ML14091A207

Initial Exam 2013-301 Final Simulator Scenarios

ML14091A207
Person / Time
Site:	Farley
Issue date:	04/01/2014
From:	Division of Reactor Safety II
To:	Southern Nuclear Operating Co
References
Download: ML14091A207 (249)

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Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, v103.1, completed thru step 5.62. Ready to perform step 5.63. MOL, 1350 ppm Cb; 1A SGFP on service. Aux steam from U-2.

Turnover:

1A SGFP is on service, MFR bypass valves are on service.

Current Risk Assessment is GREEN and projected to remain GREEN.

A Train O/S, A Train protected.

SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.

1 R (RO) Ramp up to 12% power.

2 imf I (RO) PK-145 fails high in automatic, letdown pressure controller failure pk145-a causes PCV-145 to close.

3 Imf I (BOP) 1A SGFP controller failure. SGFP speed will decrease to 3200 SK509B

-A rpm until control of SGFP is regained.

4 Imf C (RO) 1C charging pump sheared shaft.

Ncvp0 1c-b TS (SRO) T.S. 3.5.2 Condition A (mandatory until 1B charging pump swapped to opposite train) TRM 13.1.5 admin 5 N (BOP) Place letdown on service 6 Imf C (BOP) 1B SW pump trips on overcurrent.

cncps w1b_d

_co1 preset When the 1C SW pump is started, MOV-515 closes. AOP-7.0 will be entered to open MOV-515.

TS (SRO) T.S. 3.7.8 Condition A and 3.8.1 Condition B 7 Mal- M (ALL) 1A SGTR 300 gpm ramped in over 5 minutes.

rcs4A /

preset C (RO) Block auto SI. Initiate a SI manually (CT) 8 preset C (BOP) Block all AFW pumps from auto starting on SI signal C (RO) 1A ARV FAILS OPEN during EEP-0 (CT)

Terminate in EEP-3.0 when RCS cooldown (CT) is complete.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 1 of 4

Appendix D Scenario 2 Presets Form ES-D-1 PRESETS 9 Fail auto SI signals, Manual SI works

• CMFmalf / csftyinj_cc1 / open CMFmalf / csftyinj_cc11 / open 9 Prevent TDAFWP auto start

• CMFmalf / cMS3235B-cc1 / open CMFmalf / cms3235b_cc2 / open CMFmalf / cms3235a_cc1 / open CMFmalf / cms3235a_cc2 / open 9 Prevent MDAFWP auto start

• CMFmalf / Cafp01a_d_cr7 CMFmalf / Cafp01b_d_cr7 6 Indicate high flow condition in SW header TRG 2 imf af5 (2 5) failon 0 8 3371A ARV fails open 8 minutes after SI initiated TRG 1 imf pk3371A-A (1 480) 10 3 Triggers and Commands 8 CNH / 3371A-A Auto output failure high triggered on manual

• SI Trigger: jpplrtsi(1) > 0 3 Trigger 2: when 1c SW pump is started indicate high flow and

• mov-515 closure trgset 2 "nncpsw1c > 0" Trigger 3: Remove malfunction TRG 2 to allow reopening of MOV-515 trgset 3 "mncv515 == 0" trg 3 "dmf cncv515_cc7" Trigger 4: Close mov-515 on simulated high flow condition trgset 4 "xnmae06f" trg 4 " imf cncv515_cc7 closed" Trigger 5 turn off AF5 simulated flow spike trgset 5 "mncv515 < 0.98" trg 5 "imf af5 failoff" Farley June 2013 exam Page 2 of 4

Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 4% power, UOP-1.2, v103.1, completed thru step 5.62, Ready to perform step 5.63. MOL, 1350 ppm Cb; 1A SGFP on service. Aux steam from U-2.

Turnover:

1A SGFP is on service, MFR bypass valves are on service.

Current Risk Assessment is GREEN and projected to remain GREEN.

A Train O/S, A Train protected.

Event 1 Commence Ramp up to 12% power.

Verifiable actions: RO uses rods to increase RCS temperature, adjusts Steam Dumps to increase Stm flow and Rx power, and adjusts MFW flow to the SGs (Bypass FRVs on service).

Event 2 PK-145, letdown pressure controller, fails high.

Verifiable actions: Take manual control of PK-145 and restore pressure or remove letdown from service.

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

Verifiable actions: Manual control of SGFP and Bypass FRVs to control SGWL.

Event 4 1C Charging pump shaft will shear. This will cause a loss of charging flow with the pump running. Letdown will be secured and restoration of letdown will be required. TS 3.5.2 condition A and TRM 13.1.5 admin (mandatory while swapping the 1B Chg pump to B Train)

Verifiable actions: Secure letdown, secure the running Chg pump and start one Chg pump.

Event 5 Place letdown back on service per AOP-16.0.

Event 6 1B Service Water pump trips on over current. When 1C service water pump is started, MOV-515 goes closed. LCO 3.7.8 Condition A and 3.8.1 Condition B (LOSF with ECCS failure above)

Verifiable Actions: start the SW pump and open MOV-515.

Event 7 1A SGTR 300 gpm ramped in over 5 minutes.

The AUTO SI is blocked. Verifiable actions: Initiate a manual SI (CT)

Event 8 No AFW pumps start. Verifiable actions: Start one AFW pump to prevent the intact SGs from losing SGWL and for cooldown inventory.

1A ARV fails open after the SI occurs. Verifiable actions: Isolate SGs (ARV closed and MSIV closed; and AFW, when started) (CT)

Terminate in EEP-3.0 when RCS cooldown (CT) is complete at step 6.6.

UOP-1.2/ ARP/ AOP-100/AOP-16/AOP-10/AOP-7/E-0/E-3 Farley June 2013 exam Page 3 of 4

Scenario 2 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: (WOG CT E - D)

Transition to any E-3 series procedure

2. Isolate feed flow and steam from ruptured SG in EEP-3.0 before a transition to ECP-3.1 occurs. (WOG CT E - A)

Close or isolate 1A ARV Isolate AFW flow to the ruptured SG when >31%

At least one MSIV closed on 1A SG

3. Establish/maintain an RCS temperature so that transition from E-3 does not occour because the RCS temperature is in either of the following conditions.

(WOG CT E - B)

Too high to maintain [minimum required subcooling]

Below [the RCS temperature that causes an extreme (red-path) or a severe (orange-path) challenge to the subcriticality and/or the integrity CSF]

SCENARIO Low power instrument and component failures with a SGTR.

OBJECTIVE/ The team should be able to:

OVERVIEW: ramp the plant from 4% to 12 % power, respond to several instrument failures that affect the SW system, respond to a charging pump malfunction, respond to a SGFP controller failure and PK-145 malfunction, diagnose a SGTR, The crew will have to start AFW pumps when E-0 is entered, and discover and close a failed open ARV on the ruptured SG.

Termination of the event will be when the crew completes the RCS cooldown.

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

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 3

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 3 Farley June 2013 exam Page 4 of 4

Appendix D Scenario #3 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 29% power, 429 ppm, EOL; Ramping up, ramp on HOLD for chemistry.

Turnover:

Unit 2 PSS is OFF for Maintenance (OOS 2 hrs, ETR 2 hrs) 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs) 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Fuel handling is ongoing in the SFP.

Current Risk Assessment is YELLOW and projected is YELLOW, B Train On-Service - B Train Protected.

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

Imf I (RO) LT-115, VCT level controller, fails LOW 1 lt115 imf I (BOP) R-25A, SPENT FUEL POOL VENTILATION RAD MONITOR, mal-2 rms25a TS (SRO) fails HIGH and SFP ventilation does not secure, PRF starts

/ preset TS 3.3.8 condition A Imf I (RO) PT-444, PRZR PRESS CONTROL CHANNEL, fails high pt444/

preset TS (SRO) PORV-444B leaks by seat- requires block valve closure 3

T.S. 3.4.11 Condition A and TS 3.4.1 DNB Condition A (low pressure)

Imf C (BOP) 1A FRV Fails closed in Auto, will respond in manual control 4 fk478-a Imf R (RO) 1A SG tube leak - 15 gpm over 3 min and stabilizes. Ramp at 2 mal-5 rcs4a N(BOP) MW/min TS (SRO) TS 3.4.13 condition B Imf M (ALL) Running SGFP trips. RX trip required (Loss of Feed);

6 mal-fwm11a preset C (RO) Reactor Trip hand switches disabled, RX trip requires securing 7 Rod Drive MG set breakers.

C (BOP) Main Turbine will not trip in AUTO, manual trip required. (CT)

Imf M (ALL) 1A SGTR increases to 500 gpm when EEP-0 entered.

8 mal-rcs4a Imf M (ALL) 1A SG fault upstream of 1A MSIV in MSVR when 1A MSIV is mal-9 mss2a C (BOP) closed.

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 June 2013 exam Page 1 of 4

Appendix D Scenario 3 Presets Form ES-D-1 PRESETS 2 HV-3990A hi rad

• imf csf3990a_cc1 closed 2 HV-3416 hi rad

• imf csff3416_d_cc1 closed 2 HV-3417A hi rad

• imf csf3417a_d_cc1 closed 3 PORV 444B sticks at 10% after being demanded closed: TRG 1 imf rrc444b-m (1 0) 10 1 7 Fail RTB from opening on manual or auto trip

• CMFmalf / cBKRXTRP_cc21/ closed CMFmalf / cBKRXTRP_cc22/ closed 7 Main Turbine will not trip Automatically

• imf mal-tur2 8 1A MSIVs will not close on auto closure

• CMFmalf / crsh001a_cc5 /open CMFmalf / cmsh002a_d_cc5 /open 0 Tag 1A MDAFW pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 / open irf cBK2DH07_d_cd1 / open irf cBK1DH07_d_cd2 / open irf cBK2DH07_d_cd2 / open Triggers and Commands 3 Event Trigger 1 - monitors PORV444B HS closed position

• trgset 1 x30i115c 9 Trigger 3 On 1A MSIV closure, Fault in MSVR

• trgset 3 "XSLBA01" trg 3 "imf mal-mss2a 1 300" Farley June 2013 exam Page 2 of 4

Scenario 3 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 29% power, 1298 ppm, MOL; Ramping up, ramp on HOLD for chemistry.

Turnover:

Unit 2 PSS is OFF for Maintenance (OOS 2 hrs, ETR 2 hrs) 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs) 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Fuel handling is ongoing in the SFP.

Current Risk Assessment is YELLOW and projected is YELLOW, B Train On-Service - B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-115, VCT level controller, fails low.

Verifiable actions: Auto makeup must be stopped. Manual make-up required for ramp in event 5.

Event 2 R-25A, SPENT FUEL POOL VENTILATION RAD MONITOR, FAILS HIGH - SFP ventilation does not secure, PRF starts. TS 3.3.8 Condition A Verifiable actions: Manual isolation of dampers is to ensure SFP area is isolated properly.

Event 3 PT-444 fails high. Crew enters AOP-100. TS. 3.4.11 Condition A and 3.4.1 Condition A Verifiable actions: Close PORV 444B. PORV 444B discovered to be leaking by (RCS pressure continues to decrease) and PORV block valve must be closed.

Event 4 1A FRV Fails closed in Auto Verifiable actions: Take manual control of A FRV and restore SGWL Event 5 1A SG Tube leak. 15 gpm over 3 minutes and stabilizes. TS 3.4.13 condition B Verifiable actions: 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 6 Running SGFP trips.

Verifiable actions: Trip Reactor and enter FRP-S.1 Event 7 Rx will not Trip in AUTO or manual. Main Turbine will not trip in AUTO, manual trip required.

Verifiable actions: Secure Rod Drive MG Sets, Manual trip of the Main Turbine (CT)

Event 8 1A SGTR 500 gpm when EEP-0 entered.

Event 9 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.

ARP/ AOP-100/ AOP-2.0/ AOP-13/ E-0/ESP-0.1/ E-3/ E-2/ E-3 / ECP-3.1 Farley June 2013 exam Page 3 of 4

Scenario 3 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET

1. Manually trip the main turbine [before a sever (orange-path) challenge develops to either the subcriticality or the integrity CSF] or [before transition to ECP-2.1]

whichever happens first: (WOG CT FR-E - Q)

Isolate faulted SG before transitioning out of E-2.

2.

(WOG CT E - A)

Isolate AFW flow Isolate steam flow from 1A SG SCENARIO The team should be able to:

OBJECTIVE/ Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-100, and AOP-2.0 and evaluate Tech Specs.

Respond to a loss of SGFPs and then an ATWT event when the reactor will not trip.

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. This will cause a transition to ECP-3.1.

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

1. Total malfunctions (5-8) 10

2. Malfunctions after EOP entry (1-2) 4

3. Abnormal events (2-4) 5

4. Major transients (1-2) 3

5. EOPs entered/requiring substantive actions (1-2) 2

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Farley June 2013 exam Page 4 of 4

Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 75% power, 1177 ppm, MOL, Ramping up Turnover:

Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs) 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs) 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is YELLOW and projected is YELLOW, A Train On-Service - B Train Protected.

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

1 Imf I (RO) LT-460, pressurizer level, fails LOW, letdown secures lt460 TS (SRO) TS 3.3.1 Condition M 2 N (BOP) Restore Letdown 3 Imf I (BOP) FT-495, selected steam Flow Transmitter for 1C SG fails ft495 TS (SRO) HIGH Tech Spec 3.3.2 Condition D Function 1.e.4.

4 Imf C (RO) PK-444D, 1B RCP Spray valve, will open and can be closed in pk444d-a manual.

TS (SRO) TS 3.4.1 (RCS pressure) 5 Imf C (BOP) 1B Condensate Pump develops Degraded Head, Stby (1A ncfcn1b

-d % / cond) pump will not auto start.

preset 6 R (RO) Loss of 500KV line, SM directs 200 MW load reduction in 25 N (BOP) minutes 7 Imf M (ALL) 1C Condensate pump trips leading to BOTH SGFPs tripping cCfcn1c

_cc5 8 C (RO) Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered and begin driving rods in. (CT)

C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 9 Imf mal- M (ALL) LBLOCA when ESP-0.1 entered or step 5 of EEP-0.

rcs2b 10 C (BOP) A Train SI will not auto actuate.

1B RHR pump will not auto start and MOV-8803B will not open.

Required to establish one train of HHSI or LHSI flow. (CT)

Terminate in EEP-1.0 when transition to ESP-1.3 announced.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 1 of 4

Appendix D Scenario 5 Presets Form ES-D-1 PRESETS 8 1a crdm set fails to trip:

• CMFmalf / c52MGA_cr3 8 RTBs fail to open

• CMFmalf / cBKRXTRP_cc21 / closed CMFmalf / cbkrxtrp_cc22 closed 8 Prevent AUTO trip of main turbine

• MALF / T / MAL-TUR2 8 Prevent Manual trip of main turbine

• MALF / T / MAL-TUR24 10 Train A auto SI failure

• imf csftyinj_cc1 open 10 MOV-8803B does not open on SI

• imf csi8803b_d_cc5 open 10 1B RHR pump fails to auto start on SI

• imf crhp01b_d_cc9 open 5 Block 1A Cond pump from auto start

• imf ccfcn1a_cc8 open imf ccfcn1a_cc9 open imf ccfcn1a_cc10 open 0 Tag 1A MDAFW pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 / open irf cBK2DH07_d_cd1 / open irf cBK1DH07_d_cd2 / open irf cBK2DH07_d_cd2 / open 5 1B Condensate pump degraded head setup

• Imf jcfwfpll-s 250 Imf jcfwfplo-s 325 7 1A Condensate pump trips 5 seconds after 1C TRG 1 Imf cCFCN1a_cc5 (1 5) closed Triggers and Commands 7 When 1C condensate pump trips 1B condensate pump degrades to no flow Trgset 1 x22o061m Trg 1 imf ncfcn1b-d_th 100 60 Farley June 2013 exam Page 2 of 4

Scenario 5 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 75% power, 1177 ppm, MOL, Ramping up Turnover:

Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs) 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs) 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

Current Risk Assessment is YELLOW and projected is YELLOW, A Train On-Service - B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-460 fails LOW, letdown secures. TS 3.3.1 Condition M Verifiable actions: RO must take manual control of Charging to maintain pressurizer level less than tech spec (63.5%).

Event 2 Restore Letdown Verifiable actions: BOP will restore letdown to service by operating several valves.

Event 3 FT-495, selected steam Flow transmitter for 1C SG fails HIGH. Tech Spec 3.3.2 Condition D Function 1.e.4.

Verifiable actions: Take manual control of the 1C FRV and then select channel III instruments to control 1C SG functions.

Event 4 PK-444D, 1B RCP Spray valve, will open and can be closed in manual. TS 3.4.1 (RCS pressure)

Verifiable actions: Place the 1B RCP spray controller in manual and control RCS pressure using heaters and sprays before a Rx trip is required.

Event 5 1B Condensate Pump develops Degraded Head, Stby (1A cond) pump will not auto start.

Verifiable actions: start the standby Condensate pump before BOTH SGFPs trip Event 6 Loss of 500KV line, SM directs 200 MW load reduction in 25 minutes Verifiable actions: RO uses boration and/or rods, BOP operates DEH to set in ramp rate, target, initiate and stop ramp as necessary.

Event 7 Condensate pumps trip leading to BOTH SGFPs tripping, FRP-S.1 entry required.

Verifiable actions: Insert rods in manual or auto (RO) (CT)

Event 8 The Main Turbine will not trip in auto or manual, so the team will close governor valves to trip the Main Turbine (BOP) and then emergency borate (RO or BOP) (CT)

Event 9 LBLOCA when ESP-0.1 entered or step 5 of EEP-0.

Event 10 A Train SI will not auto actuate (*CT) 1B RHR pump will not auto start and MOV-8803B will not open. (*CT)

Terminate in EEP-1.0 when transition to ESP-1.3 announced.

AOP-100 / AOP-100 / AOP-100 / ARP-1.10 / AOP-17.1/ AOP-13/ FRP-S.1/ EEP-0/

EEP-1.0 Farley June 2013 exam Page 3 of 4

Appendix D Scenario 5 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 in service > 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

3. Manually start at least one low head ECCS pump before transition out of E-0.

(WOG CT E - H)

The 1B LHSI does not start and the 1A LHSI pump did not start due to the SI signal not actuating.

OR Establish flow from at least one High Head ECCS pump before transition out of E-0. (WOG CT E - I)

MOV-8803B does not open and due to the SI signal not actuating there will be no flow to the core.

• This is marked as one Critical task since flow to the core is the critical task. Actuating the SI signal will accomplish both tasks above or opening MOV-8803B and starting the 1B LHSI pump will accomplish the task.

