ EEP 2(FRP-Z.1)/ ESP-1 .1 OR EEP-1 .0 then ESP-1 .1.

Farley May 2011 exam Page 14 of 15

Scenario 2 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET

1. Establish flow from at least one HHSI pump before transition out of E-0 (start the 1C or lB Chg pump). (WOG CT E-0 - - I)

2. Manually actuate at least the minimum required complement of containment cooling equipment before an extreme (red-path) challenge develops to the containment CSF. (WOG CT E-O - - E)

Start the 1 B CS pump and/or open MOV-8820A and/or start 1 ctmt cooler in slow with emergency SW aligned after Containment pressure is/has been > 27 psig, and prior to a Red Path on FRP-Z.1 (54 psig).

Requirement is 1 ctmt cooler fan and 1 CS pump or 2 CS pumps.

3. Isolate the 1A SG (Feed flow and steam flow) and isolate the 1 B SG steam flow (WOG CT E-2 - - A)

SCENARIO Ramp down in progress.

OBJECTIVE/OV The team should be able to:

ERVIEW:

Respond to a failed equipment and instruments and complete the appropriate ARPs, AOP-100, AOP-9 & Tech Specs

Identify a spurious SI and then respond to a faulted SG inside ctmt, reinitiate SI flow, recognize that 1A Chg pump did not autostart and start the 1A or lB Chg pump as required per EEP-0. Then transition properly to ESP-1 .1 or EEP-1 .0, FRP-Z.1 (as required) and EEP-2, then back to ESP-1 .1.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 11

2. Malfunctions after EOP entry (12) 6

3. Abnormal events (24) 4

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 1 possible

7. Critical tasks (23) 3 Farley May 2011 exam Page 15 of 15

AoDendix D Ooerator Action Form ES-D-2 Op Test No.: FA2011301 Scenario# 2 Event# 1 Page 1 of 48 0 [vent

Description:

Ramp down at 5 MW/mm Crew is expected to begin the ramp when shift is relieved and get to 5 MW/mm per the shift turnover sheet. Ramp will be on HOLD.

Indications Available:

Annunciators: none Other Indications Available: NA Time Pos. Expected Actions/Behavior Comments UOP-3. I, version 109, section 8.10 and AOP-21 .0 version 29 step 12.1 in progress of Appendix Ill. (Step 12.0) IF sustained hurricane winds are projected on-site THEN pertorm the following:

(12.1) IF sustained hurricane winds of 74 mph or greater are projected, THEN verify both units shutdown to at least Mode 3 two hours prior to projected winds reaching the plant site.

SRO Will direct ramp started lAW UOP-3.1, section 8.10.

SRO Direct (step 8.10) WHEN power level The ramp will continue down decreases to approximately 60% or less, from 65% at 5 MW/mm. This 0 THEN perform the following: remove a main feed pump from operation per SOP-21 .0, step will be performed when power is less than 60%.

Condensate And Feedwater System.

SRO/ At step 8.5 the following note explains how Flux is maintained +/- 5% from RO flux should be controlled: the target value NOTE: In the following step it is desirable to maintain axial flux difference within +/- 5%

from the target value to help ensure axial flux does not exceed limits specified in the COLR figure 3. During transients maintaining axial flux difference within the +/- 5% of the target value may not be possible.

BOP Begin lowering turbine load to 40 MW using NOTE: since the ramp rate will the appropriate DEH controls be 2 MW/mm, the BOP will

. Ensure load rate increase is within have to enter the desired rate required limitations, into DEH either before or after

. Verify the HOLD light is LIT. the start of the ramp.

. Depress the GO pushbutton and ensure the GO light is LIT.

. Ensure the Main Turbine starts to ramp down, GVs start to close.

0 1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 1 Page 2 of 48 C Event

Description:

Ramp down at 5 MW/mm Time Pos. Expected Actions/Behavior Comments RO Verify rods are in AUTO or Manual and maintaining Tavg close to Tref.

RO (Step 1.0) Borating per SOP-2.3 appendix B Version 56

Set the boric acid integrator to the desired quantity NOTE: A continuous boration

. Adjust LTDN TO VCT FLOW LK 112 is allowed by appendix C setpoint as desired which maintains the BA

. M/U mode selector to STOP system lined up and the RO

. MKUP MODE SEL SWITCH to BOR will take the MSS to START

. MKUP MODE CONT SWITCH to each time a boration is START. required.

(Step 1.6) Verify proper boration operation by observing the following:

On service boric acid pump started.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B opens.

BORIC ACID TO BLENDER FCV1 1 3A opens.

Boric acid flow is displayed on Fl-i 13 MAKEUP FLOW TO CHGNCT.

RO (Step 1.7) Verify the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:

Boric acid flow returns to zero as displayed on Fl-i 13 MAKEUP FLOW TO CHG/VCT.

MKUP TO CHG PUMP SUCTION HDR FCV1 1 3B closes.

BORIC ACID TO BLENDER FCV1 13A closes.

When 5% power ramp down complete then go to next event.

2

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 Event # 2 Page 3 of 48 C, FA2O1 1301 Event Descnption: PT-508, Feedwater header pressure, fails HIGH Afterwards, PT-508 will fail high and SGFP speed will decrease. The crew will enter AOP-100 and take manual control of the SGFP controller to increase speed and control SG water levels. If no action is taken the Reactor will trip at 28% SG NR levels.

Indications Available:

Annunciators: Recognize indications of PT-508 failure

- 1A,1 B,OR 1C SG STM FLOW> FEED - SGFP speed .

FLOW (JB1, JB2, JB3) - FRVs opening

- 1A,1B,OR 1C SG LVL DEV (JF1, JF2, - SGWL NR JF3) - Feed flows to zero Time Pos. Expected Actions/Behavior I Comments AOP-1 00 ver 10, Instrumentation Malfunction, section 1 .4 SRO Direct entry into AOP-100 BOP (step 1) mmfl*f onerator ction NOTE: Feed flows will be Check that steam and feed flows matched on decreasing and FRVs begin to all SGs open fully

- Take manual control of SK-509A and increase SGFP speed

- Possibly take manual control of all FRVs SRO (step 2) IF adverse trend in SG level exists, THEN establish trip criteria.

If any are approached then Trip the reactor and go to EEP-0.

BOP (step 3) Place the Main Turbine on HOLD BOP (step 4) Adjust SGFP speed back to within NOTE: Approximate £P can the normal operating range for the feed be determined from the flow/steam flow zP required for the existing following MCB indications.

power level. [ J SOFP DISCH PRESS See table below for values P14003

[ J SG Pressure indications 3

Appendix D Operator Action Form ES-D-2 Op Test No.: Scenario # 2 Event# 2 Page 4 of 48 C FA2011301 Event

Description:

PT-508, Feedwater header pressure, fails HIGH Time Pos. Expected Actions/Behavior Comments

Unit 1 NO LOAD P is 50 psid from 0-28.1%. PROGRAM P is linear from 50-190 psid from 28.1% to 100%. TABLE 1 provides approximate P values for varying power levels.

%POWER DP 30 54 psid 40 73psid 50 93 psid 60 ll2psid BOP (step 5.0) Check Steam Dumps in Tavg Mode.

- STM DUMP MODE SEL A-B TRN no (step 6 and 8)

- Call Shift Manager

- Submit a condition report on the failed instrument, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report At the discretion of the Lead Examiner move to Event #3.

4

Appendix D Operator Action Form ES-D-2 n Op Test No.: FA2011301 Event

Description:

Scenario # 2 Event #

1 C CCW pump trip on overcurrent 3 Page 5 of 48 1C CCW pump will trip and ARP AA3 entered. This ARP will direct the team to AOP-9.O where the on service charging will be started and the running pump secured. From this point on in the scenario there will not be any CCW to B Train components and if/when they start, they will have to be secured before they overheat.

Indications Available:

Annunciators: Recognize indications of 1C CCW pump trip:

- 1C CCW PUMP OVERLOAD TRIP (AA3) - FI-3043CA decreasing toO gpm

- CHG PUMP LUBE OIL TEMP HI (EA3) possible Time j Pos. Expected Actions/Behavior I Comments AA3, ARP-1.1, Annunciator Response Procedure, ver. 52.0.

AOP-9.0 Loss of CCW version 23 SRO Direct ARP entry for AA3 NOTE: This will send the SRO SRO will direct entry to AOP-9.O. to AOP-9.O at step 3 of ARP SRO (step 1) Verify CCW pump started in affected train.

BOP (step 1 RNO)

- Start the 1C Chg pump

- Secure the 1A Chg pump SRO (step 2) Check CCW system adequate for continued plant support.

BOP (step 2) Check the following: NOTE: Flow will be adequate

CCW flow adequate in affected train. Fl- since the off service train is the 3043BA has normal flow, one that was affected.

RCP motor bearing temps < 195°F.

CCW pump not cavitating.

CCW Surge tank level 13 inches BOP (step 3) Verify SW flow supplied to the ON NOTE: SW flow will be stable SERVICE train.

CCW HX SW DISCH

[J Q1P16FI3009AA 1A CCW HX DISC

[] 01 P1 6F13009BA 1 B CCW HX DISC

[1 Qi P16FI3009CA 1C CCW HX DLSC 5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 # 2 Event # 3 Page 6 of 48 C Event

Description:

Scenario 1C CCW pump trip on overcurrent Time Pos. Expected Actions/Behavior Comments SRO (step 4) Check ON SERVICE train affected. NOTE: On service train is NOT affected; The RNO column will send the SRO to step 9 RO (step 9) Check both RHR pumps stopped SRO (step 10) Inform the SM to check for classifications per EIP-8 and EIP-9 BOP (step 1 1) Call to Check SEP cooling aligned to an operating CCW train.