SCENARIO Normal plant operation, fast ramp, 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 AOP-100, AOP-17.1, and AOP-13.

recognize the symptoms of an ATWT and implement the steps of FRP-S.1, EEP-0.0 and the recognize the LB LOCA and implement transition to EEP-1.0 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 10

2. Malfunctions after EOP entry (1-2) 5

3. Abnormal events (2-4) 5

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 3 Farley June 2013 exam Page 4 of 4

Appendix D Scenario #6 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 6 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 85% power, ramping to 18% power, 915 ppm, MOL.

Turnover:

Ramping unit to 18% power for containment entry to add oil to the 1B RCP.

1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs).

1A MDAFW T/O 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 YELLOW and projected is YELLOW.

A Train On-Service - B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.

SPLIT TRAIN ALIGNMENT Event Malf. No. Event Type* Event Description No.

R (RO) Ramp down at 2 MW/min -ramp on hold with 2 MW/min in and 1 N (BOP) HOLD not LIT- BOP will have to place the IMP PRESS LOOP in service, enter ramp rate and target, depress GO Irf loa- C (RO) 1C charging pump high lube oil temperature. Will have to be secured ccw059 and 1A or 1B Chg pump started.

2 TS (SRO) TS 3.5.2 Condition A Preset I (BOP) 1B SGFP develops speed oscillations -can be controlled in manual.

3 Imf lk459f- I (RO) LK-459F, PRZR LVL CONTROLLER, fails LOW 4 d imf mal- C (BOP) 1C RCP Thermal Barrier leak ccw6c 5

TS (SRO) TS 3.4.13 Condition A (until leak is isolated) irf loa- M (ALL) Vacuum degrades requiring a RX trip 6 cfw049 Preset C (RO) Reactor will not automatically trip; manual RX trip will occur upon operation of the second hand switch.

7 C (BOP) The Main Turbine will not trip in auto or manual, closing GVs in manual one GV sticks, required to close MSIVs. (CT)

Preset M(ALL) TDAFW pump will trip 1 minute after it starts.

8 The 1B MDAFW pump begins to experience degraded head.

Terminate event when condensate flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 1 of 4

Appendix D Scenario 6 Presets Form ES-D-1 PRESETS Event Malfunction

• means in Bat file No.

7 Fail RTB from opening in auto

• imf cbkrxtrp_cc6 open imf cbkrxtrp_cc5 open 7 MCB side Rx Trip Switch fails to cause trip

• imf cbkrxtrp_opos1 open 7 Prevent manual trip of main turb.

• imf mal-tur24 7 Main turbine fails to auto trip:

• imf mal-tur2 8 Trip TDAFW pump after one minute on after pump speed TRG 2 above 3500rpm imf mal-fwm1c (2 60) 8 Degrades head of B MDAFW pump to 95% degraded over 30 TRG 3 seconds after TDAFW pump trips imf nafp01b-d_th (3 5) 95 30 7 ALL MSIVs will not close on auto closure

• imf crsh001a_cc5 open imf cmsh002a_d_cc5 open imf crsh001b_cc5 open imf cmsh002b_d_cc5 open imf crsh001c_cc5 open imf cmsh002c_d_cc5 open 0 Tag Out 1A MDAFW Pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 open irf cBK2DH07_d_cd1 open irf cBK1DH07_d_cd2 open irf cBK2DH07_d_cd2 open Triggers and Commands 8 Event Trigger 1 GV2 reaches 25% going closed, it sticks at TRG 1 20% open trgset 1 "rehgvpz(2) < 25" trg 1 "imf mal-tur15f 20 1" 8 Event Trigger 2 Triggers trip of TDAFW pump after startup TRG 2 trgset 2 "oafp02 > 3500" 8 Event Trigger 3 Degrades the head of the B MDAFW pump TRG 3 trgset 3 "jmfwm1c > 0" 1 Event Trigger 4 Charging pump 1C trip due to high LO temp TRG 4 trgset 4 "tchspoil(3) > 175" trg 4 "imf cCVP01C_d_cc15 closed" Farley June 2013 exam Page 2 of 4

Scenario 6 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 85% power, ramping to 18% power, 915 ppm, MOL.

Turnover:

Ramping unit to 18% power for containment entry to add oil to the B RCP.

1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs) 1A MDAFW T/O 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 YELLOW and projected is YELLOW, A Train On-Service - B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Ramp down in power at 2 MW/min to 18% power.

Verifiable actions: RO will adjust rods or boron to control Tavg/Tref on program, BOP will place impulse loop in service, set target and ramp, and start a ramp on the Main Turbine.

Event 2 1C charging pump HIGH lube oil temperature. The 1C Chg pump will be tripped if temperature reaches 175°F. TS 3.5.2 Condition A Verifiable actions: 1C charging pump will have to be secured and 1A or 1B Chg pump started. If the charging pump trips, then letdown will be secured and re-established.

Event 3 1B SGFP develops speed oscillations and fails to minimum speed if left in Auto after 6 minutes.

Verifiable actions: Take manual control of SGFP speed and control SGWL.

Event 4 LK-459F, PRZR LVL CONTROLLER fails LOW Verifiable actions: RO will take manual control of charging and adjust seal injection flows.

Event 5 1C RCP Thermal Barrier leak, RCS into the CCW system. TS 3.4.13 Condition A (until leak is isolated)

Verifiable actions: Establish excess letdown, secure normal letdown, re-establish normal letdown and secure excess letdown, Isolate CCW cooling to thermal barrier to stop the leak.

Event 6 Degrading Vacuum, Auto Main Turbine and Rx trips are blocked. (SGFPs will trip on low vacuum at approx. 11 to 12 minutes)

Event 7 Reactor will not automatically trip; manual RX trip will occur upon operation of the second hand switch.

Main Turbine will not trip automatically or manually, Manual Fast action will be used to close GVs, One GV sticks open requiring MSIV closure (CT)

Verifiable actions: RO will trip the reactor. BOP will close the MSIVs Event 8 TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW is tagged out.

1B MDAFWP pump begins to experience degraded head.

Establish Condensate Pump flow to the SGs. (CT)

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

ARP / AOP-16 / AOP-100/ AOP-1/ AOP-8 / EEP-0/ FRP-H.1 Farley June 2013 exam Page 3 of 4

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

1. Failure of the turbine to trip. Manually actuate Main Steam line isolation before a severe (orange path) challenge develops to either the subcriticality or the integrity CSF: (WOG CT E - P)

Close ONE MSIV in each Main Steam Line.

2. 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). (1AF-FTS-PUMP-H) (WOG CT FR-H.1 - - A)

Verify flow to A, B, or C SG using condensate pumps.

SCENARIO The team should be able to:

OBJECTIVE/ Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-100, and Tech Specs Respond to an RCS Leak per AOP-1 and then a loss of vacuum event where the Rx will not trip automatically and the Main Turbine will not trip The crew will have to establish water flow to the SGs with the condensate pumps per FRP-H.1.

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

1. Total malfunctions (5-8) 8

2. Malfunctions after EOP entry (1-2) 3

3. Abnormal events (2-4) 4

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 0

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Farley June 2013 exam Page 4 of 4

Scenario #2 FA2013301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-36 NRC EXAM SCENARIO #2 Validation time: 120 minutes Validated by McCaffery, Sorrell, Phillips The week of February 18, 2013 TRN Supervisor Approval: Gary Ohmstede Date: 2/28/13 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 4% power, UOP-1.2, v103.1, completed thru step 5.62. Ready to perform step 5.63. MOL, 1350 ppm Cb; 1A SGFP on service. Aux steam from U-2.

Turnover:

• 1A SGFP is on service, MFR bypass valves are on service.

• Current Risk Assessment is GREEN and projected to remain GREEN.

• A Train O/S, A Train protected.

SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.

1 R (RO) Ramp up to 12% power.

2 imf I (RO) PK-145 fails high in automatic, letdown pressure controller failure pk145-a causes PCV-145 to close.

3 Imf I (BOP) 1A SGFP controller failure. SGFP speed will decrease to 3200 rpm SK509B until control of SGFP is regained.

-A 4 Imf C (RO) 1C charging pump sheared shaft.

Ncvp0 1c-b TS (SRO) T.S. 3.5.2 Condition A (mandatory until 1B charging pump swapped to opposite train) TRM 13.1.5 admin 5 N (BOP) Place letdown on service 6

Imf C (BOP) 1B SW pump trips on overcurrent.

cncps w1b_d

_co1 preset When the 1C SW pump is started, MOV-515 closes. AOP-7.0 will be entered to open MOV-515.

TS (SRO) T.S. 3.7.8 Condition A and 3.8.1 Condition B 7 Mal- M (ALL) 1A SGTR 300 gpm ramped in over 5 minutes.

rcs4A / C (RO) Block auto SI. Initiate a SI manually (CT) preset 8 preset C (BOP) Block all AFW pumps from auto starting on SI signal C (RO) 1A ARV FAILS OPEN during EEP-0 (CT)

Terminate in EEP-3.0 when RCS cooldown (CT) is complete.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 2 of 10

Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-212 and sim IC snap directory 1350 ppm Cb; 1A SGFP on service. Aux steam from U-2 Base IC is IC-33 RUN RUN simulator 0 0 Generic setup:

bat 36exam/generic_setup_HLT.txt Quick setup is in IC-212 0 0 Quick setup (all items with

• are included):

bat 36exam/2013nrcexam_2.txt PRESETS 9 Fail auto SI signals, Manual SI works

• CMFmalf / csftyinj_cc1 / open CMFmalf / csftyinj_cc11 / open 9 Prevent TDAFWP auto start

• CMFmalf / cMS3235B-cc1 / open CMFmalf / cms3235b_cc2 / open CMFmalf / cms3235a_cc1 / open CMFmalf / cms3235a_cc2 / open 9 Prevent MDAFWP auto start

• CMFmalf / Cafp01a_d_cr7 CMFmalf / Cafp01b_d_cr7 6 Indicate high flow condition in SW header TRG 2 imf af5 (2 5) failon 0 8 3371A ARV fails open 8 minutes after SI initiated TRG 1 imf pk3371A-A (1 480) 10 3 Triggers and Commands 8 CNH / 3371A-A Auto output failure high triggered on manual SI

• Trigger: jpplrtsi(1) > 0 3 Trigger 2: when 1c SW pump is started indicate high flow and

• mov-515 closure trgset 2 "nncpsw1c > 0" Trigger 3: Remove malfunction TRG 2 to allow reopening of MOV-515 trgset 3 "mncv515 == 0" trg 3 "dmf cncv515_cc7" Trigger 4: Close mov-515 on simulated high flow condition trgset 4 "xnmae06f" trg 4 " imf cncv515_cc7 closed" Trigger 5 turn off AF5 simulated flow spike trgset 5 "mncv515 < 0.98" trg 5 "imf af5 failoff" Farley June 2013 exam Page 3 of 10

Appendix D Scenario 2 Simulator setup Form ES-D-1 MCB setup DEH Clear DEH alarms Select OPS GROUP 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 Clear Recorders Cae clearrecorders.cae Provide a marked up copy of UOP-1.2 v103.1 completed UOP-1.2 copy thru step 5.62, Ready to perform step 5.63.

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 / 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 June 2013 exam Page 4 of 10

Appendix D Scenario 2 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 RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn Start of 1 exam Commence Ramp up to 12% power.

NRC 2 PK-145 fails high in automatic, letdown pressure CUE controller failure causes PCV-145 to close.

imf pk145-a 10 30 NRC 3 1A SGFP controller failure. SGFP speed will decrease CUE to 3200 rpm until control of SGFP is regained.

Imf SK509B-A 0 20 NRC 4 1C charging pump sheared shaft.

CUE Imf Ncvp01c-b 5 Place letdown on service NRC 6 1B SW pump trips on overcurrent.

CUE Imf cncpsw1b_d_co1 When the 1C SW pump is started, MOV-515 closes.

AOP-7.0 will be entered to open MOV-515.

Farley June 2013 exam Page 5 of 10

Appendix D Scenario 2 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND NRC 7 1A SGTR 300 gpm ramped in over 5 minutes.

CUE Imf Mal-rcs4A 300 600 8 All AFW pumps will not auto start on SI signal TRG 1 1A ARV FAILS OPEN Terminate in EEP-3.0 when RCS cooldown is complete.

SG overfill variable (SG full when > 0.995)

End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created.

exam2013sen2grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed Then Clear recorders for exam security Farley June 2013 exam Page 6 of 10

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 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 IF REQUESTED Alignment of 1C to auto-start for 1E SW pump will not take place during this exam.

IF REQUESTED Report alarms from TURB BLDG MISC alarm panel from panel view and clear alarms with button below.

Clear TURB BLDG MISC alarm imf kf2 failoff Report alarms from SGBD PROC PNL TRBL alarm panel from panel view and clear alarms with button below.

Clear SGBD PROC PNL TRBL alarm JB5 imf jb5 failoff 7 NONE REQUIRED 8 NONE REQUIRED Farley June 2013 exam Page 7 of 10

Appendix D Scenario 2 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

ALL AS REQUIRED SSS, SM and Dispatcher:

(Standard Repeat back failure, procedure entered, plant status, CR in the cue communications to and that type of communications.

inform supervision) 1 IF REQUESTED SSS-plant, Will have EM prepare to close Disconnect 915 per UOP-1.2, step 5.60.7.

2/3 NONE EXPECTED 4 WHEN REQUESTED Radside SO:

Called to check 1C charging pump, After 3 minutes report the following.

• the 1C charging pump motor is running

• Lube oil temperatures have decreased.

• There is no discharge pressure on the local discharge pressure gage.

• Making a grinding noise and pump is NOT rotating.

5 NONE EXPECTED 6 WHEN REQUESTED SSS / OUTSIDE:

1B SW pump breaker DK-04 has an overcurrent flag. I do not see any obvious problems with pump or motor. Oil levels look good.

1C 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 1C SW pump to auto start for 1B SW pump. (SOP-24.0D checklist) 7 WHEN REQUESTED SM:

I will make the classifications and notifications.

SM / SSS:

I will get an extra operator to secure the running DGs ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

8 NONE EXPECTED Farley June 2013 exam Page 8 of 10

Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 4% power, UOP-1.2, v103.1, completed thru step 5.62, Ready to perform step 5.63. MOL, 1350 ppm Cb; 1A SGFP on service. Aux steam from U-2.

Turnover:

• 1A SGFP is on service, MFR bypass valves are on service.

• Current Risk Assessment is GREEN and projected to remain GREEN.

• A Train O/S, A Train protected.

Event 1 Commence Ramp up to 12% power.

Verifiable actions: RO uses rods to increase RCS temperature, adjusts Steam Dumps to increase Stm flow and Rx power, and adjusts MFW flow to the SGs (Bypass FRVs on service).

Event 2 PK-145, letdown pressure controller, fails high.

Verifiable actions: Take manual control of PK-145 and restore pressure or remove letdown from service.

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

Verifiable actions: Manual control of SGFP and Bypass FRVs to control SGWL.

Event 4 1C Charging pump shaft will shear. This will cause a loss of charging flow with the pump running. Letdown will be secured and restoration of letdown will be required. TS 3.5.2 condition A and TRM 13.1.5 admin (mandatory while swapping the 1B Chg pump to B Train)

Verifiable actions: Secure letdown, secure the running Chg pump and start one Chg pump.

Event 5 Place letdown back on service per AOP-16.0.

Event 6 1B Service Water pump trips on over current. When 1C service water pump is started, MOV-515 goes closed. LCO 3.7.8 Condition A and 3.8.1 Condition B (LOSF with ECCS failure above)

Verifiable Actions: start the SW pump and open MOV-515.

Event 7 1A SGTR 300 gpm ramped in over 5 minutes.

The AUTO SI is blocked. Verifiable actions: Initiate a manual SI (CT)

Event 8 No AFW pumps start. Verifiable actions: Start one AFW pump to prevent the intact SGs from losing SGWL and for cooldown inventory.

1A ARV fails open after the SI occurs. Verifiable actions: Isolate SGs (ARV closed and MSIV closed; and AFW, when started) (CT)

Terminate in EEP-3.0 when RCS cooldown (CT) is complete at step 6.6.

UOP-1.2/ ARP/ AOP-100/AOP-16/AOP-10/AOP-7/E-0/E-3 Farley June 2013 exam Page 9 of 10

Scenario 2 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: (WOG CT E - D)

• Transition to any E-3 series procedure

2. Isolate feed flow and steam from ruptured SG in EEP-3.0 before a transition to ECP-3.1 occurs. (WOG CT E - A)

• Close or isolate 1A ARV

• Isolate AFW flow to the ruptured SG when >31%

• At least one MSIV closed on 1A SG

3. Establish/maintain an RCS temperature so that transition from E-3 does not occour because the RCS temperature is in either of the following conditions.

(WOG CT E - B)

• Too high to maintain [minimum required subcooling]

• Below [the RCS temperature that causes an extreme (red-path) or a severe (orange-path) challenge to the subcriticality and/or the integrity CSF]

SCENARIO Low power instrument and component failures with a SGTR.

OBJECTIVE/ The team should be able to:

OVERVIEW:

• ramp the plant from 4% to 12 % power,

• respond to several instrument failures that affect the SW system,

• respond to a charging pump malfunction,

• respond to a SGFP controller failure and PK-145 malfunction,

• diagnose a SGTR,

• The crew will have to start AFW pumps when E-0 is entered, and discover and close a failed open ARV on the ruptured SG.

• Termination of the event will be when the crew completes the RCS cooldown.

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

1. Total malfunctions (5-8) 7

2. Malfunctions after EOP entry (1-2) 3

3. Abnormal events (2-4) 4

4. Major transients (1-2) 1

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 0

7. Critical tasks (2-3) 3 Farley June 2013 exam Page 10 of 10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 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% IAW 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 Comments UOP-1.2, Startup of Unit from Hot Standby to Minimum Load, version 103.1 RO (step 5.63)Begin to increase reactor power Manual adjustment of rods to greater than 12% with following controls. (not more than 3 steps at a

• Manual adjustment of control rods time)

Stm dump control - adjust PK-

• Steam dumps in Steam Pressure 464 counterclockwise to Control Mode release more steam, decrease Tavg, pull rods and increase power SRO Monitor reactor power and Steam Dump Examiner NOTE: Diluting is adjustments as reactor power rises not procedurally required or expected at step 5.63 of UOP-1.2 and as such would not be a part of the reactivity plan BOP Will be reviewing UOP-1.2 and getting ready to roll the main turbine.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 1 Page 2 of 44 Event

Description:

Ramp up to 12% power Time Pos. Expected Actions/Behavior Comments RO (step 5.65) WHEN Nuclear at Power Permissive P-10 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 A to BLOCK.

• Place POWER RANGE BLOCK TRN B to BLOCK.