BOP (step 12) Check on service CCW train operating.

SRO AA3 step 5 says to refer to Tech Spec 3.7.7 for LCO requirements.

TECHNICAL SPECIFICATION 3.7.7, CCW System Two CCW trains shall be OPERABLE CONDITION REQUIRED ACTION COMPL ETION TIME A. One CCW A.1 ----NOTE 72 train inoperable. Enter applicable hours Conditions and Required Actions of LCO 3.4.6, RCS LoopsMODE 4, for RHR loops made inoperable by COW.

Restore CCW train to OPERABLE status.

SRO TS 3.7.7 Since 1C CCW pump tripped in the train that is not on service, there is only one train OPERABLE. 1 B CCW pump will have to be swapped to A Train and 1C CCW pump racked out to make the B Train OPERABLE.

6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 3 Page 7 of 48 C Event

Description:

1C CCW pump trip on overcurrent Time Pos. Expected Actions/Behavior Comments SRO Submit a condition report on the failed NOTE: There is no procedural component, and notify the Work Week guidance to place the 1 B CCW Coordinator (Maintenance ATL on pump to B Train with 1C CCW backshifts) of the condition report. pump tripped.

SRO Inform the SM of the failure and Tech Spec entry After rech Spec analysis and at the discretion of the Lead Examiner move to Event #4.

7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 4 Page 8 of 48 C Event

Description:

1A lnverter fails and does not transfer to the bypass source.

1A Inverter will fail and not transfer to the bypass source. At this power level the unit used to trip due to RCP BKR indication aligned to the inverter, but a design change removed that feature.

Many alarms will come in and many bistables will be LIT.

Indications Available:

Annunciators: (not a complete list) Recognize indications of 1A INVERTER

- 1A INV FAULT (WD1) FAILURE:

- SSPS A TRN TRBL (EC4) - Loss of power to N 1-41 with associated

- PROC CAB PWR FAILURE (EC1) alarms, bistable trip status lights and

- RCP BUS UV SINGLE INPUT ALERT indication (EF4) - Loss of power to the inverter (amps on

- RCP BUS UF SINGLE INPUT ALERT (EF5) EPB =0)

- There are many other annunciators and - Loss of power to channel I instruments bistables that come in to alarm (DK3, DEl, DF2,_DF3,_FD3,_FD4,_etc.)

Time Pos. Expected Actions/Behavior Comments WD1, ARP-2.2, Annunciator Response Procedure, ver 32 Team Recognize loss of inverter from alarms and CAUTION: Outward rod loss of NI5 motion is blocked by the High Power Rod Stop Bistable beinq tripped.

BOP Respond to alarms and recognize loss of inverter from loss of NIs and no amperage on 1A Inverter.

SRO Direct actions of WD1 NOTE: No reactor trip signals Assess plant and analyze IF a reactor trip is are present called for NOTE: The following controls may be affected if 1A 120 VAC Vital Instrumentation Panel is De-energized (Refer to A-506250, Unit 1 Load List):

A TRN SSPS output relay power is lost.

VCT Hi Lvl Divert Valve Qi E21 LCV1 1 5A diverts to the RHT if in auto.

LTDN Hi Temp Divert Valve Qi E21TCV143 bypasses the demineralizers.

1A & lB Reactor makeup water pumps start.

1A & lB BAT pumps start.

RMW to Blender FCV1 14B and Boric Acid to blender -FCV1 1 3A opens if Rx M/U Control System is in auto.

8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 4 Page 9 of 48 (J Event

Description:

1A Inverter fails and does not transfer to the bypass source.

Time Pos. Expected Actions/Behavior Comments BOP (step 1 B.) Call ROVER to Attempt to restore power from the bypass source by performing the following:

H: the BYPASS SOURCE AVAILABLE lamp is illuminated on the inverter, THEN transfer 1C INVERTER MANUAL BYPASS SWITCH to the BYPASS SOURCE TO LOAD position RO (step 2) Place LCV-1 15A, VCT HI LVL DIVERT VALVE, in the VCT position BOP (step 3) Secure 1 B RMW pump if necessary RO (step 4) Secure the running BAT pump if necessary BOP (step 5) Close FCV-1 1 4B, RMW TO If in AUTO BLENDER, and FCV-1 1 3A, BORIC ACID TO BLENDER.

SRO (step 6) 3.8.7 Condition A applies while the inverter is supplied from the bypass source and not connected to the battery. 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months mandatory LCO 3.8.9 Condition B applies for the time the vital panel was de-energized.

8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months mandatory LCO to restore the vital panel to operable status See below for Tech specs I TECHNICAL SPECIFICATION 3.8.7, InvertersOperating The required Train A and Train B inverters shall be OPERABLE.

CONDITION REQUIRED ACTION A. One required A.1 inverter Enter applicable Conditions inoperable, and Required Actions of LCO 3.8.9, Distribution Systems Operating with any vital bus de-energized.

Restore inverter to OPERABLE status.

9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 4 Page 10 of 48 Event

Description:

1A Inverter fails and does not transfer to the bypass source.

Time Pos. Expected ActionslBehavior Comments TECHNICAL SPECIFICATION 3.8.9, Distribution SystemsOperating Train A and Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE.

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more B.1 Restore AC vital bus 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months AC vital subsystem(s) to AND buses OPERABLE status. 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from inoperable. discovery of failure to meet LCO When the 1A inverter is transferred to the bypass complete the following:

RO (step 7A) Verify proper operation of the pressurizer heaters.

BOP (step 7B) Reset hi flux positive rate trip signal on NI-41 and verify proper operation of NI-41.

RO (step 7C) Verify the following CVCS components are correctly aligned for current plant conditions:

Q1E21LCV1 15A

Q1E21LCV115C & E

Q1E21LCV115B& D

Q1E21TC Vi 43 RO (step 7D) Verify the following Reactor Makeup Control System components are correctly aligned for current plant conditions:

Q1E21FCV113A

Q1E21FCV114B BOP (step 7E) Stop unnecessary Reactor Makeup NOTE: These were secured in Water and BAT pumps. the previous steps.

10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 4 Page 11 of 48 Event Descnption: 1A Inverter fails and does not transfer to the bypass source.

Time Pos. Expected Actions/Behavior Comments ALL Verify all other MCB controls and indications have returned to normal.

SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.

SRO Inform the SM of the failure and Tech Spec entry At the discretion of the Lead Examiner move to Event #5.

11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 5 Page 12 of 48 Event

Description:

Letdown leak inside ctmt.

A Letdown leak inside containment between LCV-459 and 8149A,B,C develops. The leak will cause ctmt temperature, pressure and humidity to increase over a period of time. The leak will be 130 gpm which is very close to a trip setpoint per AOP-1.0, and could be isolated if they recognize where it is. It is very hard to determine the location.

A Reactor trip may be called for here but that is neither is called for or required for these conditions. If a reactor trip occurs, Event 6 will be skipped.

Indications Available:

Annunciators: Indications of the Letdown leak:

- CHG HDR FLOW HI-LO (EA2) - TI-140, REGEN HX OUTLLET TEMP

- RMS HI RAD (FH1) increases

- Li-i 1 2B and 1 15, VCT LVL, decreasing

- Fl-122, CHG FLOW increasing

- LT-459, PRZR LEVEL, decerasing Time Pos. Expected Actions/Behavior Cornments AOP-1.0, RCS LEAKAGE, ver. 2C .0 SRO Directs performance of ARPs

- EA2, CHG HDR FLOW HI-LO

- FH1, RMS HI RAD (R-2, 7, & 12: CTMT radiation alarms in)

RO Reports pressurizer level is dropping with charging maximum.

Should diagnose and announce RCS leak.

SRO Directs entry into AOP-1 and directs actions per RO & BOP rows below:

RO (step 1) Maintain pressurizer level stable at NOTE: This is a continuing or near programmed level by: action step Take manual control of Control charging flow: charging flow OR Reduce letdown flow Removing letdown from OR service should be done per Isolating letdown- SOP-2.1, figure 1 on MCB The actions of figure 1 will isolate the leak.

12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 5 Page 13 of 48 Event Descnption: Letdown leak inside ctmt.

Time Pos. Expected Actions/Behavior Comments REMOVING LTDN FROM SERVICE

1. Place PK-145 in MANUAL and adjust demand to < 50%.

2. Close LTDN ORIF ISO 45 GPM, Q1E21HV8149A AND LTDN ORIF ISO 60 GPM, HV8149B OR HV8149C, as applicable.

3. Close LTDN LINE ISO, QIE21LCV459 and Q1E21LCV46O

4. Place FK-122 in MANUAL and adjust to 0% (closed).

5. Verify SEAL WTR INJECTION HIK 186 adjusted.

6. Refer to SOP-2. 1 when time permits.

RO (step 2) Maintain VCT level > 20% NOTE: This is a continuing action step

- Ensures Reactor makeup is in NOTE: IN AUTOMATIC AUTOMATIC to maintain VCT level>

20%

- RNO- if VCT level can not be maintained Q1E21LCV115B open

>20%, then align chg pump suctions to Q1E21LCV1 15D open RWST and Qi E21 LCV1 1 5C closed Q1E21 LCV1 15E closed RO (step 3) Determine leak rate based on flow balance (charging flow)

+ (seal injection flow)

- (letdown flow)

- (#1 seal leakoff flow)

= (RCS leak rate)

SRO (step 4) Leak rate should be determined to NOTE: This is a continuing be greater than 120 gpm. action step

- Tech Spec 3.4.13 should be evaluated> 1 LCO 3.4.13 Cond. A identified gpm unidentified leakage if location of as a MANDATORY LCO until leak is NOT known. location of leak is known when isolated.

13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 5 Page 14 of 48 Event

Description:

Letdown leak inside ctmt.

Time Pos. Expected Actions/Behavior Comments SRO (step 5) Informs Shift Manager of Leak rate NOTE: This is a continuing for classification and notification per EIP-8 & action step EIP-9.O

- need for CTMT entry to look for leak source

- T.S. requires fix leak in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or shutdown in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SRO (step 6) Directs Unit 2 UO or extra plant operator or SSS to align 1 A & 1 B post LOCA containment hydrogen analyzers for service using Attachment 1 RO (step 7) Frequently monitor CVCS flow balance as the actions of steps 7.2 through 7.12 are taken.

RO (step 7.2) Check LCV-1 1 5A in the VCT position SRO (step 7.3) Check containment sump level -

NOT RISING EXCESSIVELY Consult Shift Manager to evaluate NOTE: This is an RNO step requirement for containment entry BOP (step 7.4) Check containment radiation NOTE: CTMT radiation will be NORMAL elevated BOP (step 7 RNO) Evaluate placing CTMT sump NOTE: This is an RNO step pump handswitches in PULL-TO-LOCK to prevent overfilling the WHT.

Verify containment ventilation isolation

- Stop MINI PURGE SUPP!EXH FAN.

Verify containment mini purge dampers -

CLOSED.

- CTMTPURGEDMPRS MINI-2866C & 2867C

- CTMTPURGEDMPRS MINI-2866D_&_2867D 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 5 Page 15 of 48 Event

Description:

Letdown leak inside ctmt.

Time Pos. Expected Actions/Behavior Comments BOP (step 7.5) Check auxiliary building radiation -

NORMAL.

BOP (step 7.6) Check no SG tube leakage

- Check Secondary radiation NORMAL BOP (step 7.7) Checks CCW radiation monitors (R 17A/B)

SRO (step 8) WHEN the RCS leakage source NOTE: This is a continuing identified, THEN take appropriate actions to action step isolate the leak.

LCO 3.4.13 Cono. A is a MANDATORY LCO until the leak is isolated.

TECHNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; sf0 CONDITION REQUIRED ACTION COMPLETION TIME A. RCS A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months operational within limits.

LEAKAGE not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

When leak is isolated, Tech Specs evaluated or decision is made to shutdown and at the discretion of the Lead Examiner move to Event #6.

15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 16 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT457 failed low 1 C Chg pump does not auto start, 1 A Chg pump will not start due to the A Train vital panel be de-energized When the reactor is tripped an LOSP for BOTH units will occur and 1A Vital panel will de energize. This will cause a spurious Safety Injection to occur.

Indications Available:

Annunciators: Recognize indications of Spurious SI

- Many and various - Przr level increasing with all ECCS pumps running

- MLB-1-1 and 11-1 LIT Enter EEP-O, Reactor Trip or Safety Injection, version 40 SRO Reactor trip Direct the reactor trip and enter EEP-0.

16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 17 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor NOTE: Reactor will trip trip bypass breakers OPEN.

- automatically if setpoint Check nuclear power FALLING.

- reached.

check rod bottom lights LIT. -

(step 2) Check turbine TRIPPED.

TSLB2 14-1 thru 4 lit (step 3) Check power to 4160 V ESF busses.

4160 V ESF busses AT LEAST ONE ENERGIZED A Train (F 41 60V bus) power available lights lit NOTE: 4 DGs will be running OR due to the LOSP signal and B Train (G 41 60V bus) power available lights tied to the emergency busses.

lit OATC will check SW header pressure, ctmt cooler flows and Verify operating diesel generators are being CCW Hx SW flows and SW supplied from at least one SW pump. pump lights.

(step 4) Check SI Status.

Check any SI actuated indication. NOTE: Spurious B Train SI BYP & PERMISSIVE SAFETY INJECTION due to PT-457 failed low and

[]ACTUATED status light lit 1A Vital panel failed

[]MLB-1 1-1 lit

[1 MLB-1 11-1 lit SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to do attachment 2. ONE CRITICAL TASK In attachment 2 of EEP-0 (step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig 17

Appendix D Operator Action Form ES-D-2 OpTestNo.: FA2011301 Scenario# 2 Event# 6and7 Page 18 of 48 Event Descnption: LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO (step 7) Announce Unit 1 reactor trip and safety injection.

RO (step 8) Check AFW status.

Check secondary heat sink Available o Check total AFW flow> 395 gpm

[] Fl 3229A

[] Fl 3229 B

[] Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level > 31% {48%}

WHEN all SG narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.

WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%).

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[1 B TRN reset MDAFWPTO 1AJ1B!1CSG BTRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[} SIC 3405 adjusted 18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 19 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR APPROACHING 547°F.

TAVG 1A(1B,1C) RCS LOOP

[1 TI 412D

[] TI 422D

[] TI 432D RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column since 547°F and falling, THEN perform the RCS temp will be <547°F following.

(step 9.1.1) Verity steam dumps closed.

STM DUMP INTERLOCK

[] A TRN in OFF RESET

[1 B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB

[1 Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,1C) SG

[1 Fl 3229A

[1 Fl 3229B

[1 Fl 3229C AFW TOTAL FLOW

[] Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.6. accomplish this task 19

Appendix D Operator Action Form ESD-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 20 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO (step 10) Check pressurizer PORVs and spray valves.

WHEN pressurizer pressure less than 2335 NOTE: [CA] step psig, THEN verify both PRZR PORVs closed.

Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.

[] PRT PRESS P1 472

[1 PRT LVL LI-470

[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray NOTE: [CA] step valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[]PK444C

[]PK444D Check any PRZR PORV ISO OPEN -

RO (step 11) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <

Control charging pump miniflow valves 1300 and open when> 1900 based on RCS pressure. psig.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[] P1 403A 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 21 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

SRO (step 13) Check SGs not faulted.

[1 Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

SRO (step 14) Check SGs not ruptured.

[j Check secondary radiation indication -

NORMAL.

[1 Checks rad monitors R-15, 19, 23A and B, 1 5B and C, and 60 A, B, C, D

[] No SG level rising in an uncontrolled manner.

SRO (step 15) Check RCS intact. NOTE: Ctmt pressure will be Check containment radiation - rising and radiation monitors in

[] R-2 CTMT 155 ft alarm if the letdown leak was

[1 R-7 SEAL TABLE not isolated. This will lead the

[1 R-27A CTMT HIGH RANGE (BOP) crew to go to EEP-1 .0.

[1 R-27B CTMT HIGH RANGE (BOP)

If EEP-1 .0 entered here the 1A

[1 Check containment pressure LESS SG fault will be put in THAN 3 psi.

9

[] Check containment ECCS sump level LESS THAN 0.4 ft.

SRO (step 16) Check SI termination criteria RO (step 16.1) Check SCMM indication-> 16°F SUBCOOLED IN CETC MODE.

21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 22 of 48 Event Descnption: LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized BOP (step 16.2) Check secondary heat sink available.

Check total AFW flow to intact SGs > 395 gpm.

AFW FLOW TO 1A(1B,1C) SG

[] Fl 3229A

[] Fl 3229B

[1 Fl 3229C AFW TOTAL FLOW

[1 Fl 3229 OR Check at least one intact SG narrow range >31%.

RO (step 16.3) Check RCS pressure STABLE OR RISING.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[] P1 403A (step 16.4) Check pressurizer level -> 13%.

RO (step 17) Reset SI MLB-1 1-1 not lit (ATRN)

MLB-1 11-1 not lit (B TRN)

RO (step 18) stop all but one charging pump NOTE: Only one charging pump should be running at this time RO (step 19) Verify RCS pressure - STABLE OR Rising 1C(1A) LOOP RCS WR PRESS P1 402A AND P1 403A 22

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 23 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO (step 20) Isolate HHSI flow.

Verify charging pump miniflow valves -

OPEN.

1A(1B,1C) CHG PUMP MINIFLOW ISO

[1 Q1E21MOV81O9A

[1 Q1E21MOV81O9B

[] Q1E21MOV81O9C CHG PUMP MINIFLOW ISO

[1 Q1E21MOV81O6 Close HHSI isolation valves.

HHSI TO RCS CL ISO

[] Q1E21MOV88O3A

[1 Q1E21MOV88O3B RO (step 21) Establish normal charging.

Manually close CHG FLOW FK 122 Verify charging flow path aligned.

Verify charging pump discharge flow path -

ALIGN ED.

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A open

[1 Q1 E21 MOV81 32B open

[1 Qi E21 MOV81 33A open

[1 Q1E21MOV8133B open CHO PUMPS TO REGENERATIVE HX

[] Q1E21MOV81O7 open

[] Q1E21MOV81O8 open Verify only one charging line valve - OPEN.

RCS NORMAL CHG LINE

[1 Q1E21HV8146 RCS ALT CHG LINE

[] Q1E21HV8147 NOTE: The RCS may be approaching solid plant conditions. In the event the RCS must be operated water solid, charging flow should be adjusted to maintain subcooling instead of pressurizer level.

The RCS should not be water solid but if it is the note here applies 23

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2011301 Scenario # 2 Event # 6 and 7 Page 24 of 48 Event

Description:

LOSP for BOTH units spurious SI due to PT-457 failed low 1C Chg pump does not auto start, 1A Chg pump will not start due to the A Train vital panel be de-energized RO (step 21.2.3) Control charging flow to NOTE: [CA] step maintain pressurizer level 25%-50%

- Adjust FK-1 22 FK-1 22 should be fully closed Go To ESP-1.1, SI Termination, step 6 1A SG develops a large steam line break inside ctmt after ESP-1.1 entered and both RHR pumps are secured 24

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 25 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open When ESP-i .1 entered and at step 7 the 1A SG Steam Break will occur.