Verify the following on the Bypass and Permissive Panel:

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

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

RO (step 5.65.5) 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 (step 5.65.6)Verify NR-45B is in the desired nd speed, i.e., 2 speed (2 min/div) OR normal speed. (10 min/div)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 1 Page 3 of 44 Event

Description:

Ramp up to 12% power Time Pos. Expected Actions/Behavior Comments SRO (step 5.65.7) IF not previously performed at Step 5.51, direct qualified OPS personnel to close disconnect switch 915 in accordance with FNP-0-SOP-36.8 When 8-12% power is reached and at the discretion of the Lead Examiner move to next event.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 4 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close This controller will fail high slowly. The Letdown relief valve may open and DE3 will come into alarm. If the RO or BOP takes manual control per DE4 and reduces pressure, then letdown will not be secured. Once DE3 comes into alarm, DE3 will direct AOP-16 entered if letdown was lost.

Indications Available:

Annunciators: Recognize indications of PK-145 failing:

- LTDN ORIF ISO VLV REL LINE TEMP HI - Letdown HX outlet pressure (PI-145)

(DE3) increases to 600 psig

- LTDN HX OUTLET PRESS HI (DE4) - Letdown flow (FI-150) decreases to zero

- Letdown orifice isolation relief line to PRT Comment: The Letdown relief valve lifts to the temperature (TI-141)

PRT. - LI-112/115, VCT level, Time Pos. Expected Actions/Behavior Comments ARP-1.4, MCB ANNUNCIATOR PANEL D, DE4 version 53.0 SRO Direct entry into DE4.

RO (step 1) Monitor LTDN HX Outlet Flow (FI-150) and LTDN HX Outlet Press (PI-145).

RO (step 2) Ensure proper orifice isolation valve selection.

RO (step 3) IF the high pressure is due to LP PK-145 placed in manual and LTDN PRESS PK-145 malfunction, THEN controlled manually. ( May place valve controller in manual and attempt have been done earlier using to reduce the pressure. Skill of the craft)

RO (step 4) IF pressure can NOT be controlled manually with LP LTDN PK-145, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B, and C.

RO (step 5) IF a ramp is in progress, THEN place turbine load on HOLD.

SRO (step 6) Go to AOP-16.0, CVCS (see next page if AOP-16 is MALFUNCTION to address the loss of entered) letdown flow.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 5 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close ARP-1.4, MCB ANNUNCIATOR PANEL D, DE3 version 53.0 SRO Direct entry into DE3 If required RO (step 1) Monitor the LTDN ORIF ISO REL line to PRT Temperature (TI-141) and LTDN HX Outlet Press (PI- l45).

RO (step 2) If the high temperature is due to LP LTDN press PK-145 malfunctions, THEN place valve controller in manual and adjust as required.

RO IF temperature continues to rise rapidly indicating a lifted relief valve, THEN close LTDN ORIF ISO 45 (60) GPM Q1E21HV8149A, B AND C.

RO (step 4) IF a ramp is in progress, THEN place turbine load on HOLD.

(step 5) Direct AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow, if required.

Entry into DE3 may or may not require letdown to be isolated If letdown is secured then AOP-16 guidance is below:

AOP-16, CVCS Malfunction, ver 18.0 RO (Step 1) Verify charging flow adequate to cool letdown.

RNO - close all LTDN ORIF ISOs

[] Q1E21HV8149A Letdown flow may be secured

[] Q1E21HV8149B

[] Q1E21HV8149C RO (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 6 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close RO (Step 4) [CA] Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.

[] PI-121

[] AMMETER FOR RUNNING CHG PUMP RO (Step 5) Check charging pump - RUNNING RO (Step 6) Check Charging flow FK-122 controlling in AUTO with flow indicate RO (Step 7) Check DE3 clear May or may not be clear RO (Step 8) Determine Status of Normal Letdown will have been Letdown: removed from service so it will Check normal CVCS letdown - AFFECTED be placed in service.

BY MALFUNCTION (If letdown is still in service

- LTDN HX OUTLET FLOW, FI-150, NO procedure directs you to step FLOW INDICATED [18.1 IF charging is normal, (Step 8.2) Minimize RCS makeup: THEN go to procedure and Manually close charging flow control: step in effect.])

CHG FLOW

[] FK-122 (Step 8.2.2) Minimize seal injection between 6-13 gpm (Step 8.2.3) Direct Chemistry to shutdown the zinc addition system (ZAS)

(Step 8.3) Dispatch personnel to investigate cause of the Letdown malfunction RO (Step 9) Determine if normal letdown should be re-established: Yes PCV-145 is in manual Check normal letdown malfunction(s) - control CORRECTED

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 7 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close RO Restore letdown with the following steps:

(Step 9.2) Verify all letdown orifice isolation valves - CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C (Step 9.3) Place LTDN HX OUTLET TEMP TK 144 on service:

[] Place controller in AUTO

[] Set to maintain temperature 90 to 115°F RO (Step 9.5) Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[] Position indicator VCT light - LIT

[] Handswitch in - AUTO RO (Step 9.4) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

[] DEMIN light - LIT

[] Handswitch in - AUTO (Step 9.5) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT (Step 9.6) IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's from the PRIP.

[] Q1E21HV8175A

[] Q1E21HV8175B RO (Step 9.7) Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO (Step 9.8) Verify LTDN LINE ISO valves -

OPEN

[] Q1E21LCV459

[] Q1E21LCV460 RO (Step 9.9) Place LP LTDN PRESS PK 145 on service:

[] Place controller in MANUAL

[] Adjust demand signal to 50% or less

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 8 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close RO (Step 9.10) Initiate minimum charging flow:

(Step 9.10.1) Verify CHG FLOW FK 122 in

- MAN (Step 9.10.2) Establish minimum charging flow based on orifices to be placed on service:

1 Orifice - 18 gpm OR 2 Orifices - 40 gpm (Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:

[] Q1E21HV8149B OR

[] Q1E21HV8149C RO (Step 9.12) IF desired, THEN place the second orifice on service by OPENING:

[] Q1E21HV8149A RO (Step 9.13) Initiate actions to restore letdown flow to the demins per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION RO (Step 9.14) [CA] IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing.

(Step 9.15) Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 PSIG

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 2 Page 9 of 44 Event

Description:

PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close RO (Step 9.15.1) Set controller between 4.3 NOTE: Cannot complete step and 7.5 9.15.3, will reintroduce failure (Step 9.15.2) Check letdown flow - STABLE (Step 9.15.3) Place PK 145 in AUTO (Step 9.15.4) Control Letdown pressure as desired (Step 9.16) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP (Step 9.17) Refer to SOP-2.1, CVCS system PLANT STARTUP AND OPERATION, for further guidance on Letdown system control RO (step 10) Determine status of letdown flow: Check letdown flow - established RO (step 10.2) 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 When PK-145 is in manual control with letdown in service and at the discretion of the Lead Examiner move to the next event.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 3 Page 10 of 44 Event

Description:

1A SGFP controller failure LOW, speed will decrease to 3200 rpm.

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 SGWLs 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

- Rx Power

- RCS temp will Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, ver 12, section 1.4 (AOP-13, ver 30, 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, 1A/B SGFP SPEED continuing action step CONT, in Manual and raise 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.

• 1B SG BYPASS FLOW FK-489

• 1C SG BYPASS FLOW FK-499 IF a loss of main feedwater occurs, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER (step 2) If adverse trends in the SG level SRO exist then establish trip criteria If an automatic action is required or set NOTE: if the SGFP trips at points is approached: 82% level then the reactor Trip the reactor and go to EEP-0 would be tripped at this point.

BOP (step 3) There will not be a ramp in progress since the main turbine is not on line.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 3 Page 11 of 44 Event

Description:

1A SGFP controller failure LOW, speed will decrease to 3200 rpm.

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 mode STM PRESS mode.

RNO 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 the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 12 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown 1C Charging pump will experience a shaft shear. Due to the alignment of charging, this pump will be secured and a pump in the other train will be started.

Indications Available:

Annunciators: Recognize indications of sheared shaft

- CHG HDR FLOW HI-LO (EA2) - FI-122A decreasing to 0 gpm

- RCP SEAL INJ FLOW LO (DD1) - 1C Chg pump amps decrease to 52 amps

- REGEN HX LTDN FLOW DISCH TEMP HI - SI flow decreases to 0 gpm on all 3 RCPs (DE1) - VCT level will

- Przr level will slowly

- FK-122 demand will go to approx. 0

- LK-459F will slowly Time Pos. Expected Actions/Behavior Comments AOP-16, CVCS Malfunction, ver 18.0 EA2 will direct the crew to AOP-16.0 SRO Determine a charging system malfunction is occurring and direct entry into AOP-16.

RO - Monitor VCT level

- Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation

- PI-121 and ammeter for chg pump

- Actual amps will be lower than normal RO (Step 1) Verify charging flow adequate to RNO - close all LTDN ORIF cool letdown. ISOs CHG FLOW [] Q1E21HV8149A

[] FI-122A [] Q1E21HV8149B LTDN HX OUTLET FLOW [] Q1E21HV8149C

[] FI-150 REGEN HX OUTLET TEMP

[] TI-140 RO (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 13 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown RO (Step 4) [CA] Observe CHG HDR PRESS Amps will be lower than and MOTOR AMPS to ensure proper normal charging pump operation.

[] PI-121

[] AMMETER FOR RUNNING CHG PUMP RO (Step 5) Check charging pump - RUNNING YES but since the shaft is sheared the answer is NO RNO for step 5 RO (step 5) RNO Start an available charging NOTE: 1C charging pump may pump as follows: be stopped at any time but will (step 5.1) Check VCT level and pressure not be procedurally directed to be secured.

adequate.

(step 5.2) Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

[] Q1E21LCV115C - OPEN

[] Q1E21LCV115E - OPEN OR RWST TO CHG PUMP valves

[] Q1E21LCV115B - OPEN

[] Q1E21LCV115D - OPEN (step 5.3) Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

RO (step 5.4) Check open miniflow isolation for charging pump to be started:

• 1A CHG PUMP MINIFLOW ISO, Q1E21MOV8109A

• 1B CHG PUMP MINIFLOW ISO, Q1E21MOV8109B (step 5.5) Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 14 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown RO (step 5.6) Verify the following are closed:

[] CHG FLOW FK 122

[] SEAL WTR INJECTION HIK 186 (step 5.7) Verify a CCW pump is running in same train aligned to supply charging pump to be started.

RO (step 5.8) Start selected charging pump.

(step 5.9) Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation.

(step 5.10) WHEN charging pump comes up to speed, THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

RO (step 5.11) Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP.

RO (Step 6) Check Charging flow FK-122 RNO controlling in AUTO with flow indicated 6.1 Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

6.2 Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm.

RO (Step 7) Check DE3 clear

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 15 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown RO (Step 8) Determine Status of Normal Letdown will have been Letdown: removed from service so it will Check normal CVCS letdown - AFFECTED be placed in service.

BY MALFUNCTION

- LTDN HX OUTLET FLOW, FI-150, NO FLOW INDICATED (Step 8.2) Minimize RCS makeup:

Manually close charging flow control:

CHG FLOW

[] FK-122 (Step 8.2.2) Minimize seal injection between 6-13 gpm (Step 8.2.3) Direct Chemistry to shutdown the zinc addition system (ZAS)

(Step 8.3) Dispatch personnel to investigate cause of the Letdown malfunction NA - this is known RO (Step 9) Determine if normal letdown should be re-established:

Check normal letdown malfunction(s) -

CORRECTED Restore letdown with the following steps:

RO (Step 9.2) Verify all letdown orifice isolation valves - CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C (Step 9.3) Place LTDN HX OUTLET TEMP TK 144 on service:

[] Place controller in AUTO

[] Set to maintain temperature 90 to 115°F

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 16 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown (Step 9.4) Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

[]Position indicator VCT light -LIT

[] Handswitch in - AUTO (Step 9.5) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT (Step 9.6) IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's from the PRIP.

[] Q1E21HV8175A

[] Q1E21HV8175B RO (Step 9.7) Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO (Step 9.8) Verify LTDN LINE ISO valves -

OPEN

[] Q1E21LCV459

[] Q1E21LCV460 (Step 9.9) Place LP LTDN PRESS PK 145 on service:

[] Place controller in MANUAL

[] Adjust demand signal to 50% or less RO (Step 9.10) Initiate minimum charging flow:

(Step 9.10.1) Verify CHG FLOW FK 122 in

- MAN (Step 9.10.2) Establish minimum charging flow based on orifices to be placed on service:

1 Orifice - 18 gpm OR 2 Orifices - 40 gpm (Step 9.11) Establish approximately 60 gpm letdown flow by OPENING: Upon restoration of flow,

[] Q1E21HV8149B letdown line may be flashed to OR steam and take time to refill.

[] Q1E21HV8149C

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 17 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown RO (Step 9.12) IF desired, THEN place the second orifice on service by OPENING:

[] Q1E21HV8149A (Step 9.13) Initiate actions to restore letdown flow to the demins per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION RO (Step 9.14) [CA] IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing.

(Step 9.15) Adjust LP LTDN PRESS PK 145 RNO step required here due to to maintain desired letdown pressure - earlier controller failure.

BETWEEN 260-450 PSIG Directs pressure control in manual.

RO (Step 9.16) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP (Step 9.17) Refer to SOP-2.1, CVCS system PLANT STARTUP AND OPERATION, for further guidance on Letdown system control (step 10) Determine status of letdown flow: Check letdown flow - established SRO (step 10.2) Go to procedure and step in effect Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

Notify the Shift Manager

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 4/5 Page 18 of 44 Event

Description:

1C charging pump sheared shaft / Restore Letdown SRO Refer to Technical Specifications LCOs 3.5.2, and Technical Requirements TR 13.1.5 3.5.2 Mandatory LCO Condition A; since the 1B chg pump is aligned to A Train. 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO until the 1B chg pump is placed on B Train and the 1C CHG pump is either racked out or has a jumper installed to allow 1B chg pump to auto start 13.1.5 Admin LCO Condition A. Two charging pumps shall be operable. 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO TECHNICAL SPECIFICATION 3.5.2, ECCSOperating Two ECCS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore train(s) to trains inoperable. OPERABLE status 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

TECHNICAL REQUIREMENT 13.1.5, Charging Pumps - Operating Two charging pumps shall be FUNCTIONAL.

APPLICABILITY: MODES 1, 2, 3, and 4 This is an ADMIN LCO except during the pump swap placing 1B charging pump on A Train SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One required A.1 Restore at least two charging pump charging pumps to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> nonfunctional. FUNCTIONAL status.

At the discretion of the Lead Examiner move to the next event.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 6 Page 19 of 44 Event

Description:

1B SW pump trips.

1B SW pump will trip. SW pressure will lower but remain >60psig. 1C SW pump is available to start and then tech specs evaluated. When 1C SW pump started a flow transient causes a SW to TB MOV to close requiring AOP-7 entry.

Indications Available:

Annunciators: Recognize indications 1B SW PUMP TRIP

- SW PUMP TRIPPED (AE4) - Yellow flag above 1B SW pump handswitch

- SW TO TURB BLDG A OR B TRN FLOW - PI-3001A/B SW TO CCW HX PRESS, HI (AF5) decreasing Time Pos. Expected Actions/Behavior Comments Annunciator Response Procedure ARP-1.1, version 53.1, AE4 BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP BOP (step 1) Check Indications and determine 1B SW pump has a yellow trip which SW pump tripped flag BOP (step 2) Start the 1C SW pump NOTE: When this pump is started MOV-515 will close and AOP-7.0 will be entered for actions see PAGE 21 SRO (step 3) REFER to AOP-10 IF entered actions listed on PAGE 21 SRO (step 4) Direct SSS entry into SOP-24.0 step 4.6 to align 1C SW pump for auto start to replace the 1E SW pump BOP (step 5) Dispatch personnel to the 1B SW Sends SSS and Outside SO pump and breaker.

BOP (step 6) Return the Service Water electrical and component lineup to normal as soon as possible.

SRO (step 7 of ARP AE4) Refer to tech spec 3.7.8 for LCO requirements

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 6 Page 20 of 44 Event

Description:

1B SW pump trips.

Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.7.8 - Service Water System (SWS)

Two SWS trains shall be OPERABLE.

SRO 3.7.8 Condition A applies due to the 1B SW pump being tripped and the 1C SW pump not being selected to auto start for the 1B SW pump CONDITION REQUIRED ACTION COMPLETION TIME A. One SWS A.1 -NOTES----- 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> train 1. Enter applicable Conditions and inoperable. Required Actions of LCO 3.8.1, "AC Sources Operating," for emergency DG made inoperable by SWS.

Restore SWS train to OPERABLE status.

TECHNICAL SPECIFICATION 3.8.1 - 3 AC SourcesOperating SRO From 3.7.8 Condition A above, 3.8.1 has to be entered. Condition B applies.

SRO CONDITION REQUIRED ACTION COMPLETION TIME B. One DG B.1 Perform SR 3.8.1.1 for the 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND set required offsite Once per 8 The bolded inoperable circuit(s). hours Thereafter conditions are AND the most likely B.2 Declare required 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from path the SRO feature(s) supported by discovery of the inoperable DG set inoperable Condition B will evoke.

when its required redundant concurrent with B.1 and B.2 and feature(s) is inoperable inoperability of B.3.1 redundant AND required feature(s)

B.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG set is not inoperable due to common cause failure.

OR B.3.2 Perform SR 3.8.1.6 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG set.

AND B.4 Restore DG set to OPERABLE 10 days status AND 13 days from discovery of failure to meet LCO NOTE: LOSF w/ECCS failure should be identified. Since this is a 4 hr LCO and the 1B SW pump would be selected out in ~1 hour this may have to be discussed during post exam questions.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 6 Page 21 of 44 Event

Description:

1B SW pump trips.

Time Pos. Expected Actions/Behavior 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 AOP-10, Loss of Service Water, version 16 BOP (step 1) Verify DF02, 1F 4160 V bus tie to 1K 4160 V bus and DG02, 1G 4160 V bus tie to 1L 4160 V bus, are closed BOP (step 2) Start any available SW pump BOP (step 3) IF SW pressure in both trains greater than 60 psig, THEN go to procedure and step in effect.

AOP-7, Loss of Turbine Building Service Water, version 13 NOTE: Students may restore service water per ARP AF5, ver 53.1 guidance:

• If Service Water flow has been lost to the Turbine Building, THEN attempt to restore Service Water flow.

• Refer to FNP-1-AOP-7.0, LOSS OF TURBINE BUILDING SERVICE WATER and perform any actions required.

BOP (step 1)Check at least one SW train aligned to turbine building.

Check A train SW - ALIGNED TO TURBINE BUILDING.

SW TO TURB BLDG ISO A TRN

[ ] Q1P16V515 open

[ ] Q1P16V516 open OR Check B train SW - ALIGNED TO TURBINE BUILDING SW TO TURB BLDG ISO B TRN

[ ] Q1P16V517 open

[ ] Q1P16V514 open

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 6 Page 22 of 44 Event

Description:

1B SW pump trips.