Indications Available:

Annunciators: Recognize indications of LARGE FEED BREAK

- Various and many INSIDE CTMT

- Fire alarm (MH1) - Ctmt pressure rising

- Hi ctmt pressure (EEl) (EE2) (EE3) - Przr level decreasing

- SG pressures decreasing

- Depoints in ctmt rising

- Ctmt cooler drains increasing Time Pos. Expected Actions!Behavior Comments ES P-i .1 FO page requirements: either or both may be done Greater than 16°F {45°F} subcooled in CETC RNO mode and PRZR level above 13% {43%} Establish HHSI flow using ATTACHMENT 3, RE-ESTABLISHING HHSI FLOW and go to EEP-1, Loss Of Reactor Or Secondary Coolant.

2 Monitor FNP-1-EEP-2 and FNP-1-EEP-3 2.1 IF affected SG NOT previously isolated, branch criteria. THEN go to FNP-i-EEP-2.

2.1 No SG pressure falling in an uncontrolled manner or less than 50 psig.

NOTE: The RCS may be approaching solid plant conditions. In the event the RCS must be operated water solid, charging flow should be adjusted to maintain subcooling instead of pressurizer level.

RO (step 6 ESP-1 .1) Adjust charging flow to RNO- IF solid plant operation maintain pressurizer level > 25% required, THEN control

- Adjust FK-l 22 charging flow to maintain subcooling greater than 1 6°F{45°F}.

25

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 26 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions!Behavior Comments RO (step 7) Secure LHSI system.

7.1 RHR pumps ANY RUNNING WITH SUCTION ALIGNED TO RWST.

7.2 Stop any RHR Pumps running with suction aligned to the RWST.

7.3 Check on service train RHR pump -

STOPPED.

7.4 Isolate CCW to the on service train RHR heat exchanger.

CCWTO 1A(1B) RHR HX

[J 01 P1 7M0 V31 85A closed OR

[] 01 P1 7M0V31 85B closed Information to examiner: There are several procedural flow paths and all are acceptable:

1. Foldout iae of ESP-1 .1 and step 8 says to verify SI flow not required. If this step is used for the event in progress, the team could establish HHSI flow using ATTACHMENT 3, RE-ESTABLISHING HHSI FLOW and then transition to EEP-1. EEP-1 will Check SGs not faulted at step 2 and then transition the team to EEP-2.

2. ESP-0.0, Rediacjnosis, could be used here if the team was unsure of the best procedure flowpath. Transition to EEP-2 would be directed by ESP-0.0.

3. Foldout acie of ESP-1 .1: The team could also go straight to EEP-2 without establishing SI flow. If EEP-1 .0 is entered from EEP-2.0 then HHSI flow would be established.

4. EEP-1 .0 from diagnostics, then step 2 or the EQ page to EEP-2.

When Ctmt pressure rises to >27 psig (Hl-3), the 1 B and 1 A CS pumps will not start and MOV 8820A will not open. The 1A CS pump will not start due to the vital panel failure. Transition to ERP-Z.1 would be required unless the lB CS pump is started or the 1A CS pump is started AND MOV-8820A is opened (flow to CS header).

Sf0! (step 8) Verify SI flow not required. RNO RO Check SUB COOLED MARGIN MONITOR Establish HHSI flow using indication GREATER THAN 16°F{45°F}

ATTACHMENT 3, SUBCOOLED IN CETC MODE. Re-Establishing HHSI Flow Check pressurizer level GREATER THAN Go to EEP-1.

1 3%{43%}.

26

Op Test No.: FA2O11SO1 Scenario # 2 Event # 8 and 9 Page 27 of 48 Event Descnption: 1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments Team The team should notice ctmt pressure rising, Pzrz level dropping and RCS pressure dropping and refer to the foldout page to make the transition or use step 8 above to transition to EEP-1 after SI re-initiation is in progress. (both are similar to the above step)

ESP-1.1, ATTACHMENT 3 RE-ESTABLISHING HHSI FLOW RO (step 1) Align charging pump suction to RWST.

RWST TO CHG PUMP

[] Q1E21LCV115B open

[1 Q1E21LCV115D open CHG PUMP SUCTION HDR ISO

[1 Q1E21MOV813OA open

[] Q1E21MOV813OB open

[1 Qi E21 MOV81 31 A open

[1 Q1 E21 MOV81 31 B open VCT OUTLET ISO

[1 01 E21 LCV1 150 closed

[}Q1E21LCV115E closed (step 2) Verify charging pump miniflow valves OPEN.

1A(1B,1C) CHG PUMP MINIFLOW ISO

[] Q1E21MOV81O9A

[] Q1E21MOV81O9B

[j Q1E21MOV81O9C CHG PUMP MINIFLOW ISO

[J 01 E21 MOV81 06 27

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 28 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments RO (step 3) Isolate normal letdown and charging.

LTDN ORIF ISO 45 GPM

[] 01 E21 HV81 49A closed

[] Q1E21HV8149B closed

[] Q1E21HV8149C closed LTDN LINE CTMT ISO

[] 01 E21 HV81 52 closed Manually close chg flow control valve.

FK 122 Verify charging flow path aligned.

CHG PUMP DISCH HDR ISO

[1 Q1E21MOV8132A open

[1 Q1E21MOV8132B open

[1 01 E21 MOV81 33A open

[1 Q1 E21 MOV81 33B open CHG PUMPS TO REGENERATIVE HX

[] Qi E21 MO V81 07 closed

[1 Q1E21MOVS1O8 closed RO (step 4) Open HHSI isolation valves.

HHSI TO RCS CL ISO

[1 Q1E21MOV88O3A

[] 01 E21 MOV88O3B RO (step 5) Start additional CHG PUMPs as required.

(step 6) Monitor charging pump miniflow criteria.

Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

[] P1 402A

[] P1 403A 28

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 29 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior I Comments Actions for FRP-Z.l below followed by EEP-2 SRO Direct transition to EEP-2 or FRP-Z.1 FRP-Z.1 below, EEP-2 on page 32 FRP-Z.1 actions here RO (step 1) Verify PHASE A CTMT ISO -

ACTUATED.

[] MLB-2 1-1 lit

[]MLB-211-1 lit (step 2) Check all MLB-2 lights LIT. -

- Verify containment ventilation isolation.

- Verify all containment purge dampers-CLOSED.

- Verify containment mini purge dampers -

CLOS ED.

- Stop MINI PURGE SUPP/EXH FAN.

RD (step 3) Check if containment spray is NOTE: [CA] step required.

- Containment pressure HAS RISEN TO GREATER THAN 27 psig.

- Verify PHASE B CTMT ISO ACTUATED Critical task Verify containment spray pumps 1 B CS Pump will need to be RUNNING started Check containment spray flow in both RNO trains > 0 gpm.

- VERIFY CS PUMP TO SPRAY HDR ISO MOV-8820A CS FLOW on Fl 958A and Fl 958B AND MOV-8820B open Critical task MOV-8820A will need to be opened and the 1A CS um started BOP Check all MLB-3 lights - LIT. A Train will need to be aligned RD Stop all RCPs.

29

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 30 of 48 Event

Description:

1 A SG Faulted inside ctmt, 1 B CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments BOP (step 4) Verify containment fan cooler alignment.

Verify all available containment fan coolers -

STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED

[1 1A NOTE: 1 B CTMT cooler fan

[] lB-TRIPPED tripped and 1 D did not start

[] 1C Critical task fl iDDID NOT START Start the 1 C or 1 D CTMT Verify associated emergency service water cooler or the 1A CTMT cooler outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[1 Q1P16MOV3O24A Will have to align emergency

[J Q1P16MOV3O24B SW to the A Train coolers to

{] Q1P16MOV3O24C be operable

{] Q1P16MOV3O24D BOP (step 5) Verify MSIV and bypass valves Critical task CLOSE MSIVs.

BOP (step 6) Check if feed flow should be isolated to any SG.

Check any SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

Verify all faulted SG main feed stop valves -

CLOSED.

SRO Evaluation IF all SGs faulted THEN

- Only the 1A SG is faulited maintain 20 gpm AFW flow to each SG.

BOP (step 6.4) Isolate AFW flow to all faulted Critical task SGs. Close 3764A or E 1A -

Close MDAFWP isolation valves to all faulted MDAFWP to 1A SG ISO SGs. (BOP) valves 30

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 31 of 48 Event

Description:

1 A SG Faulted inside ctmt, 1 B Cs pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments BOP Close TDAFWP flow control valves to all Take HV-3228A pot to 0 faulted SGs.

TDAFWP FCV 3228

[] RESET reset SRO Call to SSS-P or TSC to have Qi N23V017A closed in the MSVR End of FRP-Z.1 Beam EEP- 2.0. version 1 here BOP (step 1) Verify all MSIV and bypass valves Critical task

- CLOSED. CLOSE MSIVs.

Place handswitches for all MSIVs to the CLOSED position (6 total)

BOP (step 2) Check if any SG not faulted. Only 1A SG will be blowing Check pressure in at least one SG STABLE

- down once the MSIVs are OR RISING. closed (step 3) Identify the faulted SG 1A SG BOP (step 4) Isolate all faulted SGs.

- Verify 1 A ARV closed - PC3371 A minimum demand

- Verify 1A SG Feed stop valves closed M0V3232A

- Verify blowdown from all faulted SGs

- ISOLATED. HV 7614A Since the fault is on the 1A SG, the crew will proceed to step 4.6 31

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 32 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions!Behavior Comments BOP (step 4.6) Verify SG blowdown sample ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE ISO

[] MLB1 1 9-2 lit Qi P1 5HV3328 closed

{] MLB1 1 9-3 lit 01 P1 5HV3329 closed

[] MLB1 1 9-4 lit 01 P1 5HV3330 closed BOP (step 5) Isolate AFW flow to all faulted SGs. Critical task Close MDAFWP isolation valves to all faulted Closes M0V3764A and E on SGs. (BOP) the BOP Close TDAFWP flow control valves to all Critical task faulted SGs. Close HV3228A pot to 0 or call TDAFWP FCV 3228 to close VO17A below.