Time Pos. Expected Actions/Behavior Comments BOP (step 2) IF main generator on line, THEN check generator hydrogen temperature less than 46°C by the following:

[ ] TI-4067 BOP (step 3) Check SW HDR Pressure - RNO 3 CLOSE SW DIL BYP GREATER THAN 110 psig. ISO.

Train A Train A

[ ] PI-3001A [ ] Q1P16V558 Train B Train B

[ ] PI-3001B [ ] Q1P16V557 BOP (step 4) Restore both trains of SW to turbine building.

4.1 Dispatch personnel to correct cause for loss of SW.

4.2 WHEN cause for loss of SW corrected, THEN verify both SW trains aligned to turbine building.

SW TO TURB BLDG ISO A(B) TRN

[ ] Q1P16V515 open

[ ] Q1P16V516 open

[ ] Q1P16V517 open

[ ] Q1P16V514 open SRO (step 5) IF at least one SW train aligned to turbine building, THEN monitor turbine building component temperatures and go to procedure and step in effect.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 7 Page 23 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes 1A SG tube leak will start and ramp in over 5 minutes. Because of power level SG tube leak alarm (FG1) does not function. Based on leak rate early in AOP-2.0 SI criteria will be met.

Indications Available:

Annunciators: Recognize indications of SG TUBE LEAK

- RMS HI RAD (FH1) - R-15, 19 AND 23 IN ALARM

- Charging flow

- Pzr level Time Pos. Expected Actions/Behavior Comments ARP-1.6, Annunciator response procedure, FH1 Ver. 70 BOP Reference ARP FH1 (step 1) Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity.

(step 2) Insure any auto actions have occurred.

BOP Check ARP FH1 for actions as Rad monitors come into alarm.

(step 3.3) Do not allow personnel to enter the affected area without the approval of the Health Physics Department.

(step 3.6) IF high activity indication of Steam Generator Tube Leakage is present, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR TUBE LEAKAGE.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 7 Page 24 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments SRO/ IF R-15 alarms AND remains above the BOP alarm setpoint (not a momentary spike),

THEN perform the following:

• IF high effluent activity is possible, THEN implement NMP-EP-110

• Notify the Counting Room to immediately sample the SGs per CCP-31 to determine the leak rate.

• Notify the Operations Shift Manager.

• IF an actual SG tube leak is confirmed, consider placing SJAE Filtration System in service per FNP-1-SOP-28.5.

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.

AOP-2.0, Steam Generator Tube Leakage Ver. 35 RO (step 1) Maintain pressurizer level stable at NOTE: [CA] step -

normal programmed value by: RNO is to trip the Rx and

- Control charging actuate an SI Critical task

- Reduce letdown close HV-8149 A, B, C to actuate SI (step 1 or 3 of this AOP)

RO (step 1.3) Determine leak rate, if possible Plant conditions will NOT (use STP-9.0, RCS leakage) permit the use of STP-9.0, so (RNO step 1.3) Determine leak rate based on a leak rate flow balance will be flow balance used.

___________(charging flow)

+___________(seal injection flow)

-___________(letdown flow)

-___________(#1 seal leakoff flow)

=___________(RCS leak rate)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 7 Page 25 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments RO (step 2) Maintain VCT level greater than NOTE: [CA] step -

20%. by: RNO is to trip the Rx and Verify RMW system in AUTO actuate an SI OR Critical task Manually control makeup as required by to actuate SI (step 1 or 3 of using SOP-2.3, CVCS Rx makeup system this AOP)

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: [CA] step -

leakage Check R-70s or R-15 for increasing count rate Begin trending R-70C, SG TUBE LEAK, and Chemistry will acknowledge R-15, SJAE EXH, using the plant computer CCP-31 app C and Data sheet 1.

BOP (step 6) Call TBSO to place SJAE filtration on service.

SRO (step 7) Direct chemistry to perform grab samples and leak rate determinations.

CCP-201 Table 55 (step 8) Notify SM of leak rate NOTE: [CA] step -

(step 9) Continue to monitor R-70s, R-15 or NOTE: [CA] step -

CHM/HP leak rate input for primary to secondary leak rate and rate of change using Data sheet 1.

SRO (Step 10) Monitor the Continuous Radiation NOTE: [CA] step -

Monitoring System operation.

[ ] R OPERABLE OR

[ ] R-70s - OPERABLE SRO (step 11) Evaluate Table to determine appropriate response:

- ACTION LEVEL 3 Condition 1 30 gpd/hr rate of increase AND 75 gpd leak in any SG

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 7 Page 26 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments SRO (step 12) For entry into Action Level 3 Crew not expected to get Condition 1 perform the following: beyond this point in AOP-2 12.1 Check any two of the following rad before meeting SI Criteria.

monitors trending in the same manner.

[ ] R-70s/R-15 trending in the same direction with the same order of magnitude.

OR

[ ] R-70s/R-23A(B) trending in the same direction with the same order of magnitude.

OR

[ ] R-15/R-23A(B) trending in the same direction with the same order of magnitude.

12.2 Reduce power to less than or equal to 50% rated thermal power within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

12.3 Place the Unit in Mode 3 within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> of entering Action Level 3 Condition 1.

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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 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.

The next event is based on evaluation of plant conditions by the crew. It is expected the RX trip and SI will be completed early in the AOP-2 actions. Tech Spec evaluation if required by examiner may be delayed until after scenario termination.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 27 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes EEP-0 entered based on a RX trip and SI directed by AOP-2. Crew will meet transition criteria for EEP-3.0 Indications Available:

Annunciators: Indications of LOSP/RX trip

- Various and numerous - Nuclear power

- Rod bottom lights

- Control Room Lighting Time Pos. Expected Actions/Behavior Comments EEP-0, Reactor Trip or Safety Injection, rev 44 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 (step 3) Check power to 4160 V ESF busses.

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

RO/ (step 4) Check SI Status.

BOP (step 4.1) Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit (step 4.2) Verify both trains of SI-ACTUATED.

[] MLB-1 1-1 lit AND [] MLB-1 11-1 lit

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 28 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments SRO (step 5) Directs continuing into EEP-0 at step For Attachment 2 and 4

5. actions.

Directs the BOP to perform Go to page 37 Attachment 2 of EEP-0.

EEP-0 FOLD OUT PAGE CRITERIA IN EFFECT NOTE: [CA] step Ruptured SG AFW Isolation. The action to Isolate AFW to the ruptured SG may be

• Manually stop AFW flow to a SG if BOTH completed beyond this conditions listed below occur: point.

• Level increases in an uncontrolled manner or radiation in that SG is abnormal AND

• Narrow range level - GREATER THAN 31% {48%}

(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig (checked on IPC or PI950, 951, 952, 953,CNMT PRESSURE)

RO (step 7) Announce "Unit 1 reactor trip and safety injection".

RO (step 8) Check AFW status. RNO 8.1.1 Verify all available Check secondary heat sink Available AFW pumps started.

o Check total AFW flow > 395 gpm

[] FI 3229A AFW pumps fail to autostart.

[] FI 3229B Operator should start AFW

[] FI 3229C pumps here if not already o Total Flow FI 3229 complete.

OR May have been started earlier Check any SG NR level > 31% {48%} based on backing up an automatic function that did not WHEN all SG narrow range levels less than occur.

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.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 29 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes 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

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] 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

[] TI 432D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 30 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments 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) 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 cool down, AFW FLOW TO 1A(1B,1C) SG

[] FI 3229A

[] FI 3229B

[] FI 3229C AFW TOTAL FLOW

[] FI 3229 IF MSIVs are closed THEN proceed to step 9.1.8 BOP (step 9.1.5 RNO) IF MSIVs are open THEN isolate steam loads in the turbine building:

• MSRs reset (steps 9.1.5.1 and 9.1.5.2 RNO) these actions are performed by Systems Operators when RX trip is announced in step 7.

(9.1.5.3 RNO is already complete) Gland seal from Unit 2 BOP (step 9.1.5.4 RNO) IF two SJAEs in service, THEN secure one SJAE

• 1A SJAE o A Section ISO closed o B Section ISO closed

• 1B SJAE o A Section ISO closed o B Section ISO closed

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 31 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments BOP (step 9.1.6 RNO) IF cool down continues .

THEN close main steam isolation and bypass valves.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B

[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYPASS

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C 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 PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 NOTE: [CA] step -

psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 32 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments 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

[] PI 402A

[] PI 403A 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.

(step 13.1) Check no SG pressure -

FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.

SRO Check SGs not ruptured. RNO Go to FNP-1-EEP-3, STEAM GENERATOR TUBE Check secondary radiation RUPTURE.

indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

No SG level rising in an uncontrolled manner.

EEP-3.0, SGTR, ver 27 RO (step 1) Check RCP criteria.

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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 33 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments BOP (step 2) Identify ruptured SG(s). NOTE: [CA] step Check any SG level - RISING IN AN UNCONTROLLED MANNER SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: [CA] step RO THEN isolate flow from ruptured SG(s). 1A SG is ruptured Verify ruptured SG(s) atmospheric relief Because the ARVs controller valve - ALIGNED. is failed, placing the valve in AUTO will result in it going full

- PC3371A, 1A MS ATMOS REL VLV, set open. Crew should recognize 8.25 and in auto this and NOT place the controller in AUTO.

- Verify 3371A, 1C MS ATMOS REL VLV, Critical task is closed (step 3.6) Verify blowdown from ruptured SG(s) - ISOLATED.

(step 3.7) Verify at least one SG MSIV and Critical task bypass valves on 1A SG closed

[]3369A or

[]3370A And

[]3368A or

[]3976A BOP (step 4) WHEN ruptured SG(s) NR level NOTE: [CA] step greater than 31% THEN perform the following:

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

- FCV 3227A in MOD, and 3227AA closed Critical task

- HV 3328A in MOD and 3228AA closed SRO (step 5) Check ruptured SG(s) pressure GREATER THAN 250 psig.

SRO (step 6) Perform RCS cooldown.

Determine required CETCs for cooldown based on ruptured SG pressure.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 34 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments SRO (step 6.2) IF the plant computer is available, This is normally selected by THEN display Highest Core Exit Temp Chan the STA and put on the control A and B on one of the following displays. board display.

1TC1 STA Other display

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 35 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes Time Pos. Expected Actions/Behavior Comments SRO Will direct these steps:

(step 6.3) WHEN P-12 light lit (543F),THEN perform the following.

(step 6.3.1) Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

[] A TRN to BLOCK

[] B TRN to BLOCK (step 6.3.2) Verify blocked indication.BYP &

PERMISSIVE STM LINE ISOL. SAFETY INJ.

[] TRAIN A BLOCKED light lit

[] TRAIN B BLOCKED light lit (step 6.3.3) Bypass the steam dump interlock.

STM DUMP INTERLOCK NOTE: Step 6.4 path depends

[] A TRN to BYP INTLK on condenser availability, both

[] B TRN to BYP INTLK are possible.

(step 6.4) IF condenser available, THEN Critical task dump steam to condenser from intact SGs at maximum attainable rate. RNO 6.4 Dump steam to atmosphere.

BYP & PERMISSIVE 6.4.1 Direct counting room to.

[] C-9 light lit perform FNP-0-CCP-645 6.4.2 Dump steam from intact STM DUMP SGs at maximum attainable

[] MODE SEL A-B TRN in STM PRESS rate.

1A(1B,1C) MS ATMOS STM DUMP INTERLOCK REL VLV

[] A TRN in ON

• PC 3371A adjusted

[] B TRN in ON

• PC 3371B adjusted

• PC 3371C adjusted STM HDR PRESS FNP-1-SOP-62.0, EMERGENCY

[] PK 464 adjusted RO (step 6.5) Check hottest CETCs less than Continue to step 7 until CETCs required temperature. are < required temp.

(step 6.6) Stop the cooldown Critical task (step 6.7) [CA] Maintain core exit T/Cs -

LESS THAN REQUIRED TEMPERATURE.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 36 of 44 Event

Description:

1A SGTR- 300 gpm over 5 min and stabilizes 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

[] A TRN reset

[] B TRN reset MDAFWP TO 1A/1B/1C SG B TRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted When cool down complete and at the discretion of the Lead Examiner, terminate the scenario.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 37 of 44 Event

Description:

Attachment 2 of EEP-0 Cue: BOP will accomplish when at step 5 of EEP-0 Attachment 2 of EEP-0 AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.

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

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

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.

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

[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS Operator should proceed to THAN step 4 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow - greater than 3

1.5 X10 gpm

[] 1A RHR HDR FLOW FI-605A

[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

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

[] B train (1D,1E or 1C)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 38 of 44 Event

Description:

Attachment 2 of EEP-0 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 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

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

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 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

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 39 of 44 Event

Description:

Attachment 2 of EEP-0 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

[] 1A

[] 1B B train

[] 1C

[] 1D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 40 of 44 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED. RNO 8.1 Verify MDAFW Verify both MDAFW Pumps - STARTED Pumps deliver flow to each

[] 1A MDAFW Pump amps > 0 SG.

[] 1B MDAFW Pump amps > 0 8.1.1 Manually start MDAFW AND Pumps

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm 8.1.2 Verify AFW flow path to

[] FI-3229C indicates > 0 gpm AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open (Step 8.2) Check TDAFW Pump start required.

Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 41 of 44 Event

Description:

Attachment 2 of EEP-0 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

[] 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

[] 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.

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 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 [] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 42 of 44 Event

Description:

Attachment 2 of EEP-0 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

[] N1C11E005A

[] N1C11E005B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] 1B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 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 accomplish pumps per FNP-0-SOP-0.0, APPENDIX B, this.

TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 43 of 44 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Seen Next Page Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 2 Event # 8 Page 44 of 44 Event

Description:

Attachment 4 of EEP-0 Time Pos. Expected Actions/Behavior Comments Attachment 4 of EEP-0 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 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

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify SFP Cooling in service per Will call Radside SO to SOP-54.0 accomplish this.

End of Attachment 4

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2013-301 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, call Unit 2 at 2434 or page the Unit 2 Unit Operator.

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 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]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 4% power, 1350 ppm, MOL 10000 MWD/MTU FRV Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - A Train Protected 1.0  ; 109.1 No adj. ; 63.7  ; FSP-20,0  ;

Status of Special Testing All MODE 1 STPs are complete. Permission to proceed to MODE 1 has been granted.

General Information

1. Shift Goal is to Raise power to 12% and prepare roll the Main Turbine to 1800 rpm

2. Current Risk Assessment is GREEN and projected is GREEN

3. Aux steam is being supplied from Unit 2

4. 1A SGFP is on service with FRV Bypass valves in AUTO

5. UOP-1.2 ver 103.1, is complete through step 5.62. Continue the startup starting at step 5.63.

6. Unit 2 is at 100% power with no major issues.

7.

8.

9.

Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status Control rods and steam dumps, as required. #3 RHT - On Service WGS - secured LCO Status 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 ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes

Scenario #3 FA2013301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #3 Validation time: 120 minutes Validated by McCaffery, Sorrell, Phillips The week of February 18, 2013 TRN Supervisor Approval: Gary Ohmstede Date: 3/8/2013 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario #3 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 29% power, 429 ppm, EOL; Ramping up, ramp on HOLD for chemistry.

Turnover:

• Unit 2 PSS is OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

• 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

• Fuel handling is ongoing in the SFP.

• Current Risk Assessment is YELLOW and projected is YELLOW,

• B Train On-Service - B Train Protected.

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

Imf I (RO) LT-115, VCT level controller, fails LOW 1 lt115 imf I (BOP) R-25A, SPENT FUEL POOL VENTILATION RAD MONITOR, mal-2 rms25a TS (SRO) fails HIGH and SFP ventilation does not secure, PRF starts

/ preset TS 3.3.8 condition A Imf I (RO) PT-444, PRZR PRESS CONTROL CHANNEL, fails high pt444/

preset TS (SRO) PORV-444B leaks by seat- requires block valve closure 3

T.S. 3.4.11 Condition A and TS 3.4.1 DNB Condition A (low pressure)

Imf C (BOP) 1A FRV Fails closed in Auto, will respond in manual control 4 fk478-a Imf R (RO) 1A SG tube leak - 15 gpm over 3 min and stabilizes. Ramp at 2 mal-5 rcs4a N(BOP) MW/min TS (SRO) TS 3.4.13 condition B Imf M (ALL) Running SGFP trips. RX trip required (Loss of Feed);

6 mal-fwm11a preset C (RO) Reactor Trip hand switches disabled, RX trip requires opening 7 CRDM MG set breakers.

C (BOP) Main Turbine will not trip in AUTO, manual trip required. (CT)

Imf M (ALL) 1A SGTR increases to 500 gpm when EEP-0 entered.

8 mal-rcs4a Imf M (ALL) 1A SG fault upstream of 1A MSIV in MSVR when 1A MSIV is mal-9 mss2a C (BOP) closed.

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 June 2013 exam Page 2 of 11

Appendix D Scenario 3 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-213 and sim IC snap directory Base IC is IC-47 RUN RUN simulator 0 0 Generic setup:

bat 36exam/generic_setup_HLT.txt Quick setup is in IC-213 0 0 Quick setup (all items with

• are included):

bat 36exam/2013nrcexam_3.txt PRESETS 2 HV-3990A hi rad

• imf csf3990a_cc1 closed 2 HV-3416 hi rad

• imf csff3416_d_cc1 closed 2 HV-3417A hi rad

• imf csf3417a_d_cc1 closed 3 PORV 444B sticks at 10% after being demanded closed: TRG 1 imf rrc444b-m (1 0) 10 1 7 Fail RTB from opening on manual or auto trip

• CMFmalf / cBKRXTRP_cc21/ closed CMFmalf / cBKRXTRP_cc22/ closed 7 Main Turbine will not trip Automatically

• imf mal-tur2 8 1A MSIVs will not close on auto closure

• CMFmalf / crsh001a_cc5 /open CMFmalf / cmsh002a_d_cc5 /open 0 Tag 1A MDAFW pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 / open irf cBK2DH07_d_cd1 / open irf cBK1DH07_d_cd2 / open irf cBK2DH07_d_cd2 / open Triggers and Commands 3 Event Trigger 1 - monitors PORV444B HS closed position

• trgset 1 x30i115c 9 Trigger 3 On 1A MSIV closure, Fault in MSVR

• trgset 3 "XSLBA01" trg 3 "imf mal-mss2a 1 300" Farley June 2013 exam Page 3 of 11

Appendix D Scenario 3 Simulator setup Form ES-D-1 MCB setup 1C DG MSS Place in Mode 3 Place HOLD Tag on 1C DG MSS 1 HOLD TAG Place HOLD Tag on 1C DG output breakers 2 HOLD TAGS DHO7-1 and DHO7-2 Place Unit 1 and Unit 2 Bypass and inoperable panel lights to Unit 1 A-Train the up position (EMERGENCY POWER SYSTEM) Unit 2 A Train Place Unit 1 Bypass and inoperable panel lights to the up Unit 1 A-Train position (Auxiliary Feedwater System)

Place HOLD Tag on 1A MDAFW pump H/S 1 HOLD TAG DEH Clear DEH alarms Select OPS 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 Cae clearrecorders.cae Provide a marked up copy of UOP-3.1 v112.4 completed UOP-3.1 copy thru step 5.3, Ready to perform step 5.4.