[1 RESET reset SRO Call to 555-P or TSC to have Q1 N23V017A key Z-139 closed in the MSVR BOP (step 6) Check CST level greater than 5.3 feet [1 R-15

[] 19 (step 7) Check secondary radiation [] 23A and B indication NORMAL.

[] 15B and C,

[1 60 A, B, C, D SRO (step 8) Evaluate SI termination criteria

- Check SCMM indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

- Check secondary heat sink available.

>395 gpm AFW flow OR

> 31%{48%} SGNR level

- Check RCS pressure STABLE OR RISING

- Check pressurizer level>

1 3%{43%}.

32

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 33 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments SRO Enter EEP-1 or ESP-1.1 depending on SI If EEP-1 is entered then SI termination criteria reinitiation criteria should be checked per the EQ page When the decision to transfer to EEP-1 .0 or ESP-1 .1 announced, then terminate the exam.

If EEP-1 is entered and the exam is allowed to continue then these actions will be performed.

EEP-1. LOSS OF REACTOR OR SECONDARY COOLANT.

Foldout page requirement below SI reinitiation criteria RNO- Establish HHSI flow, Greater than 1 6°F{45°F} subcooled in CETC and start additional CHG mode and PRZR level above 13%{43%}. PUMPs as required using ATTACHMENT 6, RE ESTABLISHING HHSI FLOW.

Attachment 6 actions (not required due to being a steam break) 33

Op Test No: FA2011301 Scenario # 2 Event # 8 and 9 Page 34 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments RD (step 1) Align charging pump suction to RWST.

RWST TO CHG PUMP

[] Q1E21LCV1 15B open

[] Q1E21LCV1 15D open CHG PUMP SUCTION HDR ISO

[1 Qi E21 MOV81 30A open

[1 Q1E21MOV813OB open

[1 01 E21 MOV81 31 A open

[] Q1 E21 MOV81 31 B open VCT OUTLET ISO

[1 Qi E21 LCV1 1 5C closed

[1 Q1E21LCV1 15E closed (step 2) Verify charging pump miniflow valves OPEN.

1A(1B,1C) CHG PUMP MINIFLOW ISO

[1 Q1E21MOV81O9A

[] Q1E21MOV81O9B

[] Q1E21MOV81O9C CHG PUMP MINIFLOW ISO

[1 Q1E21MOV81O6 34

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 35 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments RO (step 3) Isolate normal letdown and charging.

LTDN ORIF ISO 45 GPM

[1 Qi E21 HV81 49A closed

[1 Q1E21HV8149B closed

[1 Q1E21HV8149C closed LTDN LINE CTMT ISO

[1 Q1E21HV8152 closed Manually close chg flow control valve.

FK 122 Verify charging flow path aligned.

CHG PUMP DISCH HDR ISO

[1 Qi E21 MO V81 32A open

[1 Qi E21 MOV81 32B open

[1 Qi E21 MOV81 33A open

[1 Q1 E21 MOV81 33B open CHG PUMPS TO REGENERATIVE HX

[1 Q1E21MOV81O7 closed

[] Q1E21MOV81O8 closed RO (step 4) Open HHSI isolation valves.

HHSI TO RCS CL ISO

[] Qi E21 MOV88O3A

[] 01 E21 M0V8803B RO (step 5) Start additional CHG PUMPs as required.

(step 6) Monitor charging pump miniflow criteria.

Control charging pump miniflow valves based on RCS pressure.

1C(1A) LOOP RCS WR PRESS

{] Pt 402A

[1 P1 403A 35

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 36 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected ActionslBehavior Comments Step 1 of EEP-1 .0 below RO (step 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

BOP (step 2) Check SGs not faulted.

Check no SG pressure FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

BOP (step 3) Check intact SG levels.

Check any intact SG narrow range level GREATER THAN 31%{48%}.

NOTE: [CA] step WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31 %-65%{48%-65%}.

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWPTO 1AI1B!1CSG BTRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted BOP (step 4) Check secondary radiation [] R-1 5 indication - NORMAL. [] 19 Checks rad monitors [] 23A and B

[] 15B and C,

[1 60 A, B, C, D 36

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 37 of 48 Event

Description:

1A SG Faulted inside ctmt, 18 CS pump will not auto start and MOV 8820A will not open Time Pos. Expected Actions/Behavior Comments RO (step 5) Check pressurizer PORVs Check any PRZR PORV ISO power available NOTE: [CA] step WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

[] Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.

[] PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.

[] PRT PRESS P1 472

[1 PRT LVL Ll-470

[] PRT TEMP Tl-471

[] Check at least one PRZR PORV ISO -

OPEN SRO (step 6) Perform the following within 1 NOTE: These steps will be hour of start of event, passed off to the Shift

[] Close recirculation valve disconnects using Manager ATTACHMENT 1.

[] Establish 1 A and 1 B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

[] Plot hydrogen concentration on FIGURE 1.

Check containment hydrogen concentration

[] LESS THAN 3.5%.

[] Less than 0.5%

37

Op Test No.: FA2011301 Scenario # 2 Event # 8 and 9 Page 38 of 48 Event

Description:

1A SG Faulted inside ctmt, lB CS pump will not auto start and MOV 8820A will not open Time Pos. Expected ActionslBehavior Comments SRO (step 7) F,1iif I termination criteria

[] Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

Check secondary heat sink available.

[] >395 gpm AFW flow OR

[] > 31%{48%} SGNR level

[] Check RCS pressure STABLE OR RISING

[J Check pressurizer level GREATER THAN 1 3%{43%}.

When the decision to transfer to step 1 of EEP-l .0 or ESP-1 .1 announced, then terminate the exam.

38

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 39 of 48 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-O Attachment 2 of EEP-O AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each CRITICAL TASK: Start 1 C or train STARTED.

- 1 B Chg pump BOP []Atrain(lAorlB)amps>O

[1 B train (1C or 1B) amps> 0 BOP (Step 2) Verify RHR PUMPs - STARTED.

RHR PUMP

[1 1A amps > 0

[1 lB amps> 0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow - GREATER THAN 0 gpm.

[] Fl 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow greater than 1.5 Xl o gpm

[] 1A RHR HDR FLOW Fl-605A

[J 1 B RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[jAtrain (1A,lBor 1C)

[J B train (1D,lEor 1C) 39

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 40 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (Step 5) Verify each train of CCW -

STARTED.

(Step 2.1) Verify one CCW PUMP in each train- STARTED.

A train HX 1 C or 1 B CCW FLOW

[] Fl 3043CA > 0 gpm OR

[j Fl 3043BA > 0 gpm B train HX lAor lB CCW FLOW

[] Fl 3043AA > 0 gpm OR

[1 Fl 3043BA> 0 gpm Verify SW flow to associated CCW HXs SW FROM 1A(1B, 1C) CCW HX

[1 01 P1 6F3OO9AA> 0 gpm

[1 Q1P16FI3009BA> 0 gpm

[1 01 P1 6F13009CA> 0 gpm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[]1A

[]1 B

[]1C Check INST AIR PRESS P1 4004B greater than 85 psig.

40

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 41 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOS ED.

[13197

[1 3198D

[1 3198C

[] 3196

[1 3198A

[]3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[1 2866C

[1 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-31 96 & 3197 BOTH-3198B & 3198C

[] 2866D

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 41

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 42 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

CTMT CLR FAN SLOW SPEED A train NOTE: 1 B CTMT cooler

[J 1A tripped and 1 D did not start

[] lB trips Critical task B train Start the 1C or 1 DoriA

[] 1C CTMT cooler in slow speed

[1 1 D does not auto start Verify associated emergency service water outlet valves OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[J 01 P1 6M0V3024A

[j 01 P1 6M0V3024B

[] Qi P1 6M0V3024C

[1 01 P1 6MOV3024D BOP (step 8) Verify AFW Pumps STARTED.

Verify both MDAFW Pumps STARTED-

[J 1A MDAFW Pump amps> 0

[J lB MDAFW Pump amps>0 AND

[] Fl-3229A indicates > 0 gpm

[j Fl-3229B indicates > 0 gpm

[j Fl-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

Condition EITSLB Setoint ElCoincidence RCP Bus TSLB2 1-1 E12680 V 1/2 Detectors Undervoltacie 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1 ,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1 6-2,6-3 42

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 43 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 8.3) Verify TDAFWP started.

[] MLB-4 1-3 lit

[1 MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[JSI 3411A> 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWPTO 1A(1B,1C) SG

[] Q1N23HV3228A in MOD

[1 Q1N23HV3228B in MOD

[] Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C)SG FLOW CONT

[1 HIC 3228AA open

[] HIC 3228BA open

[j HIC 3228CA open 43

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 44 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

1A(1B,1C) SG FW FLOW

[] FCV 478

[] FCV 488

[1 FCV 498 Verify both SGFPs TRIPPED.

Verify SG blowdown ISOLATED.

1A(1B,1C) SGBD ISO

[1 Q1G24HV7614A closed

[1 Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1 BiG) SGBD SAMPLE STEAM GEN ISO

[] MLB1 19-2 lit Q1P15HV3328 closed

[] MLB1 19-3 lit Q1P15HV3329 closed

[] MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

SirinI Setooint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 1/2 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.

(Step 11 .1) Verify PHASE A CTMT ISO -

ACTUATED.

BOP [1 MLB-2 1-1 lit

[j MLB-2 11-1 lit 1 1 .2 Check all MLB-2 lights - LIT.

44

F-Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 45 of 48 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected Actions/Behavior Comments BOP (step 12) Check all reactor trip and reactor trip bypass breakers OPEN Reactor trip breaker A Reactor trip breaker B Reactor trip bypass breaker A Reactor trip bypass breaker B BOP (step 13) Trip CRDM MG set supply breakers.

1A(1B) MG SET SUPP BKR

[] N1C11EOO5A

[] N1C11EOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[J 1A

[] 1 B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate Will call TBSO to pumps per FNP-O-SOP-O.O, APPENDIX B, accomplish this.

TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.

45

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 46 of 48 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[J A TRAIN

[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[]810- OPEN

[] 914 OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.

End of Attachment 2 46

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 47 of 48 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected Actions/Behavior I Comments Attachment 4 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DFO1 closed

[j Verify DFO2 closed

[] Check DG15 closed

[] Verfiy DGO2 closed

[1 Verify two trains of battery chargers energized Amps > 0 (Step 1 .6) Verify two trains of ESF equipment aligned.

[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

CHG PUMP DISCH HDR ISO

[1 Q1E21MOV8132A

[1 Qi E21 MOV81 32B

[1 Qi E21 MOV81 33A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[1 Q1E21MOV813OA

[] Q1E21MOV813OB

[] Q1E21MOV8131A

[1 01 E21 MO V81 316 47

Op Test No.: FA2011301 Scenario # 2 Event # 6 Page 48 of 48 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected Actions/Behavior Comments (Step 1.7) Verify all post accident containment air mixing system fans STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] lB

[1 1C

{J 1 D RX CAV H2 DILUTION FAN

[1 1A

[] 1 B (Step 1 .8) WHEN power restored to any de energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1 .9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 48

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2O1I-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.

If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.

In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.

Assign operating positions.

Ask for and answer Questions.

Appendix D Turnover sheet Form ES-D-2 I X 1 Unit 1 1 1 Unit 2 Shift: Date I Off-going SS - I Oncoming SS I [ ] N [ X] D I Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, 5, D, SW, X on key ring. SS Unit 65% power RTP, MOL, 838 ppm Cb, 10,000 MWD, Eq Xe, (-2939)

Status Unit was ramping up lAW UOP-3.1, v.109, when AOP-21 was entered due to winds in excess of 75 mph expected at the plant site in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months . The Shift Manager has directed Unit 1 to shutdown to Mode 3 at 5 MW/mm. Step S

810 of UOP-3.1 has been completed. Pimp loop is in.

All steps of AOP-21 have been completed or are in progress.

STPs/Evolutions: B Train On-Service B Train Protected 1.0_; 109.1 Noadi.; 63.7; FSP-20,0 Status of Special Testing General Information

1. Ramp down in power at 5 MW/mm to be off line 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months from now.

2. 1 B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

3. PT-457 failed low last shift- l&C is working on it.

4. Current Risk Assessment is and projected is

5. AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.

6. All notifications for the ramp have been made by the Shift Manager 7.

8.

9.

Equipment Status PT-457 is failed low 18 EHC pump is tagged out Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status NA #3 RHT On Service WGS secured; LCO Status PT-457, LCO 3.3.1 cond M and E, 3.3.2 cond D and K (admin)

Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

[X]Yes [X]Yes [X]Yes [XJYes [X]Yes [X]Yes

1. Appendix D Scenario Outline Form ES-D-1 hngrp DRAF Facility: Farley Nuclear Plant Scenario No.: 1 Op-Test No.: FA2O11-301 Examiners: Operators: SRO RO BOP Initial Conditions: Mode 2, 1 08 amps, EOL, 549 ppm boron.

Turnover:

. 1 08 amps, raising power to the POAH.

. Reactor Startup in progress.

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.

SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

R (RO) Raise reactor power and enter the POAH. Stabilize at 1-2%

1 power lAW UOP-1 .2, Startup of Unit from Hot Standby to R (BOP) Minimum Load, step 5.24 viOl 1 I (RO) LT-459 fails high. AOP-100 entry to restore Pzr level.

2 TS (SRO) LCO 3.3.1 Cond M admin LCO <10%, mandatory for >10%

and 33.3 admin LCO.

2 I (BOP) Rad monitor R35A, control room radiation monitor, fails high. 3 3 Control room dampers fail to automatically close. Manual TS (SRO) isolation of dampers is required. TS 3.3.7 3 C (BOP) PK-3371A tails high. AOP-14 entry.

5 4 C (RO) 1A RCP trips, AOP-4.0 entry required.

6 M (ALL) The SBLOCA (300 gpm over 60 seconds) increases. AOP-1 .0 entry.

6 C (BOP) Automatic SI fails to actuate, manual actuation required (CT) 7 C (BOP) 1 A & 1 B CTMT coolers fail to auto start, manual start of at least one required 1A RHR pump fails to automatically start and can be manually 8 C (BOP or started. (CT)

RO) 1 B RHR pump trips at 38 feet in RWST 9 M(ALL) A LBLOCA occurs 15 minutes after SBLOCA.

7 Secure RCPs (CT)

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 d DRAFT SUBM1TTA A Terminate when transition to ES P-i .3.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor H

Changes in BLUE Changed the order of steps 3 AND 4 Farley May 2011 exam Page 2 of 6

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 1 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SRO RO BOP Initial Conditions: Mode 2, 108 amps, EOL, 549 ppm boron.

Turnover:

1O amps, raising power to the POAH.

. Reactor Startup in progress.

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.

SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

R (RO) Raise reactor power and enter the POAH. Stabilize at 1-2%

1 power lAW UOP-1 .2, Startup of Unit from Hot Standby to R (BOP) Minimum Load, step 5.24 viOl 1 I (RO) LT-459 fails high. AOP-100 entry to restore Pzr level.

2 TS (SRO) LCO 3.3.1 Cond M admin LCO <10%, mandatory for >10%

and 3.3.3 admin LCO.

2 I (BOP) Rad monitor R35A, control room radiation monitor, fails high. 3 3 Control room dampers fail to automatically close. Manual TS (SRO) isolation of dampers is required. TS 3.3.7 4 3 C (BOP) PK-3371A fails high. AOP-14 entry.

4 C (RO) 1A RCP trips, AOP-4.0 entry required.

6 M (ALL) The SBLOCA (300 gpm over 60 seconds) increases. AOP-1 .0 entry.

6 C (BOP) Automatic SI fails to actuate, manual actuation required (CT) 7 C (BOP) 1 A & 1 B CTMT coolers fail to auto start, manual start of at least one required 1A RHR pump fails to automatically start and can be manually 8 C (BOP or started. (CT)

RO) 1 B RHR pump trips at 38 feet in RWST 9 M(ALL) A LBLOCA occurs 15 minutes after SBLOCA.

7 Secure RCPs (CT)

Farley May 2011 exam Page 1 of 6

Appendix D Scenario Outline Form ES-D-1 Terminate when transition to ES P-i .3.

(N)ormal, (R)eactivity, (I)nstru ment, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 6

Appendix D Scenario Pre-sets Form ES-D-1 3 0 3622, 3624 and 3626 will not close on hi rad

Cmf mal / chvh3622_d_cc3 closed Cmf mal / chvh3624_d_cc3 closed Cmf_mal_I_chvh3626_d_cc3_closed 6 0 auto SI train A fails

CMFmalf / csftyinj_cci_I open 6 0 auto SI train B fails

CMFmalf I csftyinj_ccl 1 / open 6 0 1A RHR pump tails to auto start on SI. Manual start allowed.

CMFmalf! crhpOia_d_cc9 I open 6 0 1 A & 1 B ctmt crls do not auto start on LOSP or ESF sequencer

CMFmalf / cchflal_d_cc3 / open CMFmalf! cchf 1 bl_d_cc3 / open CMFmalf! cchf 1 al_d_cc4! open CMFmalf! cchf 1 bl_d_cc4! open 6 0 1 B RHR pump trips on overload after auto start. Trigger 1 CMFmalf/ crhpolb_d_col /0/Trigger 1 7 0 LBLOCA occurs 15 minutes after SBLOCA Trigger 2 MaIf! mal-rcs2a / 15 minute ramp / Trigger 2 0 0 Isolate MSDPs, preset to help prevent RCS cooldown

Remote I Nil! loa-mssO57/ 0 Remote / Ni 1! loa-mss058 / 0 Remote! Nil! loa-mssO59 I 0 Remote / Nl 1/ loa-mssO6O /0 Triggers and Commands 7 0 Trigger 1 RWST LI 4075a

- < 38, event 7

Event: bsis4075 < 38 6 0 Trigger 2 SBLOCA Event: jmrcsla Farley May 2011 exam Page 3 of 6

Scenario 1 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: Mode 2, 108 amps, EOL, 549 ppm boron.

Turnover:

1 08 amps, raising power to the POAH.

Reactor Startup in progress.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Raise reactor power and enter the POAH. Stabilize at 1-2% power lAW UOP-1 .2, Startup of Unit from Hot Standby to Minimum Load, step 5.24 Verifiable actions: RO will pull rods, establish a 3/4 dpm SUR, enter power range and stabilize at 1-2% power. BOP will adjust steam dumps as necessary to increase power when in power range.

Event 2 LT-459 fails high. AOP-100 entry to restore Pzr level. LCO 3.3.1 Cond M admin LCO for mode 2 and 3.3.3 admin LCO. Post exam the TS question will be asked if the unit can ramp up to >10% power and the actions required, if any. (in mode 2 the TS is an admin but at 10% power it is a mandatory and the decision to enter 10% power and actions required would be examined.)