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 / 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 June 2013 exam Page 4 of 11

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 RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1 NRC CUE LT-115, VCT level controller, fails LOW imf lt115 0 20 2 NRC CUE R-25A, SPENT FUEL POOL VENTILATION RAD MONITOR, fails HIGH and SFP ventilation does not secure, PRF starts TS 3.3.8 condition A imf mal-rms25a 1000000 3 3 NRC CUE PT-444, PRZR PRESS CONTROL CHANNEL, fails high imf pt444 2500 45 PORV-444B leaks by seat- requires block valve closure TRG 1 T.S. 3.4.11 Condition A and TS 3.4.1 DNB Condition A (low pressure) 4 NRC CUE 1A FRV Fails closed in Auto, will respond in manual control imf fk478-a 0 25 5 NRC CUE 1A SG tube leak - 15 gpm over 3 min and stabilizes.

Ramp at 2 MW/min TS 3.4.13 condition B imf mal-rcs4a 15 300 6 NRC CUE Running SGFP trips. RX trip required (Loss of Feed);

imf mal-fwm11a Farley June 2013 exam Page 5 of 11

Appendix D Scenario 3 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 Reactor Trip hand switches disabled, RX trip requires securing Rod Drive MG set breakers.

Main Turbine will not trip in AUTO, manual trip required.

(CT) 8 1A SGTR increases to 500 gpm when EEP-0 entered.

Malf / R / mal-rcs4a / 500 / 60 9 TRG 3 1A SG fault upstream of 1A MSIV in MSVR when 1A MSIV is closed.

Imf mal-mss2a 1 50 Close ALL MSIVs and isolate AFW flow to the Faulted SG. (CT)

NRC CUE Terminate when ECP-3.1 is entered.

End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created.

exam2013sen3grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed Then Clear recorders for exam security Farley June 2013 exam Page 6 of 11

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 If asked, remove power from MOV-8000B FV-W4 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 3 minutes after Locally open reactor trip breakers requested CMFmalf / cBKRXTRP_cc21 / open CMFmalf / cBKRXTRP_cc22 / open 7 WHEN REQUESTED TBSO:

I have opened the condenser vacuum breaker isolation valves N1N51V518A and 518B.

REMOTE / N21 / LOA-CFW012 / 100 / 20 sec ramp 8 NONE REQUIRED 9 WHEN REQUESTED Fire alarm communications 1A - 106 is in alarm MSVR Use extremeview/cr fire panels to acknowledge TDAFW Pump isolation valve Close v017A irf loa-afw006 0 10 Farley June 2013 exam Page 7 of 11

Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

ALL AS REQUIRED SSS, SM and Dispatcher:

(Standard Repeat back failure, procedure entered, plant status, communications to CR in the cue and that type of communications.

inform supervision) 1 NONE EXPECTED 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.

IF requested, HP reports:

Rad Levels are normal R-25A is pegged HIGH 3 NONE EXPECTED 4 NONE EXPECTED 5 WHEN REQUESTED AOP-2.0 communications- HP and shift radiochemist, counting room, and SM will all be notified.

SSS/TBSO:

I will place SJAE filtration on service.

Radside SO:

I will secure SGBD.

6 NONE EXPECTED 7 3 MINUTES AFTER [BOOTH] OPEN the Rx trip bkrs using the buttons on REQUESTED LOCAL OPERATOR ACTIONS PAGE, Then report the following:

ROVER:

I have locally Opened Unit one Reactor Trip breakers 8 WHEN REQUESTED ANY CALL TO SHIFT RADIO CHEMIST:

I am doing dose assessment and CCP-645 Farley June 2013 exam Page 8 of 11

Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:

9 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 WHEN REQUESTED Unit 2 UO:

Fire alarm is ________

[Booth] look at Pyro Panel on simulator computer and report to control room 3 minutes after requested.

Farley June 2013 exam Page 9 of 11

Scenario 3 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 29% power, 1298 ppm, MOL; Ramping up, ramp on HOLD for chemistry.

Turnover:

• Unit 2 PSS is OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

• 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

• Fuel handling is ongoing in the SFP.

• Current Risk Assessment is YELLOW and projected is YELLOW,

• B Train On-Service - B Train Protected.

• Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-115, VCT level controller, fails low.

Verifiable actions: Auto makeup must be stopped. Manual make-up required for ramp in event 5.

Event 2 R-25A, SPENT FUEL POOL VENTILATION RAD MONITOR, FAILS HIGH - SFP ventilation does not secure, PRF starts. TS 3.3.8 Condition A Verifiable actions: Manual isolation of dampers is to ensure SFP area is isolated properly.

Event 3 PT-444 fails high. Crew enters AOP-100. TS. 3.4.11 Condition A and 3.4.1 Condition A Verifiable actions: Close PORV 444B. PORV 444B discovered to be leaking by (RCS pressure continues to decrease) and PORV block valve must be closed.

Event 4 1A FRV Fails closed in Auto Verifiable actions: Take manual control of A FRV and restore SGWL Event 5 1A SG Tube leak. 15 gpm over 3 minutes and stabilizes. TS 3.4.13 condition B Verifiable actions: 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 6 Running SGFP trips.

Verifiable actions: Trip Reactor and enter FRP-S.1 Event 7 Rx will not Trip in AUTO or manual. Main Turbine will not trip in AUTO, manual trip required.

Verifiable actions: Secure Rod Drive MG Sets, Manual trip of the Main Turbine (CT)

Event 8 1A SGTR 500 gpm when EEP-0 entered.

Event 9 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.

ARP/ AOP-100/ AOP-2.0/ AOP-13/ E-0/ESP-0.1/ E-3/ E-2/ E-3 / ECP-3.1 Farley June 2013 exam Page 10 of 11

Scenario 3 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET

1. Manually trip the main turbine [before a sever (orange-path) challenge develops to either the subcriticality or the integrity CSF] or [before transition to ECP-2.1]

whichever happens first: (WOG CT FR-E - Q)

Isolate faulted SG before transitioning out of E-2.

2.

(WOG CT E - A)

• Isolate AFW flow

• Isolate steam flow from 1A SG SCENARIO The team should be able to:

OBJECTIVE/

• Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-100, and AOP-2.0 and evaluate Tech Specs.

• Respond to a loss of SGFPs and then an ATWT event when the reactor will not trip.

• 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. This will cause a transition to ECP-3.1.

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

1. Total malfunctions (5-8) 10

2. Malfunctions after EOP entry (1-2) 4

3. Abnormal events (2-4) 5

4. Major transients (1-2) 3

5. EOPs entered/requiring substantive actions (1-2) 2

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Farley June 2013 exam Page 11 of 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 1 Page 1 of 43 Event

Description:

LT-115 fails LOW.

LT-115 will fail low. This will cause an auto make-up to occur that requires manual control of the make-up system.

Indications Available:

Annunciators: Recognize indications of LT-115 failing LOW

- VCT LVL HI-LO (DF3) - VCT level, increasing

- LT-115 indicator reading 0 Time Pos. Expected Actions/Behavior Comments ARP-1.4, Annunciator Response Procedure, DF3 Ver 53.0 SRO Directs RO to perform Actions of DF3 RO (Step 1) Determine if VCT level is high or low RO determines LI-115 is low, as indicated by LI-115 and LI-112B, VCT goes to step 9 LEVEL, on the MCB.

(step 9) IF LI-115 has failed low, THEN:

9.1 Manually makeup for VCT level control.

9.2 Take manual control of the make-up system.

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 next Event.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 2 Page 2 of 43 Event

Description:

R-25A fails HIGH 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 SFP room

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

Indications Available:

Annunciators: Indications:

- SFP AREA RE25 A OR B HI RAD (FH5)

• A TRN PRF starting Time Pos. Expected Actions/Behavior Comments Annunciator Response Procedure, ARP-1.6 FH5 Ver 70, SRO Direct entry into FH5. R-25A will be failed HIGH

• Determines the cause of the alarm. NOTE: SFP 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, SFP TO 1A PRF SUPPLY DMPR, is OPEN BOP (step 5 of ARP) Verify automatic actions have occurred.

o Trips the Fuel Handling Area Supply Not all automatic actions have and Exhaust Fans. occurred and SOP-58.0 will be o Closes the Fuel Handling Area referenced.

Supply and Exhaust Dampers.

o Starts the Penetration Room 1A OR SEE PAGE 4 FOR 1B Filtration Units. SOP-58.0 ACTIONS IF any automatic actions have not occurred, THEN go to FNP-1-SOP-58.0. (The section for Fuel Handling Area Heating and Ventilation Operation for guidance)

RO (step 6 and 7 of ARP) Announces receipt of Evacuate the SFP area if the the alarm and the evacuation of affected alarm is in high area.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 2 Page 3 of 43 Event

Description:

R-25A fails HIGH Time Pos. Expected Actions/Behavior Comments SS (step 8 of ARP) Call SM to evaluate 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 SRO (step 12 of ARP) IF high activity indication is due to instrument failure, THEN refer to Technical Specifications, section 3.3.8.

TECHNICAL SPECIFICATION 3.3.8, Penetration Room Filtration (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 assemblies in the SFP room.

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

inoperable.

SFP 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.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 2 Page 4 of 43 Event

Description:

R-25A fails HIGH Time Pos. Expected Actions/Behavior Comments SOP-58.0, Auxiliary Building Hvac System, ver 75.3 BOP (step 4.8.6.a) Verify open

• HV3538A SFP TO 1A PRF SUPPLY DMPR

• HV3538B,SFP TO 1B PRF SUPPLY DMPR (step 4.8.6.b) is not required to be done since a fuel handling accident is not in progress.

(step 4.8.6.c) Verify started

• 1A PRF RECIRC FAN M002A

• 1A PRF EXH FAN M001A (step 4.8.6.e) Secure SFP AHU as follows:

• Stop SFP AHU SUPP FAN M002.

• Stop 1A(1B) SFP EXH FAN M001A(B)

(step 4.8.6.f) Verify closed the following:

• SFP EXH FAN SUCT DMPR HV3990A

• SFP EXH FAN SUCT DMPR HV3990B

• SFP AHU DISCH TO SFP HV3991A

• SFP AHU DISCH TO SFP HV3991B Note: Examinee may elect to start B Train PRF early to prevent action above causing an auto start. This guidance can be found in multiple locations of the procedure.

• Start 1B PRF RECIRC FAN, Q1E15M002B

• Start 1B PRF EXH FAN, Q1E15M001B After Tech Spec analysis and at the discretion of the Lead Examiner move to next Event.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 3 Page 5 of 43 Event

Description:

PT-444, PRZR Press Control Channel, fails HIGH PT-444, PRZR Press control channel, fails HIGH. The PORV closes in manual, Przr pressure control will be in manual. Due to PORV seat leakage the block valve is required to be closed to stop RCS Pressure drop.

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) - PIs 455;456;457, RCS Press

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

- PRZR PRESS HI-LO (HC1)

• TI-465; TI-467; TI-469 Code Safety Tailpiece temps Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.1 ver 12 SRO Direct entry into AOP-100 RO (step 1) Take manual control of the Steps 1 and 2 are IOAs following equipment as necessary:

- PORV 444B, PRZR PORV.

- ALL Pzr heaters NOTE: Block valve required

- PK-444C & D, 1A& 1B LOOP SPRAY due to 444B seat leakage VLV (RCS pressure still falling)

- PK-444A, PRZR PRESS reference NOTE: HA5 ARP may be used Controller to isolate leaking PORV

- PRZR BLOCK VLV MOV8000B actions on PAGE 7 (step 2) IF pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D RO (step 3) If the PORV is open then close the PORV when RCS pressure is < 2310 psig.

RO (step 4) IF an alarm was caused by a 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.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 3 Page 6 of 43 Event

Description:

PT-444, PRZR Press Control Channel, fails HIGH Time Pos. Expected Actions/Behavior Comments SRO (step 5) Determine NO protection instrument failure occurred.

RO (step 6) References required Technical See T.S. required below Specifications :

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-1.2, Reactor Coolant Pressure Relief System, for cooldown of the PRT

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

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 COMPLETION TIME A. One or more RCS A.1 Restore RCS DNB parameters not DNB parameter(s) to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> within limits. within limit.

TECHNICAL SPECIFICATION 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and inoperable and capable maintain 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of being manually power to associated cycled. block valve.

When T.S. addressed and MOV-8000B closed and at the discretion of the Lead Examiner move to next Event .

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 3 Page 7 of 43 Event

Description:

PT-444, PRZR Press Control Channel, fails HIGH Time Pos. Expected Actions/Behavior Comments ARP-1.8, Annunciator Panel H HA5 ver 35.2 RO (step 5 of ARP)IF the alarm is determined to be caused by relief valve leakage, THEN isolate both relief valves by closing both PRZR PORV ISOs Q1B31MOV8000A

& B and determine the leaking valve as follows:

a) Allow relief line temperature to decrease sufficiently that temperature changes can be observed.

b) Open PRZR PORV ISO Q1B31MOV8000A and monitor the relief line temperature.

c) IF temperature does NOT increase, THEN no further action is necessary.

d) IF a temperature rise is observed, THEN close PRZR PORV ISO Q1B31MOV8000A and open PRZR PORV ISO Q1B31MOV8000B.

e) Verify that the relief line temperature decreases to ambient

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 4 Page 8 of 43 Event

Description:

1A FRV fails closed in AUTO. Controllable in MANUAL.

The 1A FRV AUTO controller fails to the closed position. The valve is able to be controlled in MANUAL.

Indications Available:

Annunciators: Indications:

- JB1 1A SG STM FLOW > FEED FLOW - 1A SGWL decreasing

- JF1 1A SG LVL DEV - 1A FRV demand position decreasing

- 1A SG Feed Flow decreasing Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.5 ver 12, (AOP-13, ver 33, 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) IF required, THEN take manual NOTE: Step 1 is an Immediate BOP control of the affected feedwater regulating Operator Action and a valves or bypass valves. continuing action step

[ ] 1A SG FW FLOW FK-478 IF a loss of main feedwater occurs, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER (step 2) If adverse trends in the SG level SRO exists then establish trip criteria If an automatic action is required or set NOTE: if the SGFP trips at points is approached: 82% level then the reactor Trip the reactor and go to EEP-0 would be tripped at this point.

BOP (step 3) There will not be a ramp in progress since the main turbine is not on line.

BOP (step 4) Determine if an instrument failure has occurred.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 4 Page 9 of 43 Event

Description:

1A FRV fails closed in AUTO. Controllable in MANUAL.

Time Pos. Expected Actions/Behavior Comments BOP (step 5) Refer to Tech Specs 3.3.1, 3.3.2 & None required 3.3.3 for any LCO requirements.

SRO (step 6) Notify the Shift Manager SRO (step 7) WHEN plant conditions permit, THEN return systems to automatic control.

SRO (step 8) Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator When 1A FRV is in manual and SGWL is under control and at the discretion of the Lead Examiner move to the next Event

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 10 of 43 Event

Description:

1A SG Tube Leak (15gpm) 1A SG tube leak will start and ramp in to 15 gpm over 3 minutes. Crew is required to place the Unit in Mode 3.

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 ARP-1.6, Annunciator response procedure, FG1 Ver. 70 SRO Direct ARP FG1 actions BOP (Step 1)Check N1D11RISH0070A, B, & C to R-70A will be increasing determine the magnitude of the leak and the generator indicating leakage.

BOP (step 3)Notify Chemistry of the alarm condition (step 5)Perform a qualitative confirmation for the existence of a SG tube leak by checking two independent radiation monitors R-70s/R-15, R-70s/R-23B, or R-15/R-23B trending in the same direction with the same order of magnitude.

• Consider placing SJAE Filtration System in service per FNP-1-SOP-28.5 SRO (step 6) IF this annunciator will not clear due to actual SG tube leakage OR an increase in existing tube leak is indicated, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR AOP-2.0 actions on page 12.

TUBE LEAKAGE.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 11 of 43 Event

Description:

1A SG Tube Leak (15gpm)

Time Pos. Expected Actions/Behavior Comments SRO (step 7) Refer to Technical Specifications T.S. Listed on PAGE16 section 3.4.13 for limiting conditions for operation.

ARP-1.6, Annunciator response procedure, FH1 Ver. 70 BOP Reference ARP FH1 (step 1) Check indications on radiation monitoring system console and determine which radiation monitor channel indicates high activity.

(step 2) Insure any auto actions have occurred.

BOP Check ARP FH1 for actions as Rad monitors come into alarm.

(step 3.3) Do not allow personnel to enter the affected area without the approval of the Health Physics Department.

(step 3.6) IF high activity indication of Steam Generator Tube Leakage is present, THEN go to FNP-1-AOP-2.0, STEAM GENERATOR TUBE LEAKAGE.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 12 of 43 Event

Description:

1A SG Tube Leak (15gpm)

Time Pos. Expected Actions/Behavior Comments SRO/ IF R-15 alarms AND remains above the BOP alarm setpoint (not a momentary spike),

THEN perform the following:

• IF high effluent activity is possible, THEN implement NMP-EP-110

• Notify the Counting Room to immediately sample the SGs per CCP-31 to determine the leak rate.

• Notify the Operations Shift Manager.

• IF an actual SG tube leak is confirmed, consider placing SJAE Filtration System in service per FNP-1-SOP-28.5.

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.

AOP-2.0, Steam Generator Tube Leakage Ver. 35 RO (step 1) Maintain pressurizer level stable at NOTE: [CA] step normal programmed value by: FK-122 adjusted as required

- Control charging close one or more orifice isol.

- Reduce letdown close HV-8149 A, B, C valves RO (step 1.3) Determine leak rate, if possible (use STP-9.0, RCS leakage)

(RNO step 1.3) Determine leak rate based on flow balance

___________(charging flow)

+___________(seal injection flow)

-___________(letdown flow)

-___________(#1 seal leakoff flow)

=___________(RCS leak rate)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 13 of 43 Event

Description:

1A SG Tube Leak (15gpm)

Time Pos. Expected Actions/Behavior Comments RO (step 2) Maintain VCT level greater than NOTE: [CA] step 20%. by: RNO is to trip the Rx and Verify RMW system in AUTO actuate an SI OR Manually control makeup as required by using SOP-2.3, CVCS Rx makeup system BOP (step 3) Check Unit in Mode 1 or Mode 2.

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: [CA] step leakage Check R-70s or R-15 for increasing count rate Chemistry will acknowledge Begin trending R-70A, SG TUBE LEAK, and CCP-31 app C R-15, SJAE EXH, using the plant computer and Data sheet 1.