Verifiable actions: Take manual control of FCV-122 and control Pzr level, swap channels.

Event 3 Rad monitor R35A, control room radiation monitor, fails high. 3 Control room dampers fail to automatically close on BOP. LD4 BOP annunciator. LCO 3.3.7 mandatory LCO.

Verifiable actions: Manual isolation of dampers is to ensure CR is isolated properly.

Event 4 PK-3371A fails high with indication of demand on MCB. AOP-14 will be entered to find and close the extra steam flow at low power levels. Rx power will start to increase due to more steam flow, Stm dumps will start to close and RCS temperature will decrease.

Verifiable actions: Close PCV-3371A. (Pzr level may drop <15% requiring letdown to be placed on service after problem fixed).

Event 5 1A RCP trips. The crew will enter AOP-4.0 for the loss of flow in the A loop.

Verifiable actions: Close the 1A loop spray valve will be required (RO) & secure feeding the 1A SG by closing 1A loop AFW FCV (BOP) Control RCS pressure and SG water level with in the band is required. The decision to drive rods in and open RT breakers w/i 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is required.

Event 6 A SBLOCA (300 gpm over 60 seconds) occurs.

Automatic SI fails to actuate. Manually actuate at least one train of SI. (CT) 1A RHR pump fails to automatically start; can be manually started. (CT)

When RWST level reaches 38 feet, 1 B RHR pump trips on overcurrent.

1A and lB CTMT CRLS do not auto start.

Event 7 A LBLOCA occurs 15 minutes after SBLOCA.

Secure the RCPs before EEP-1 .0 step 2. (CT)

Farley May 2011 exam Page 4 of 6

Scenario 1 detailed summary Appendix D Form ES-D-1 sheet Terminate when transition to ESP-1 .3.

UOP-1 .2/ AOP-1 00/ LD4 BOP/ AOP-1 4/ AOP-4.0/ AOP-1 .0/ EEP-0/ EEP-1 .0 Farley May 2011 exam Page 5 of 6

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-0 - - D)

Transition to any E-1 series procedure or

Transition to any FRP

Completion of step 9 in ESP-0.1

Manually Actuate SI

2. Manually start at least one low head ECCS pump before transition out of E-0.

(WOG CT E-0 - - H)

The 1 A LHSI does not start and the 1 B LHSI pump trips at 38 feet in RWST.

3. Trip all RCPs so that CETC temperatures do not become superheated when forced circulation in the RCS stops (WOG CT E-1 - - C)

Secure the RCPs when the LB LOCA occurs SCENARIO Mode 2 with component and instrumentation failures, LBLOCA, failure of CS OBJECTIVE/ systems, ECP-1.1 entry required.

OVERVIEW: The team should be able to:

recognize and respond to failures of various instruments and components per ARPs AOP-4.0, AOP-100, & Tech Specs

identify a SBLOCA, LBLOCA, initiate a manual SI, recognize that the required Containment Cooling System components are not operating and start Ctmt coolers as required per EEP-0 and EEP-1 .0 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 9

2. Malfunctions after EOP entry (12) 4

3. Abnormal events (24) 3

4. Major transients (12) 2

5. EOPs entered/requiring substantive actions (12) 1

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 3 Farley May 2011 exam Page 6 of 6

Appendix D Scenario Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 7 Op-Test No.: FA2O1 1 -301 Examiners: Operators: SRO RO BOP Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

CB D at 175 steps. (Xe is -1795 pcm and building in)

Turnover:

. 2C DG TIC for governor work. (OOS 2 days, ETR 4 hrs)

. 1 B EHC pump T/C for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

. Fuel handling is on going in the SFP room with the last fuel bundle being moved.

. Current Risk Assessment is RLEN and projected is

. A Train On-Service A Train Protected.

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.

1 I (RO) PT-444 fails high 1

TS (SRO) TS 3.4.1 DNB (low pressure) 2 I (BOP) R-25A FAILS HIGH and SFP ventilation does not secure, PRF 2 starts TS (SRO) TS 3.3.8 3 3 I (RO) LK-459F fails LOW 4 R (RO & 1A RCP #1 seal fails to 7 over 90 seconds 4

BOP) 5 C (BOP) Loss of the 1G emergency bus (DG-15 trips open) 5 TS (SRO) TS 3.8i M (RO & 1A RCP #1 seal fails to 10 over 120 seconds 6

BOP) 6 C (RO) Reactor will not trip, CRDM MG set breakers will open (CT) 7 C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 8 M(ALL) TDAFW pump will trip 1 minute after it starts.

The 1A MDAFW pump begins to experience degraded head.

8 10 1 B MDAFWP will not start when required and cannot be started from the MCB or HSD panel.

Farley May 2011 exam Page 1 of 5

Appendix D Scenario Outline Form ES-D-1 Terminate event when SGFP flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

I (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 2 of 5

Appendix D Scenario Pre-sets Form ES-D-1 0 0 Tag out lB EH pump

CMFmaIf I cmshfpb_cp2 0 0 2C DG output breakers racked out

cBKl DJO6_d_cpl cBK2DJO6_d_cpl CMFmaIf I cBK1 DJO6_d_cpl CMFmaIf I cBK2DJO6_d_cpl 0 0 Main turbine fails to auto trip:

MALF / T I MAL-TUR2 Prevent manual trip of main turb.

imf mal-tur24 0 0 Fail RTB from opening in auto

imf cbkrxtrp_cc6 open imf cbkrxtrp_cc5 open 0 0 1 B DG fails to auto start

set jdgblkl b = true 8 0 lb mdafw breaker will not close

imf cafpolb_d_cr5 8 0 Trip TDAFW pump 1 minute after start Trigger 1 VLVS / mal-fwm 1 c / 1 mm delay / Trigger 1 8 0 1A MDAFW develops degraded head when SI occurs Trigger 2 imf NAFPO1A-D_th (2 0) 100 60 7 0 1 A MSIVs will not close on auto closure

imf crsh00l a_cc5 open imf cmsh002a_d_cc5 open 1 B MSIVs will not close on auto closure imf crsh00l b_cc5 open imf cmsh002b_d_cc5 open 10 MSIVs will not close on auto closure mt crsh00lc_cc5 open imf cmsh0o2c_d_cc5 open Triggers and Commands 8 0 Event Trigger 1 monitors start of TDAFW:

Trgset 1 jtdafwp 8 0 Event Trigger 2 Auto Start (AMPS > 70):

Trgset 2 yAFPO1 B > 70 Farley May 2011 exam Page 3 of 5

Appendix D Scenario detailed summary sheet Form ES-D-1 Initial Conditions: 72% power, continuing a ramp to 100% power, 909 ppm, MOL.

Turnover:

2C DG TIO for governor work. (OOS 2 days, ETR 4 hrs)

1 B EHC pump TIC for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Fuel handling is on going in the SEP room with the last fuel bundle being moved.

Current Risk Assessment is and projected is

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 PT-444 fails high.

Verifiable actions: AOP-1 00, take manual control of PORV (close), close spray valves and manually control pressure. DNB TS 3.4.1 Event 2 R-25A FAILS HIGH - SFP ventilation does not secure, PRF starts. TS 3.3.8 Verifiable actions: Manual isolation of dampers is to ensure SEP area is isolated properly.

Event 3 LK-459F fails LOW Verifiable actions: RO will take manual control of charging and adjust seal injection flows.

Due to the failure letdown could be secured and then placed back on service.

Event 4 1A RCP #1 seal fails to 7 over 90 seconds Verifiable actions: Ramp unit off line using rod control and boron Event 5 Loss of the 1 G emergency bus (DG-1 5 trips is opened due to tagging order error) and 1 B DG does not auto start. TS 3.8.1 on DG (There will have to be cues to show there are no electrical faults on the 1 B SU Xfmr and no visual problems with the 1 B DG)

Verifiable actions: RO will start 1A CHG Pump; BOP will close M0V517 and start the lB DG per attachment 6.

Event 6 1A RCP #1 seal fails to 10 over 120 seconds Verifiable actions: RO will trip the reactor; BOP will secure 1A RCP and shut HV8141A.

Event 7 Reactor will not trip, CRDM MG set breakers will open (CT)

Main Turbine will not trip automatically or manually, Manual Fast action will be used to close GVs (CT)

Event 8 TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW pump begins to experience degraded head.

lB MDAFWP will not be available (cannot be started in auto or manually).

Establish SGFP flow to the SGs. (CT)

Terminate event when SGFP flow to SGs accomplished and FRP-H.1 transition criteria reached.

AOP-100/ARP/AOP-5.0/AOP-4.l/ EEP-0/ FRP-H.1 Farley May 2011 exam Page 4 of 5

Appendix D Scenario Critical Task Sheet Form ES-D-1 CRITICAL TASK SHEET

1. Manual Rx trip vs CRDM trip Manipulation of CRDM MG Set Breaker hand switches when conditions require a Reactor trip. Negative reactivity must be inserted within 6 minutes of the start of the event with MEW in service and > 40% power. (PRA NR:27) (WOG CT E A)

Both CRDM MG Set Supply breakers open.

2. Failure of the turbine to trip. The team should: (WOG CT E 0) -

Close main turbine GVs prior to SGs boiling dry.

3. Heat sink or feed and bleed Establish feedwater flow into at least one SG before feed and bleed is required (2 SG is < 12% WR level). (PRA NR:4) (WOG CT FR-H.1

- - - A)

Verify flow to A, B, or C S/G using A or B SGFP.

SCENARIO The team should be able to:

OBJECTIVEI

Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-100, AOP-5.0, AOP-4.1 and AOP-13 and Tech Specs

Respond to a RCP seal failure and then a Loss of Feed event when the reactor trips.

The crew will have to establish feed water flow to the SGs with the SGFPs pumps and transition to the appropriate procedure.

Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after SOP entry (12) 5

3. Abnormal events (24) 5

4. Major transients (12) 2

5. SOPs enteredlrequiring substantive actions (12) 0

6. SOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley May 2011 exam Page 5 of 5

Scenario #1 FA2O1 1301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE HLT-34 NRC EXAM SCENARIO #1 Validation time: 90 minutes Validated by Justin Wheat, Jamie Coleman and Denny Williams The week of January 3, 2011 TRN Supervisor Approval: Gary Ohmstede Date: 2/7/201 1 NRC Chief Examiner Ron Aiello Date:

SOUTHERN A COMPANY

Appendix D Scenario #1 Outline Form ES-D-1 Facility:

Examiners:

FarleyNuclearPlant I ScenarioNo.: 1 Operators:

Op-TestNo.: 2011-301 SRO RO BOP Initial Conditions: Mode 2, 108 amps, EOL, 549 ppm boron.

Turnover:

. 10-8 amps, raising power to the POAH.

. Reactor Startup in progress.

. Current Risk Assessment is and projected is

. B Train On-Service B Train Protected

. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.

SPLIT TRAIN ALIGNMENT Event Maif. Event Type* Event Description No. No.

R (RO) Raise reactor power and enter the POAH. Stabilize at 1-2%

1 power lAW UOP-1 .2, Startup of Unit from Hot Standby to R (BOP) Minimum Load, step 5.24 viOl 1 I (RO) LT-459 fails high. AOP-1 00 entry to restore Pzr level.

2 TS (SRO) LCO 3.3.1 Cond M admin LCO <10%, mandatory for >10%

and 3.3.3 admin LCO.

2 I (BOP) Rad monitor R35A, control room radiation monitor, fails high. 3 3 Control room dampers fail to automatically close. Manual TS (SRO) isolation of dampers is required. TS 3.3.7 4 3 C (BOP) PK-3371A fails high. AOP-14 entry.

4 C (RO) 1A RCP trips, AOP-4.0 entry required.

6 M (ALL) The SBLOCA (300 gpm over 60 seconds) increases. AOP-1 .0 entry.

6 C (BOP) Automatic SI fails to actuate, manual actuation required (CT) 7 C (BOP) 1 A & 1 B CTMT coolers fail to auto start, manual start of at least one required 1 A RHR pump fails to automatically start and can be manually 8 C(BOPor started. (CT)

RO) 1 B RHR pump trips at 38 feet in RWST 9 M(ALL) A LBLOCA occurs 15 minutes after SBLOCA.

7 Secure RCPs (CT)

FarleyMay 2011 exam Page2ofl3

Appendix D Scenario #1 Outline Form ES-D-1 Terminate when transition to ESP-1 .3.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley May 2011 exam Page 3 of 13

Appendix D Scenario 1 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 IC-21 1, EOL, 549 ppm boron.

UOP-1.2ver. 101 at step 5.24 D © 148, B Tm 0/S Xe free S/U, Hotwell flush at 0.08 Base IC- IC-018 RUN RUN simulator 0 0 Generic setup:

bat generic_setup_H LT.txt 0 0 Quick setup (all items with are included):

bat 201 1 nrcexam_01 .txt PRESETS 3 U 3622, 3624 and 3626 will not close on Mi rad Cmf mal / chvh3622_d_cc3 closed Cmf mal / chvh3624_d_cc3 closed Cmf mal / chvh3626_d_cc3 closed 6 0 auto SI train A fails CMFmalf / csftyinj_ccl / open 6 0 auto SI train B tails CMFmaIf / csftyinj_ccl 1 / open 6 0 1A RHR pump fails to auto start on SI. Manual start allowed.

CMFmalf I crhpOl a_d_cc9 / open 6 0 1A & 1 B ctmt crls do not auto start on LOSP or ESF sequencer

CMFmaIf I cchflaLd_cc3 /open CMFmaIf I cchf 1 bl_d_cc3 I open CMFmaIf / cchf 1 aI_d_cc4 / open CMFmaIf I cchf 1 bl_d_cc4 / open 6 0 1 B RHR pump trips on overload after auto start. Trigger 1 CMFmaIf I crhpol b_d_col I 0 I Trigger 1 7 0 LBLOCA occurs 15 minutes after SBLOCA Trigger 2 Malt! mal-rcs2a I 15 minute ramp / Trigger 2 0 0 Isolate MSDPs, preset to help prevent RCS cooldown

Remote! Ni 1! Ioa-mssO57! 0 Remote! Nil! Ioa-mssO58 /0 Remote! Ni 1! loa-mssO59 / 0 Remote / Nil! Ioa-mssO6O /0 Triggers_and_Commands 7 0 Trigger 1 RWST LI 4075a

- < 38, event 7 Event: bsis4O75 < 38 6 0 Trigger 2 SBLOCA Event: jmrcsla Farley May 2011 exam Page 3 of 12

Appendix D Scenario 1 Simulator setup Form ES-D-1 MCB setup Scaler timer should be secured DEH Clear DEH alarms Select CRITICAL STARTUP on MCB monitor IPC CRITICAL STARTUP Acknowledge computer alarms Delete R-35A on plant computer. Use IPC operation from Delete R-35A SIM BOOTH Workstation.doc to delete the point from the plant computer.

IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Recorders Verify memory disks cleared Provide a marked up copy of UOP-1 .2. v 101 UOP-1 .2 copy The following steps should be signed off or NA as appropriate:

Initial conditions: 2.1 through 2.25 Steps: 5.1 through 5.23, 5.25, 5.28, 5.29, 5.34 through 5.36 l

Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:

Simview I sv DataCollection.uvl It needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley May 2011 exam Page 4 of 12

Appendix D Scenario 1 Booth Guide Form ES-D-l EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam -

RUN simulator Verify Horns ON: hornf lag Verify Horns On HORNS ON = TRUE ann horn 1 0 Raise reactor power and enter the POAH. Stabilize at 1 -

2% power lAW UOP-1 .2, Startup of Unit from Hot Standby to Minimum Load, step 5.24 2 NRC LT-459 tails HIGH CUE imf 1t459 10040 3 NRC Pad monitor R35A, control room radiation monitor, fails Al CUE HIGH.

MALI R / imf mal-rmsip35A 4 NRC PK-3371A fails HIGH CUE imfpk337lA-A1035 5 NRC lARCPtrips CUE CMFmalf/imfcRCRCP1_co2 6 NRC SBLOCA (300 gpm over 60 seconds)

CUE imf mal-rcsla 300 60 7 15 mm LBLOCA occurs on Trigger 2. Trigger 2 after SB LOCA Buttons provided as backup.

Malt / P / imf MAL-RCS2A Cmf/ imf crhp01bd_co1 Farley May 2011 exam Page 5 of 12

Appendix D Scenario 1 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Trigger 1: RWST level reaches 38 feet, 1 B RHR pump will trip End NRC Terminate when transition to ES P-i .3.

CUE End of Exam I

Verify HORNS OFF ann horn E simulator Stop data collection for Simview file sv DataCollection.uvl Export data file with the to name of NRC examOl Ensure data file created.

grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

Restore R-35A on plant computer after all scenarios are run Use IPC oreration from SIM BOOTH Workstation.doc to restore the rlant comruter ioint to normal.

Farley May 2011 exam Page 6 of 12

Appendix D Scenario 1 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 WHEN REQUESTED SSS I RADSIDE:

I have performed steps 1 and 2 of attachment 1 of EEP-1 and need you to perform step 3 of attachment 1.

Button goes here CAE ECCS_disc_delayed.cae 6 WHEN REQUESTED Unit Two UO; RESET FIRE ALARM MH1 ANN /MH1 failoff Farley May 2011 exam Page 7 of 12

Appendix D Scenario 1 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

NONE 2 WHEN REQUESTED SM:

ACKNOLWEDGE LT459 failure and CR that will be written and in the queue.

3 WHEN REQUESTED ROVER:

- R35B is reading normal, but R35A is reading LOW END of scale and the Yellow alert light is lit, Red HIGH light is lit and the power on light is not lit.

- TSC HVAC is in recirc mode of operation

- BOTH control room doors are closed IF REQUESTED Unit 2 UO:

R-35A will not reset.

WHEN REQUESTED SM/DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

4 As Directed by NRC if ROVER or TB SO:

ARV not noticed open or There is a lot of steam coming from the roof of the MSVR when directed by AOP- Rover can report from inside the MSVR that the 1A MS line has a lot 14 of steam coming from the bay upstream of the MSIVs.

5 WHEN REQUESTED ROVER:

DA-04 is tripped open and has a trip flag on the breaker.

6 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SM/SSS:

I will get someone to perform step 6 of EEP-1 I will get an extra operator to secure the 1 B DG ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

FarleyMay2Oll exam Page8ofl2

Appendix D Scenario 1 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

6 WHEN REQUESTED RADSIDESO:

The 1 B RHR pump has a burnt insulation smell in the room, and the motor is hot to the touch.

ROVER:

WHEN REQUESTED The 1A RHR pump breaker, DG-09, is tripped on overcurrent.

Farley May 2011 exam Page 9 of 12

Scenario 1 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: Mode 2, 108 amps, EOL, 549 ppm boron.

Turnover:

108 amps, raising power to the POAH.

Reactor Startup in progress.

Current Risk Assessment is and projected is

B Train On-Service B Train Protected

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Raise reactor power and enter the POAH. Stabilize at 1-2% power lAW UOP-1 .2, Startup of Unit from Hot Standby to Minimum Load, step 5.24 Verifiable actions: RO will pull rods, establish a 3/4 dpm SUR, enter power range and stabilize at 1-2% power. BOP will adjust steam dumps as necessary to increase power when in power range.