BOP (step 6) Call TBSO to place SJAE filtration on service.

SRO (step 7) Direct chemistry to perform grab samples and leak rate determinations.

CCP-201 Table 55 (step 8) Notify SM of leak rate NOTE: [CA] step -

(step 9) Continue to monitor R-70s, R-15 or NOTE: [CA] step -

CHM/HP leak rate input for primary to secondary leak rate and rate of change using Data sheet 1.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 14 of 43 Event

Description:

1A SG Tube Leak (15gpm)

Time Pos. Expected Actions/Behavior Comments SRO (Step 10) Monitor the Continuous Radiation NOTE: [CA] step -

Monitoring System operation.

[ ] R OPERABLE OR

[ ] R-70s - OPERABLE SRO (step 11) Evaluate Table to determine appropriate response:

- ACTION LEVEL 3 Condition 1 30 gpd/hr rate of increase AND 75 gpd leak in any SG BOP (Step 12.1) 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-15/R-23A(B) trending in the same direction with the same order of magnitude SRO (step 12.2) Direct reducing power to 50% Unit is below 50% already rated thermal power within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> RO (step 12.3) Place the Unit in Mode 3 within Begin ramping offline BOP the next 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />.

SRO (step 12.4)Identify the correct leaking SG 1A SG has a 15 gpm tube Using R-70s, R-60s and level rise in any SG leak BOP (step 12.6) Have Chemistry convert R-15 readings to gpd within 15 minutes.

SRO (step 12.7) Call SM to evaluate emergency classifications per NMP-EP-110 and EIP 8.0 SRO (step 17) Direct Chemistry to monitor the turbine building sump for activity

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 15 of 43 Event

Description:

1A SG Tube Leak (15gpm)

Time Pos. Expected Actions/Behavior Comments SRO (step 18) Refer to FNP-0-AOP-2.1; Contingency Plan For Minimizing And Controlling Contaminated Secondary Condensate.

BOP (step 19) 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, B, C BOP (Step 20) Verify affected SG(s) atmospheric relief valve-ALIGNED

- 3371A 8.25 and in AUTO BOP (Step 21) Check affected SG atmospheric relief valve 3371A - CLOSED (Step 22) if TDAFWP is running or required TDAFWP not running or then direct the counting room to perform required CCP-645 (STEP 23) Check 1B or 1C SG(s) - Not affected AFFECTED.

BOP (Step 24) Verify SGBD isolated from the 1A SG- 7614A closed (Step 25) Check AS supplied from Unit 2 It is aligned from Unit 2 Tech specs on next page

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 5 Page 16 of 43 Event

Description:

1A SG Tube Leak (15gpm)

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 COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> Action and AND associated B.2 Be in MODE 5. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Completion Time of Condition A not met.

OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

When ramp of 5% completed and at the discretion of the Lead Examiner move to the next Event. Tech Spec evaluation if required by examiner may be delayed until after scenario termination.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 6 Page 17 of 43 Event

Description:

Only running Feed pump trips >5% power. Loss of BOTH SGFPs.

SGFP trips resulting in a loss of feed condition. At >5% this requires a Reactor Trip.

Indications Available:

Annunciators: Indications

- KC3 1A or 1B SGFP TRIPPED - SGFP Speed decreasing

- JF1/2/3 SG LVL DEV - SGWL decreasing Time Pos. Expected Actions/Behavior Comments AOP-13, Condensate and Feedwater Malfunction, ver 33 NOTE: All steps listed below are immediate operator actions.

SRO (step 1) Check only one SGFP running RNO Proceed to step 2 SRO (Step 2) Check Both SGFPs - TRIPPED RO (Step 2.1) Check Rx power less than 5% RNO Trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

See next page for EEP-0.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 18 of 43 Event

Description:

1A SGTR 500 gpm.

When the crew tries to trip the reactor, the reactor trip breakers will not open and RX trip requires securing Rod Drive MG sets. 1A SG will rupture upon entry of this procedure.

Indications Available:

Annunciators: Recognize indications of event

- Various and many

• RTBs still closed

• Nis indicate full power Enter EEP-0, Reactor Trip or Safety Injection, version 44 RO/ (step 1) Check reactor trip. IOA of EEP-0 BOP Check all reactor trip breakers and reactor RNO 1.1 Manually trip reactor.

trip bypass breakers - OPEN. 1.2 IF reactor can NOT be Check nuclear power - FALLING. tripped, THEN trip both MG set Check rod bottom lights - LIT. supply breakers.

• N1C11E005A

• N1C11E005B Critical task (step 2) Check turbine - TRIPPED.

RNO 2.1 Place main turbine TSLB2 14-1 thru 4 lit emergency trip switch to TRIP for at least 5 seconds.

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

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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 19 of 43 Event

Description:

1A SGTR 500 gpm.

RO/ (step 4) Check SI Status.

BOP (step 4.1) Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit (step 4.2) Verify both trains of SI-ACTUATED.

[] MLB-1 1-1 lit AND [] MLB-1 11-1 lit NOTE: IF crew has not recognized SGTR yet they may transition to ESP-0.1.

FOLDOUT PAGE criteria of ESP-0.1 to actuate SI and transition back EEP-0 is PZR level <4%.

If required, actions for ESP-0.1 are located on PAGE 32 SRO (step 5) Directs continuing into EEP-0 at step For Attachment 2 and 4

5. actions.

Directs the BOP to perform Go to page 35 attachment 2.

EEP-0 FOLD OUT PAGE CRITERIA IN EFFECT NOTE: [CA] step Ruptured SG AFW Isolation. The action to Isolate AFW to the ruptured SG may

• Manually stop AFW flow to a SG if BOTH be completed beyond this conditions listed below occur: point.

o Level increases in an uncontrolled manner or radiation in that SG is abnormal AND o Narrow range level - GREATER THAN 31% {48%}

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".

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 20 of 43 Event

Description:

1A SGTR 500 gpm.

RO (step 8) Check AFW status.

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

[] FI 3229A

[] FI 3229B

[] FI 3229C o Total Flow FI 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 NOTE: [CA] step -

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 MDAFWP TO 1A/1B/1C SG B TRN

[] 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

[] TI 432D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 21 of 43 Event

Description:

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 <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

[] 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

[] FI 3229A

[] FI 3229B

[] FI 3229C AFW TOTAL FLOW

[] FI 3229 IF MSIVs are closed THEN proceed to step 9.1.8 to break condenser vacuum BOP (step 9.1.5 RNO) IF MSIVs are open THEN isolate steam loads in the turbine building:

• MSRs reset (steps 9.1.5.1 and 9.1.5.2 RNO) these actions are performed by Systems Operators when RX trip is announced in step 7.

(9.1.5.3 is NA, it is already aligned)

BOP (step 9.1.5.4 RNO) IF two SJAEs in service, THEN secure one SJAE

• 1A SJAE o A Section ISO closed o B Section ISO closed

• 1B SJAE o A Section ISO closed o B Section ISO closed

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 22 of 43 Event

Description:

1A SGTR 500 gpm.

BOP (step 9.1.6 RNO) IF cool down continues THEN close main steam isolation and bypass valves.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B

[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SGMSIV - BYPASS

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 23 of 43 Event

Description:

1A SGTR 500 gpm.

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 PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 NOTE: [CA] step -

psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D 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

[] PI 402A

[] PI 403A

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 24 of 43 Event

Description:

1A 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.

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

SRO (step 14) Check SGs not ruptured RNO: Go T0 EEP-3.0

[] No SG level rising in an uncontrolled manner.

EEP-3.0, Steam Generator Tube Rupture, ver 27.0 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: [CA] step -

• Check any SG level - RISING IN AN UNCONTROLLED MANNER

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 25 of 43 Event

Description:

1A SGTR 500 gpm.

SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: [CA] step -

RO THEN isolate flow from ruptured SG(s).

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 1B or 1C SG is TDAFWP: N/A ruptured Verify blowdown from ruptured SG(s) - Closes 7614A ISOLATED.

(step 3.7) Verify at least one SG MSIV on 1A Verifies MSIV 3369A or 3370A SG closed closed and bypass valves closed NOTE: Step above triggers steam fault in 1A SG. FOLDOUT PAGE criteria will be met to transition to EEP-2.

No SG pressure falling in an uncontrolled manner or less than 50 psig. THEN go to EEP-2.

For EEP-2 actions Go To Page 26. Examine may transition to ECP-3.1 beyond this point, it is the intent of this scenario to Transition to EEP-2 for faulted SG isolation before termination. IF transition is made early, ECP-3.1 steps are located on Page 29. EEP-3 is continued on Page 28.

BOP (step 4) WHEN ruptured SG(s) NR level NOTE: [CA] step -

greater than 31% THEN perform the following:

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

• FCV 3227A in MOD

• HIC 3227AA closed

• HV 3328A in MOD

• HIC 3328AA closed

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 26 of 43 Event

Description:

Faulted SG Isolation 1A SG has a SGTR and is NOW faulted. Isolation will be accomplished in EEP-2.0 and transition back to EEP-3 will be made. Based on a ruptured, faulted SG transition to ECP-3.1 will be made.

Indications Available:

Annunciators: Recognize indications of SGTR with a fault:

- MH1 FIRE

• Przr level falling rapidly

- JB4 MS LINE HI STM FLOW ALERT

• RCS pressure dropping rapidly

• Steam Flow increasing Time Pos. Expected Actions/Behavior Comments EEP- 2.0, Faulted SG Isolation, version 15 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 ALL ARVs closed o 3371A/B/C

• Verify ALL Feed stop valves closed o 3232A/B/C

• Verify blowdown from all faulted SGs ISOLATED.

o 7614A/B/C BOP (step 4.6) Verify SG blowdown sample ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE ISO

• MLB1 19-2 lit Q1P15HV3328

• MLB1 19-3 lit Q1P15HV3329

• MLB1 19-4 lit Q1P15HV3330

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 27 of 43 Event

Description:

Faulted SG Isolation Time Pos. Expected Actions/Behavior Comments BOP (step 5.1) Isolate AFW flow to all faulted Critical task SGs.

Close MDAFWP isolation valves to all faulted SGs. (BOP)

• 3764A closed

• 3764E closed (Step 5.2) Close TDAFWP flow control Critical task valves to all faulted SGs. AFW isolated by either this TDAFWP FCV 3228 step or v017A called for.

• RESET

• 3228A in MOD

• 3228AA closed SRO (step 5.3) Locally close flow control inlet to faulted SGs.

• Q1N23V017A BOP (step 6) Check CST level greater than 5.3 feet.

• LI 4132A

• LI 4132B The intent of Step 7 is to transition to EEP-3 if a known SGTR exists. Since there is a Rx trip and SI at this point the secondary radiation monitors may not indicate a SGTR. However, the 1A SG has a Fault and a Tube rupture and should be identified and EEP-3 entered.

SRO (step 7.1) Direct Counting Room to sample per CCP-31.

(step 7.2) Check secondary radiation RNO: Go to EEP-3.0 next indication - NORMAL. page.

• R-15

• R-19

• R-23A and B

• R-15B and C,

• R-60 A, B, C, D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 28 of 43 Event

Description:

Faulted SG Isolation Time Pos. Expected Actions/Behavior Comments EEP-3.0, Steam Generator Tube Rupture, ver 27.0 Note: Crew may return to step 4 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: [CA] step -

• Check any SG level - RISING IN AN UNCONTROLLED MANNER SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: [CA] step -

RO THEN isolate flow from ruptured SG(s).

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 1B or 1C SG is TDAFWP: N/A ruptured Verify blowdown from ruptured SG(s) - Closes 7614A ISOLATED.

Verifies MSIV 3369A or (step 3.7) Verify at least one SG MSIV on 1A 3370A closed and bypass SG closed 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.

• FCV 3227A in MOD

• HIC 3227AA closed

• HV 3328A in MOD

• HIC 3328AA closed SRO (step 5) Check ruptured SG(s) pressure Go to ECP-3.1 transition at GREATER THAN 250 psig. this step When the 1A MSIVs and the AFW flow to the 1A SG is isolated, then terminate the exam.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 29 of 43 Event

Description:

ECP-3.1 Time Pos. Expected Actions/Behavior Comments ECP-3.1, SGTR with LOSS of Reactor Coolant SUBCOOLED RECOVERY Desired, ver 23.0 Note: If EEP-2 has not been performed, FOLDOUT page criteria directs entry to EEP-2 RO (step 1) Verify SI - RESET

• MLB-1 1-1 not lit (A TRN)

• MLB-1 11-1 not lit (B TRN)

RO (step 2) Verify PHASE A CTMT ISO - RESET

• MLB-2 1-1 not lit

• MLB-2 11-1 not lit RO (step 3) Check PHASE B CTMT ISO - RESET

• MLB-3 1-1 not lit

• MLB-3 6-1 not lit RO (step 4) IF instrument air available, THEN establish instrument air to containment.

(step 4.1) Verify at least one air compressor started.

AIR COMPRESSOR 1A / 1B / 1C (step 4.2) Check INST AIR PRESS PI 4004B greater than 85 psig.

(step 4.3) Check instrument air to containment.

IA TO CTMT

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

• Annunciator KD1 clear BOP (step 5)Verify 4160 V busses energized. [CA]

(step 5.1) Perform ATTACHMENT 1, VERIFYING Att 1 starting at 4160V BUSSES ENERGIZED.

PAGE 43 RO (step 6)Turn off all pressurizer heaters.

PRZR HTR GROUP VARIABLE 1C PRZR HTR GROUP BACKUP 1A 1B 1D 1E

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 30 of 43 Event

Description:

ECP-3.1 RO (step 7) Check containment spray system. [CA]

(step 7.1) Check any containment spray pump -

STARTED. CS PUMP 1A 1B (step 7.2) Reset containment spray signals.

CS RESET A TRN B TRN (step 7.3) WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />, AND containment pressure is less than 16 psig, THEN stop both CS PUMPs.

RO (step 8) Check ruptured SG(s) level. [CA]

(step 8.1) Check ruptured SG(s) narrow range level -

GREATER THAN 31%{48%}.

(step 8.2) Verify AFW flow to ruptured SG(s) -

ISOLATED.

RO (step 9) Check if LHSI Pumps should be stopped. [CA]

(step 9.1) RHR pumps - ANY RUNNING WITH SUCTION ALIGNED TO RWST.

(step 9.2) Check RCS pressure - GREATER THAN 275 psig{435 psig}.

1C(1A) LOOP RCS NR PRESS

[] PI 402B [] PI 403B (step 9.3) Check RCS pressure - STABLE OR RISING.

1C(1A) LOOP RCS NR PRESS

[] PI 402B [] PI 403B (step 9.4) Stop any RHR Pumps running with suction from the RWST.

RO (step 10) Begin evaluation of plant status.

(step 10.1) Begin taking ECCS logs.

(step 10.2) Check no intersystem LOCA outside CTMT.

and/or leakage.

(step 10.2.1) Check auxiliary building radiation -

NORMAL.

[] R-3 RADIOCHEMISTRY LAB

[] R-4 1C CHG PUMP RM

[] R-5 SFP RM

[] R-6 SAMPLE RM AREA

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 31 of 43 Event

Description:

ECP-3.1

[] R-8 DRUMMING STATION

[] R-10 PRF (step 10.2.2) Check auxiliary building room sumps - HI LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO. (BOP)

(step 10.2.3) Check WHT and FDT levels - NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

(step 10.3) Verify at least one train of PRF in operation using SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

(step 10.4) Close recirculation valve disconnects using ATTACHMENT 3.

(step 10.5) Evaluate RCS sampling requirements.

(step 10.5.1) Consult TSC staff to evaluate need for RCS sampling.

(step 10.5.2) IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-0-CCP-1300, CHEMISTRY AND ENVIRONMENTAL ACTIVITIES DURING A RADIOLOGICAL ACCIDENT.

(step 10.6) Establish 1A and 1B post LOCA - IN SERVICE USING ATTACHMENT 4, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

(step 10.7) Plot hydrogen concentration on FIGURE 1.

(step 10.8) Check containment hydrogen concentration

- LESS THAN 3.5%.

(step 10.9) Check containment hydrogen concentration

- LESS THAN 0.5%.

SRO (step 11)Check SGs not faulted. RNO 11.1 (step 11.1) Check no SG pressure - FALLING IN AN IF faulted SG NOT UNCONTROLLED MANNER OR LESS THAN 50 needed for RCS cooldown AND psig.

faulted SG NOT previously isolated, THEN go to EEP-2 Above is the last chance for the crew to diagnose a SG fault.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 32 of 43 Event

Description:

ESP-0.1 Actions ESP-0.1, Reactor Trip or Safety Injection, rev 32 FOLDOUT PAGE criteria of ESP-0.1 to actuate SI and transition back EEP-0 is PZR level <4%.

When SI is actuated return to page PAGE 18 RO (step 1) Check RCS temperature

• IF any RCP running, THEN check RCS average temperature -

STABLE AT OR APPROACHING 547 F BOP (step 1.1.1 RNO) Verify steam dumps closed

• STM Dump Interlock A and B Train to OFF RESET BOP (step 1.1.2 RNO Verify atmospheric reliefs closed. MS ATMOS REL VLV

• PC 3371A

• PC 3371B

• PC 3371C BOP (step 1.1.3 RNO) IF MSIVs are open THEN NOTE: steps in 1.3.1 RNO isolate steam loads in the turbine building other than listed actions are while continuing with RNO step 1.1.4. dispatched outside of the

• Resets MSRs control room BOP (step 1.1.3.4 RNO) IF two SJAEs in service, THEN secure one SJAE

• 1A SJAE o A Section ISO closed o B Section ISO closed

• 1B SJAE o A Section ISO closed o B Section ISO closed BOP (step 1.1.3.5 RNO) Verify SG blowdown -

ISOLATED 1A(1B,1C) SGBD

• Q1G24HV7614A closed

• Q1G24HV7614B closed

• Q1G24HV7614C closed

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 33 of 43 Event

Description:

ESP-0.1 Actions BOP (step 1.1.4 RNO) IF cooldown continues, THEN minimize total AFW flow. NOTE: This may have been AFW FLOW to 1A(1B,1C) SG already directed to be

• FI 3229A controlled via operator aid

• FI 3229B posted on MCB

• FI 3229C AFW TOTAL FLOW

• FI 3229 o Control TDAFWP FCV 3228 Reset SIC 3405 adjusted BOP (step 1.1.5 RNO) IF cooldown continues THEN close main steam isolation and bypass valves.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B

[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYPASS

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 34 of 43 Event

Description:

ESP-0.1 Actions (step 2) When RCS average temperature less than 554F THEN verify feedwater status (step 2.1) Verify main feedwater flow control and bypass valves- CLOSED 1A(1B,1C) SG FW FLOW

• FCV 478

• FCV 488

• FCV 498 1A(1B,1C) SG FW BYP FLOW

• FCV 479

• FCV 489

• FCV 499 (step 2.2) Defeat MDAFWP auto start on SGFP trip.

• 1A in DEFEAT

• 1B in DEFEAT (step 2.3) Verify both steam generator feed pumps - TRIPPED

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 35 of 43 Event

Description:

Attachment 2 of EEP-0 Cue: BOP will accomplish when at step 5 of EEP-0 Attachment 2 of EEP-0 AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.

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

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

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.

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

[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS Operator should proceed to THAN step 4 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow - greater than 3

1.5 X10 gpm

[] 1A RHR HDR FLOW FI-605A

[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

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

[] B train (1D,1E or 1C)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 36 of 43 Event

Description:

Attachment 2 of EEP-0 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 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

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

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 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

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 37 of 43 Event

Description:

Attachment 2 of EEP-0 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

[] 1A

[] 1B B train

[] 1C

[] 1D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 38 of 43 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED. RNO 8.1 Verify MDAFW Verify both MDAFW Pumps - STARTED Pumps deliver flow to each

[] 1A MDAFW Pump amps > 0 SG.

[] 1B MDAFW Pump amps > 0 8.1.1 Manually start MDAFW AND Pumps

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm 8.1.2 Verify AFW flow path to

[] FI-3229C indicates > 0 gpm AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open (Step 8.2) Check TDAFW Pump start required.

Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 39 of 43 Event

Description:

Attachment 2 of EEP-0 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

[] 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

[] 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.

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 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 [] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 40 of 43 Event

Description:

Attachment 2 of EEP-0 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

[] N1C11E005A

[] N1C11E005B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] 1B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B If NO condensate pumps are started then place all HSs to STOP (step 14.3) IF condensate pump operating, Will call TBSO to THEN verify backup cooling aligned to accomplish this.

condensate pumps per FNP-0-SOP-0.0, APPENDIX B, TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 41 of 43 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Seen Next Page Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 8 Page 42 of 43 Event

Description:

Attachment 4 of EEP-0 Time Pos. Expected Actions/Behavior Comments Attachment 4 of EEP-0 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verify DG02 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

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 3 Event # 9 Page 43 of 43 Event

Description:

Attachment 1 of ECP-3.1 Time Pos. Expected Actions/Behavior Comments Attachment 1 of ECP-3.1 Verify 4160V Busses Energized BOP (step 1.1) Check offsite power -

AVAILABLE.

(step 1.2) Check BKR DF01 (1A startup transformer to 1F 4160 V bus) - CLOSED.

(step 1.3) Verify BKR DF02 (1F 4160 V bus tie to 1K 4160 V bus) - CLOSED.

(step 1.4) Check BKR DG15 (1B startup transformer to 1G 4160 V bus) - CLOSED.

(step 1.5) Verify BKR DG02 (1G 4160 V bus tie to 1L 4160 V bus) - CLOSED.

(step 1.6) Verify all RCP busses -

ENERGIZED.

[] 1A 4160 V bus

[] 1B 4160 V bus

[] 1C 4160 V bus (step 1.7) Check 1E 4160 V bus -

ENERGIZED.

(step 1.8) Check 1D 4160 V bus -

ENERGIZED.

(step 1.9) IF 1D 4160 V bus energized, THEN proceed to step PROCEDURE STEPS, step 6.

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2013-301 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, call Unit 2 at 2434 or page the Unit 2 Unit Operator.

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 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]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 29% power, 429 ppm, EOL 16000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely B Train On-Service - B Train STP-27.1 completed 2 Protected hours ago 1.0  ; 109.1 No adj. ; 63.7  ; FSP-20,0  ;

Status of Special Testing General Information

1. Shift Goal is to Maintain 29% power and complete chemistry hold (2 more hours), then ramp to 100% power

2. Current Risk Assessment is YELLOW and projected is YELLOW due to maintenance on 1A MDAFW pump and 1C DG

3. UOP-3.1 ver 112.4, is complete through step 5.3.

4. 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

5. 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

6. Fuel handling in ongoing in the SFP.

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

8. Unit 2 PSS is OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

9. Unit 2 is at 100% power with no major issues.

Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status Diluting 25 gallons every 15 minutes to maintain #3 RHT - On Service current conditions WGS - secured LCO Status 3.8.1 Condition B for 1C DG, STP-27.1 completed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago 3.7.5 Condition B for 1A MDAFW Pump 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 ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes

Scenario #5 FA2013301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-36 NRC EXAM SCENARIO #5 Validation time: 90 minutes Validated by McCaffery, Sorrell, Phillips The week of February 18, 2013 TRN Supervisor Approval: Gary Ohmstede Date: 3-12-2013 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 75% power, 1177 ppm, MOL, Ramping up Turnover:

• Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

• 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

• Current Risk Assessment is YELLOW and projected is YELLOW,

• A Train On-Service - B Train Protected.

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

1 Imf I (RO) LT-460, Pressurizer level, fails LOW, letdown secures lt460 TS (SRO) TS 3.3.1 Condition M 2 N (BOP) Restore Letdown 3 Imf I (BOP) FT-495, selected steam Flow Transmitter for 1C SG fails HIGH ft495 TS (SRO) Tech Spec 3.3.2 Condition D Function 4e 4 Imf C (RO) PK-444D, 1B RCP Spray valve, will open and can be closed in pk444d-a manual.

TS (SRO) TS 3.4.1 (RCS pressure) 5 Imf C (BOP) 1B Condensate Pump develops Degraded Head, Stby (1A ncfcn1b

-d % / cond) pump will not auto start.

preset 6 R (RO) Loss of 500KV line, SM directs 200 MW load reduction in 25 N (BOP) minutes 7 Imf M (ALL) 1C Condensate pump trips leading to BOTH SGFPs tripping cCfcn1c

_cc5 8 C (RO) Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered and begin driving rods in. (CT)

C (BOP) Main Turbine will not trip automatically or in manual. Main Turbine GVs fast action closed. (CT) 9 Imf mal- M (ALL) LBLOCA when ESP-0.1 entered or step 5 of EEP-0.

rcs2b 10 C (BOP) A Train SI will not auto actuate.

1B RHR pump will not auto start and MOV-8803B will not open.

Required to establish one train of HHSI or LHSI flow. (CT)

Terminate in EEP-1.0 when transition to ESP-1.3 announced.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 2 of 12

Appendix D Scenario 5 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-215 Base IC is IC-56 RUN RUN simulator 0 0 Generic setup:

bat 36exam/generic_setup_HLT.txt 0 0 Quick setup (all items with

• are included):

bat 36exam/2012nrcexam_5.txt PRESETS 8 1a crdm set fails to trip:

• CMFmalf / c52MGA_cr3 8 RTBs fail to open

• CMFmalf / cBKRXTRP_cc21 / closed CMFmalf / cbkrxtrp_cc22 closed 8 Prevent AUTO trip of main turbine

• MALF / T / MAL-TUR2 8 Prevent Manual trip of main turbine

• MALF / T / MAL-TUR24 10 Train A auto SI failure

• imf csftyinj_cc1 open 10 MOV-8803B does not open on SI

• imf csi8803b_d_cc5 open 10 1B RHR pump fails to auto start on SI

• imf crhp01b_d_cc9 open 5 Block 1A Cond pump from auto start

• imf ccfcn1a_cc8 open imf ccfcn1a_cc9 open imf ccfcn1a_cc10 open 0 Tag 1A MDAFW pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 / open irf cBK2DH07_d_cd1 / open Farley June 2013 exam Page 3 of 12

Appendix D Scenario 5 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS irf cBK1DH07_d_cd2 / open irf cBK2DH07_d_cd2 / open 5 1B Condensate pump degraded head setup

• Imf jcfwfpll-s 250 Imf jcfwfplo-s 325 7 1A Condensate pump trips 5 seconds after 1C TRG 1 Imf cCFCN1a_cc5 (1 5) closed Triggers and Commands 7 When 1C condensate pump trips 1B condensate pump degrades to no flow Trgset 1 x22o061m Trg 1 imf ncfcn1b-d_th 100 60 Farley June 2013 exam Page 4 of 12

Appendix D Scenario 5 Simulator setup Form ES-D-1 MCB setup 1C DG MSS Place in Mode 3 Place HOLD Tag on 1C DG MSS 1 HOLD TAG Place HOLD Tag on 1C DG DG output breakers DHO7-1 and 2 HOLD TAGS DHO7-2 Place Unit 1 and Unit 2 Bypass and inoperable panel lights to Unit 1 A-Train the up position (EMERGENCY POWER SYSTEM) Unit 2 A Train Place Unit 1 Bypass and inoperable panel lights to the up Unit 1 A-Train position (Auxiliary Feedwater System)

Place HOLD Tag on 1A MDAFW pump H/S 1 HOLD TAG 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 Cae clearrecorders.cae Provide a marked up copy of UOP-3.1 version 112.4 UOP-3.1 copy through step 5.19 complete.

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 / 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 June 2013 exam Page 5 of 12

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 RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1

NRC LT-460, pressurizer level, fails LOW, letdown secures CUE TS 3.3.1 Condition M imf lt460 0 20 2 Restore Letdown 3

NRC FT-495, selected steam Flow Transmitter for 1C SG fails CUE HIGH TS 3.3.2 Condition D imf ft495 575 20 4

NRC PK-444D, 1B RCP Spray valve, will open and can be CUE closed in manual. TS 3.4.1 (RCS pressure) imf pk444d-a 10 20 5

NRC 1B Condensate Pump develops Degraded Head, Stby CUE (1A cond) pump will not auto start.

imf ncfcn1b-d_th 40 180 6

NRC Loss of 500KV line, SM directs 200 MW load reduction in Communication required CUE 25 minutes. see Coms sheet.

7 After 5% 1C Condensate pump trips leading to BOTH SGFPs pwr tripping reduction imf ccfcn1c_cc5 closed 1B Condensate pump completely degrades TRG 1 8 Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered and begin driving rods in. (CT)

Farley June 2013 exam Page 6 of 12

Appendix D Scenario 5 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Main Turbine will not trip automatically or in manual.

Main Turbine GVs fast action closed. (CT) 9 LBLOCA when ESP-0.1 entered or step 5 of EEP-0.

imf mal-rcs2b 10 A Train SI will not auto actuate.

1B RHR pump will not auto start and MOV-8803B will not open.

Required to establish one train of HHSI or LHSI flow.

(CT)

Terminate in EEP-1.0 when transition to ESP-1.3 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 Ensure data file created.

exam2013sen5grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed Then Clear recorders for exam security Cae clearrecorders.cae Farley June 2013 exam Page 7 of 12

Appendix D Scenario 5 Local Operator Action sheet Form ES-D-1 EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE EXPECTED 3 NONE EXPECTED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 3 minutes Locally open reactor trip breakers after requested CMFmalf / cBKRXTRP_cc21 / open CMFmalf / cBKRXTRP_cc22 / open 9 WHEN Unit Two UO; RESET FIRE ALARM MH1 REQUESTED Imf MH1 failoff 9 WHEN SSS / RADSIDE:

REQUESTED 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 Farley June 2013 exam Page 8 of 12

Appendix D Scenario 5 Communications sheet Form ES-D-1 EVENT TIME Communication:

NO.

ALL AS SSS, SM and Dispatcher:

REQUIRED Repeat back failure, procedure entered, plant status, CR in the cue and that type (Standard of communications.

communicatio ns to inform supervision) 1 WHEN Work Week Coordinator:

REQUESTED 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 <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

2 NONE EXPECTED 3 WHEN Work Week Coordinator:

REQUESTED Ill get I&C to place bistables in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

SM:

You have permission to return FK-498 to Auto 4 NONE EXPECTED 5 WHEN TBSO:

REQUESTED Walked down condensate pumps and found no obvious problems 6 Event SM:

initiation ACC informed me we just lost the Raccoon Creek 500kV line. Based on UOP-3.1 Appendix 5 Unit 1 is required to reduce load by 200 MW in the next 27 minutes IF asked about Unit 2 reducing load then respond with:

SM:

Unit 2 is unable to reduce load at this time.

7 NONE EXPECTED 8 NONE EXPECTED Farley June 2013 exam Page 9 of 12

Appendix D Scenario 5 Communications sheet Form ES-D-1 EVENT TIME Communication:

NO.

9 WHEN SM:

REQUESTED I will make the classifications and notifications.

SM / SSS:

I will get someone to perform step 6 of EEP-1.

I will get an extra operator to secure the 1B DG ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

Extra Operator:

The fire alarm is 1A-22 and I have acknowledged it on the fire alarm panel.

Farley June 2013 exam Page 10 of 12

Scenario 5 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 75% power, 1177 ppm, MOL, Ramping up Turnover:

• Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

• 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

• Current Risk Assessment is YELLOW and projected is YELLOW,

• A Train On-Service - B Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 LT-460 fails LOW, letdown secures. TS 3.3.1 Condition M Verifiable actions: RO must take manual control of Charging to maintain pressurizer level less than tech spec (63.5%).

Event 2 Restore Letdown Verifiable actions: BOP will restore letdown to service by operating several valves.

Event 3 FT-495, selected steam Flow transmitter for 1C SG fails HIGH. Tech Spec 3.3.2 Condition D Function 4e Verifiable actions: Take manual control of the 1C FRV and then select channel III instruments to control 1C SG functions.

Event 4 PK-444D, 1B RCP Spray valve, will open and can be closed in manual. TS 3.4.1 (RCS pressure)

Verifiable actions: Place the 1B RCP spray controller in manual and control RCS pressure using heaters and sprays before a Rx trip is required.

Event 5 1B Condensate Pump develops Degraded Head, Stby (1A cond) pump will not auto start.

Verifiable actions: start the standby Condensate pump before BOTH SGFPs trip Event 6 Loss of 500KV line, SM directs 200 MW load reduction in 25 minutes Verifiable actions: RO uses boration and/or rods, BOP operates DEH to set in ramp rate, target, initiate and stop ramp as necessary.

Event 7 Condensate pumps trip leading to BOTH SGFPs tripping, FRP-S.1 entry required.

Verifiable actions: Insert rods in manual or auto (RO) (CT)

Event 8 The Main Turbine will not trip in auto or manual, so the team will close governor valves to trip the Main Turbine (BOP) and then emergency borate (RO or BOP) (CT)

Event 9 LB LOCA when ESP-0.1 entered or step 5 of EEP-0.

Event 10 A Train SI will not auto actuate (*CT) 1B RHR pump will not auto start and MOV-8803B will not open. (*CT)

Terminate in EEP-1.0 when transition to ESP-1.3 announced.

AOP-100 / AOP-100 / AOP-100 / ARP-1.10 / AOP-17.1/ AOP-13/ FRP-S.1/ EEP-0/

EEP-1.0 Farley June 2013 exam Page 11 of 12

Appendix D Scenario 5 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 in service > 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

3. Manually start at least one low head ECCS pump before transition out of E-0.

(WOG CT E - H)

• The 1B LHSI does not start and the 1A LHSI pump did not start due to the SI signal not actuating.

OR Establish flow from at least one High Head ECCS pump before transition out of E-0. (WOG CT E - I)

• MOV-8803B does not open and due to the SI signal not actuating there will be no flow to the core.

• This is marked as one Critical task since flow to the core is the critical task. Actuating the SI signal will accomplish both tasks above or opening MOV-8803B and starting the 1B LHSI pump will accomplish the task.

SCENARIO Normal plant operation, fast ramp, 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 AOP-100, AOP-17.1, and AOP-13.

• recognize the symptoms of an ATWT and implement the steps of FRP-S.1, EEP-0.0 and the recognize the LB LOCA and implement transition to EEP-1.0 Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (5-8) 10

2. Malfunctions after EOP entry (1-2) 5

3. Abnormal events (2-4) 5

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 1

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 3 Farley June 2013 exam Page 12 of 12

Op Test No.: FA2013301 Scenario # 5 Event # 1 and 2 Page 1 of 48 Event

Description:

LT-460 Fails LOW, Letdown secures automatically LT-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/II position. This will cause letdown to secure and AOP-100 actions to be taken. Letdown will be placed back in service using AOP-100.

Indications Available:

Annunciators: Indications of LT-460 failing LOW

- PRZR LVL LO HTRS OFF LTDN SEC - LI-460 failing low (HA3) - Backup Heater Breakers open

- PRZR LVL DEV LO (HB2) - PI-145 Ltdn HX outlet pressure

- PRZR HTR CONT TRBL (HD4) - LI-459A and 461

- FI-122 charging flow

- FK-122 demand

- FI-150 letdown flow goes to 0 gpm

- LCV-460 goes closed

- LI-112B & LI 115 VCT Level Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.2 Ver 12, SRO Direct BOP to reference ARPs BOP Performs actions of ARPs (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-100.

HB2 (step 1) Place the Turbine on hold SRO SRO will direct entry to AOP-100.

RO Determines and reports LT-460 failure to SRO RO (step 1) Checks pressurizer level on or RNO: manual control of trending to program value. (PRZR level charging flow taken increasing) FK-122, CHG FLOW CONTROLLER, in manual and charging flow reduced

Op Test No.: FA2013301 Scenario # 5 Event # 1 and 2 Page 2 of 48 Event

Description:

LT-460 Fails LOW, Letdown secures automatically Time Pos. Expected Actions/Behavior Comments RO (Step 2) Check RCP seal injection flows

- Adjusts SI flow to 6-13 gpm by using HIK-186, SEAL WTR INJECTION CONTROLLER.

SRO/ (step 3) Determine if a PRZR level Determines LI-460 failed low RO transmitter / indicator loop has failed.

LI-459, LI-460, or LI-461 SRO/ (Step 3) IF selected PRZR level control RO channel failed THEN select an unaffected channel.

Controlling channel I / II is affected

- RO directed to select channel I / III on LS-459Z, PRZR LEVEL CONTROL CHANNEL SWICH IF required THEN select an unaffected Channel 459 selected no channel on the PRZR level recorder control action required switch LS/459Y, PRZR LEVEL RECORDER INPUTS SWITCH SRO/ (step 4) Check letdown in service RO - Orifice isolation valves one or more open HV-8149A,B,C, LTDN ORIF ISO VLVS

- Flow indicated on FI-150, LTDN HX Letdown NOT in service OUTLET FLOW.

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.

IF necessary THEN open LTDN LINE PENE Action not required RM ISOs HV-8175A and B from PRIP.

Op Test No.: FA2013301 Scenario # 5 Event # 1 and 2 Page 3 of 48 Event

Description:

LT-460 Fails LOW, Letdown secures automatically Time Pos. Expected Actions/Behavior Comments RO (step 4 RNO)

- Verify open LTDN LINE CTMT ISO HV-8152

- Verify open both LTDN LINE ISO LCV- Will open LCV-460 459 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 ORIF ISO 60 GPM HV-8149B or C to establish approx. 60 gpm letdown flow NOTE: Crew may use posted procedure guidance to restore a 45 gpm orifice at this point.

PLACING SECOND LTDN ORIFICE ON SERVICE DURING TRANSIENT CONDITIONS

1. Place FK-122 in MANUAL and adjust to greater than 80 gpm.

2. Place PK-145 in MANUAL and adjust to less than or equal to 50%.

3. Open LTDN ORIF ISO 45 GPM, Q1E21HV8149A.

4. Establish desired LTDN pressure and return PK-145 to AUTO. (260-450 psig)

5. Restore FK-122 to AUTO when desired.

6. Refer To SOP-2.1 when time permits.

RO (step 5) Check letdown flow established:

- Check letdown flow indicated FI-150

- 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 Admin LCO for 3.3.3

Op Test No.: FA2013301 Scenario # 5 Event # 1 and 2 Page 4 of 48 Event

Description:

LT-460 Fails LOW, Letdown secures automatically 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 required 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for surveillance testing of other channels.

M.1 Place channel in trip. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR M.2 Reduce THERMAL 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br /> 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, CVCS Startup and Operation, section 4.7.2 version 131, RO (step 4.7.2)

- Place LK-459F, PZR LVL Controller, in manual

- Verify Pzr level is w/I 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 FI-122A

- Place LK-459F in AUTO

- Place FK-122 in AUTO

Op Test No.: FA2013301 Scenario # 5 Event # 1 and 2 Page 5 of 48 Event

Description:

LT-460 Fails LOW, Letdown secures automatically Time Pos. Expected Actions/Behavior Comments Continue AOP-100 actions here RO (step 8) Restore control of pressurizer heaters:

- 1A PRZR HTR GROUP BACKUP

- 1B 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.

When Tech Specs have been evaluated and letdown is in service, then at the discretion of the Lead Examiner move to Event 3.

Op Test No.: FA2013301 Scenario # 5 Event # 3 Page 6 of 48 Event

Description:

FT-495 Fails HIGH FT-495, selected steam flow transmitter for 1C 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

- MS Line HI Stm Flow Alert (JB4) - TSLB 4 18-4 LIT

- 1C SG LVL DEV (JF3) - 1C FRV FK-498 Demand

- FI-497 & 496 Feed Flow 1C SG

- 1C SG level LI-494, 495, 496

- A & B SG level

- SGFP speed

- SGFP suction pressure Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.5 Ver 12 BOP Announces Receipt of MCB Alarms May notice FI-495, steam flow transmitter for 1C SG, Failed High and inform SRO.

SRO Instructs BOP/RO to perform Immediate Operator Actions of AOP-100 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%1.1

• 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 1.2

[ ] 1A SG FW FLOW FK-478

[ ] 1B SG FW FLOW FK-488

[ ] 1C SG FW FLOW FK-498

Op Test No.: FA2013301 Scenario # 5 Event # 3 Page 7 of 48 Event

Description:

FT-495 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 CH III CH IV CH III CH IV A S/G FI-474 FI-475 FI-477 FI-476 B S/G FI-484 FI-485 FI-487 FI-486 C S/G FI-494 FI-495 FI-497 FI-496 Check for failed or erroneous readings on the following SG pressure indicators S/G CH II CH III CH IV A S/G PI-474 PI-475 PI-476 B S/G PI-484 PI-485 PI-486 C S/G PI-494 PI-495 PI-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 FS/498Z and FS/498Y for BOP will verify proper system 1C SG in the III position: FT-494 (STM Flow) response

& FT-497 (FEED Flow)

Op Test No.: FA2013301 Scenario # 5 Event # 3 Page 8 of 48 Event

Description:

FT-495 Fails HIGH Time Pos. Expected Actions/Behavior Comments SRO (step 5) Refer to Tech Specs 3.3.1, 3.3.2, and 3.3.3 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 4e - High steam flow in two steam lines coincident w/ lo-lo 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 <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 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.

When Tech Specs have been evaluated, then at the discretion of the Lead Examiner move to Event 4.

Op Test No.: FA2013301 Scenario # 5 Event # 4 Page 9 of 48 Event

Description:

PK-444D, 1B RCP Spray valve controller, fails high. 1B RCP spray valve will open, able to be controlled in manual.

PK-444D will open and can be closed in manual. 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 HTRS ON (HD1) - Pzr pressure

- PRZR HTR BKR TRIPPED (HD5) - Amber light above 1A Pzr Htr control Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.1 Ver 12 SRO (step 1) Direct entry into AOP-100 Perform the IOAs of AOP-100 for RCS pressure.

BOP (step 1) Take manual control of PK-444D, 1B NOTE: Step 1 and 2 is an LOOP SPRAY VLV, 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, 1B LOOP SPRAY VLV,can be closed from the controller RO (step 3) IF PORV is open and pressurizer pressure is less than 2310 psig, THEN close the PORV.

RO (step 4) Take manual control of Sprays, Heaters, PORVs and PORV isolation valves, as necessary SRO (step 5) IF a PROTECTION instrument failure has occurred, THEN determine which pressure channel has caused the alarm.

Op Test No.: FA2013301 Scenario # 5 Event # 4 Page 10 of 48 Event

Description:

PK-444D, 1B RCP Spray valve controller, fails high. 1B RCP spray valve will open, able to be controlled in manual.

Time Pos. Expected Actions/Behavior Comments SRO (step 6) Refer to Tech Specs for LCO requirements that exist.

• Sections 3.3.1, 3.3.2, & 3.3.3 for instrument failures

• Section 3.4.1 for DNB limits

• Section 3.4.5 RCS Loops - Mode 3

• Section 3.4.11 PORVs 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 COMPLETIO N TIME A. One or more A.1 Restore RCS DNB 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> RCS DNB parameter(s) to within parameters not limit.

within limits.

SRO (step 7) Notify Shift Manager SRO (step 8) WHEN plant conditions permit, THEN restore components to automatic control.

SRO (step 9) Submit a Condition Report and notify the Work Week Coordinator SRO (step 11) Go to procedure and step in effect.

When Tech Specs have been evaluated (if required) and the plant is under control and at the discretion of the Lead Examiner move to Event 5 NOTE: Next event takes 3-5 minutes to build in

Op Test No.: FA2013301 Scenario # 5 Event # 5 Page 11 of 48 Event

Description:

1B Condensate pump degraded head. Leads to SGFP low suction pressure.

1B Condensate pump head degrades. STBY Condensate pump will not start. Operator must recognize degrading feed pump suction pressure and start the STBY condensate pump per ARP guidance. This event takes 3-5 minutes to build in. First alarm is SGFP Suction Pressure Low.

Indications Available:

Annunciators: Recognize indications of

- KB4 SGFP SUCT PRESS LO - SGFP suction pressure decreasing

- JF1,2,3 SG LVL DEV Time Pos. Expected Actions/Behavior Comments NOTE: Crew may enter AOP-13, which is on the Next Page.

ARP-1.10, Main Control Board Ann Panel K, KB4 ver 70.2 BOP (step 1) WHEN low pressure alarm comes in, THEN observe suction pressure on MCB recorder PR-4039 or plant computer.

BOP (step 2) IF a malfunction of SGWLC has raised SGFP speed, THEN take manual control of appropriate SGFP speed controller and adjust, as required BOP (step 3) IF a feedwater heater malfunction is indicated, THEN go to FNP-1-AOP-13.0, CONDENSATE AND FEEDWATER MALFUNCTION BOP (step 4) IF pressure continues to decrease below 300 PSIG, THEN verify both heater drain pumps are running.

BOP (step 5) IF a heater drain pump has tripped, THEN perform the following:

BOP (step 6) IF a heater drain pump has not tripped, THEN check the power supply breakers in the L & N Racks AND reset if necessary

Op Test No.: FA2013301 Scenario # 5 Event # 5 Page 12 of 48 Event

Description:

1B Condensate pump degraded head. Leads to SGFP low suction pressure.

Time Pos. Expected Actions/Behavior Comments BOP (step 7) IF suction pressure continues to decrease, THEN start the standby condensate pump.

SRO (step 10) IF operation with three condensate pumps is required, THEN carefully monitor Tave, reactor power, pressurizer level and pressure, and S/G level due to effects of colder feedwater.

AOP-13, Condensate and Feedwater Malfunction ver 33.0 Note: AOP-13 allows direct entry to step 6 BOP (STEP 6.1)Check SGFP suction pressure RNO(6.1.1)Verify standby stabilizes above 275 psig. condensate pump started.

(6.1.2)IF suction pressure still falling,THEN reduce turbine load rapidly usingAOP-17.1 (6.1.3)IF SGFP(s) trip occurs, THEN return to step 1.

BOP (Step 6.2) Check required number of heater drain pumps running.

BOP (step 6.3) Check required number of condensate pumps running.

BOP (Step 6.4) Verify proper position of Contains all field actions and condensate and feedwater system valves. will be dispatched.

BOP (step 6.5) Check LESS THAN three RNO When acceptable stop condensate pumps running. on condensate pump and place in Auto.

BOP (step 6.6) Check SGFP suction pressure stabilizes GREATER THAN - 300 psig.

At the discretion of the Lead Examiner move to next Event 6.

Op Test No.: FA2013301 Scenario # 5 Event # 6 Page 13 of 48 Event

Description:

Fast ramp required AOP-17.1 entry.

Time Pos. Expected Actions/Behavior Comments AOP-17.1, Rapid Turbine Load Reduction, version 4 SRO (step 1) Perform a rapid ramp briefing

- Use attachment 1 as time permits

- Contact Rx Engineering as soon as practical for fast ramp recovery recommendation

- Notify SRC of power reduction if it will will result in greater than 15% Rx power change in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to perform STP-746 (SR 3.4.16.2)

BOP (step 2) Reduce turbine load at desired rate in OPERATOR AUTO (DEH)

- Desired rate will be between 7 and 11 MW/min 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 down, GVs start to move.

RO (step 3) RO will maintain Tavg w/i +5°F of Continuing action step Tref by adjusting rod position or boron concentration.

Verify rods are in AUTO or MANUAL as desired RO (step 3.2) If required Initiate a manual See next page for SOP-2.3 boration per SOP-2.3 below: actions RO (step 3.2.1) IF desired the Boration response can be optimized by:

- Placing a second letdown orifice in service.

OR

- Use of the Emergency Borate valve MOV 8104.

(step 3.2.2) Start additional pressurizer heaters as required.

- To aid in maintaining pressurizer pressure.

- To increase Boron mixing

Op Test No.: FA2013301 Scenario # 5 Event # 6 Page 14 of 48 Event

Description:

Fast ramp required AOP-17.1 entry.

Time Pos. Expected Actions/Behavior Comments (step 3.3) RO will adjust rod position to maintain Delta I w/i limits (step 3.4) check proper operation of the Steam Dumps.

- Check LOSS OF LOAD INTERLOCK C-7A on the BYP & PERMISSIVES panel is illuminated.

- Check STM DUMP MODE SEL TRAINS A B in TAVG.

- Check STM DUMP INTLK TRAIN A and B in ON.

- Check steam dumps properly responding to TAVG/TREF deviation SOP-2.3, CVCS Rx Makeup Control System version 59.1 RO (Step 1.0) Borating per SOP-2.3 appendix B

• 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 each time a boration is

• MKUP MODE CONT SWITCH to 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 FCV113B opens.

• BORIC ACID TO BLENDER FCV113A opens.

• Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

AOP-17.1 actions CONTINUED below:

BOP/ (step 4) 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

Op Test No.: FA2013301 Scenario # 5 Event # 6 Page 15 of 48 Event

Description:

Fast ramp required AOP-17.1 entry.

Time Pos. Expected Actions/Behavior Comments SRO (step 5) Check parameters w/I limits for Continuing action step continued operation

- PZR level >15%

- Pzr press > 2100 psig

- SG NR levels 35-75%

- Tavg 541 - 580°F

- Control bank LO-LO position clear (FE2)

- Delta I w/I limits RO (step 6) when power reduction completed Continuing action step then restore Tavg to programmed value

• Adjust turbine load at less than or equal to 2 MW/min.

• Refer to Table 1 to aid in determining needed boration and/or rod position.

• WHEN TAVG is within 3°F of TREF, THEN adjust boron and rods as needed to control Delta I.

RO (step 7) Check LOSS OF LOAD INTERLOCK C-7A NOT illuminated.

BOP/ (step 8) Check plant stable.

RO When 5% ramp is reached, at the discretion of the Lead Examiner move to next Event 6.

Op Test No.: FA2013301 Scenario # 5 Event # 7 Page 16 of 48 Event

Description:

1C Condensate pump trips. Loss of BOTH SGFPs.

1C Condensate pump trips and suction pressure decreases to SGFP automatic trip setpoint (30 second delay), causing a LOSS OF FEED >5% power.

Indications Available:

Annunciators: Indications

- KB4 SGFP SUCT PRESS PO - SGFP speed decreasing

- KC3 1A or 1B SGFP TRIPPED - SGWL decreasing

- JF1,2,3 SG LVL DEV - SGFP suction pressure decreasing Time Pos. Expected Actions/Behavior Comments AOP-13, Condensate and Feedwater Malfunction, ver 33 SRO (step 1) Check only one SGFP running RNO Proceed to step 2 SRO (Step 2) Check Both SGFPs - TRIPPED RO (Step 2.1) Check Rx power less than 5% RNO Trip the reactor and go to FNP-1-EEP-0, REACTOR TRIP OR SAFETY INJECTION.

See next page for FRP-S.1 actions.

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 17 of 48 Event

Description:

FRP-S.1 Entry When the crew tries to trip the reactor, the reactor trip breakers will not open and one of the CRDM MG set breakers will not open.

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 Time Pos. Expected Actions/Behavior Comments Enter EEP-0, Reactor Trip or Safety Injection, version 44 SRO Reactor trip Direct the reactor trip and enter EEP-0.

RO/ Immediate Operator actions of EEP-0 RNO BOP (step 1) Check reactor trip. 1.1 Manually trip reactor.

Check all reactor trip breakers and reactor 1.2 IF reactor can NOT be trip bypass breakers - OPEN. tripped, THEN trip both MG set Check nuclear power - FALLING. supply breakers.

check rod bottom lights - LIT.

• N1C11E005A

• N1C11E005B 1.3 IF reactor will NOT trip, THEN go to FNP-1-FRP-S.1 SRO Direct entry into FRP-S.1, RESPONSE TO NUCLEAR POWER GENERATION - ATWT, Ver 27.0 Steps 1 and 2 are IOA steps 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.

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 18 of 48 Event

Description:

FRP-S.1 Entry Time Pos. Expected Actions/Behavior Comments BOP (step 2) Check Main Turbine tripped RNO 2.1 Place main turbine emergency trip switch to TRIP for at least 5 seconds.

Critical task RNO 2.2 IF turbine can NOT be tripped, THEN reduce GV position demand signal to zero from DEH panel.

[] TURBINE MANUAL depressed

[] GV CLOSE depressed

[] FAST ACTION depressed NOTE: Any time beyond this point crew may elect to take Early Action for Step 7 and direct an SO to locally open the RTBs.

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.

• Start a BAT pump

• Open MOV 8104

• Establish normal letdown flow - 8149A and either 8149B or C open

• Establish normal charging flow > 40 gpm

• Verify adequate emergency boration flow of > 30 gpm on FI-110

• Check RCS pressure less than 2335 psig

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 19 of 48 Event

Description:

FRP-S.1 Entry Time Pos. Expected Actions/Behavior Comments BOP (step 5) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

• 3197

• 3198D

• 3198C

• 3196

• 3198A BOP will take HS 3198 and

• 3198B HS 3196 to close and HS Verify containment mini purge dampers - 2868 to stop. This will close CLOSED. required dampers and CTMT PURGE DMPRS secure the fan.

MINI-2866C & 2867C FULL-3198A & 3198D

• 2866C

• 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

• 2866D

• 2867D Stop MINI PURGE SUPP/EXH FAN.

BOP (step 6) Check SI actuated -

6.1 BYP & PERMISSIVE SAFETY INJECTION

• ACTUATED status light lit

• MLB-1 1-1 lit

• MLB-1 11-1 lit (IF SI has actuated) 6.2 Initiate ATTACHMENT 1, Go to page 38 for ATT 1 AUTOMATIC SAFETY INJECTION actions.

VERIFICATION.

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 20 of 48 Event

Description:

FRP-S.1 Entry Time Pos. Expected Actions/Behavior Comments RO (step 7) Check ALL RTBs open RNO Dispatch an operator to locally trip the reactor trip and bypass breakers.

Check Main Turbine tripped NOTE: Transition to EEP-0 will be made when requirements of step 8 are met.

RO (step 8) Check if reactor still critical. NOTE: [CA] step If power range indication is GREATER RNO Go to procedure and step THAN OR EQUAL TO 5%. in effect.

OR Check any intermediate range startup rate -

POSITIVE.

BOP (step 9) Monitor CST level. NOTE: [CA] step Check CST level greater than 5.3 ft.

CST LVL

• LI 4132A

• LI 4132B BOP (step 10) Check SG levels. NOTE: [CA] step Check at least one SG narrow range level -

GREATER THAN 31%{48%}.

Large Break LOCA will be initiated when EITHER ESP-0.1 entered or at Step 5 of EEP-0

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 21 of 48 Event

Description:

LBLOCA LBLOCA will occur when step 5 of EEP-0 is started Indications Available:

Annunciators: Recognize indications of LOCA

- Various and many

• Charging Flow increasing

• VCT level decreasing

• PZR level decreasing

• CTMT pressure increasing Time Pos. Expected Actions/Behavior Comments Enter EEP-0, Reactor Trip or Safety Injection, version 44 RO/ (step 1) Check reactor trip. Immediate Action steps of BOP Check all reactor trip breakers and reactor EEP-0 trip bypass breakers - OPEN.

Check nuclear power - FALLING.

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 4160V bus) power available lights lit OR B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 22 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO (step 4) Check SI Status.

(step 4.1) Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit (step 4.2) Verify both trains of SI-ACTUATED.

[] MLB-1 1-1 lit AND [] MLB-1 11-1 lit NOTE: When FRP-P.1 is entered actions are located on PAGE 34 NOTE: Crew may transition to ESP-0.1 depending on plant conditions.

FOLDOUT PAGE criteria of ESP-0.1 to actuate SI and transition back EEP-0 is PZR level <4%.

If required, actions for ESP-0.1 are located on PAGE 35 SRO (step 5) Directs continuing into EEP-0 at step For Attachment 2 and 4

5. actions.

Directs the BOP to perform Go to page 41 attachment 2.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 23 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO (step 6) Check containment pressure- HAS NOTE: [CA] step -

REMAINED LESS THAN 27 psig RNO 6.1 Verify PHASE B CTMT ISO - ACTUATED.

• MLB-3 1-1 lit

• MLB-3 6-1 lit 6.2 Stop all RCPs.

RCP

• 1A

• 1B

• 1C 6.3 Verify PHASE B CTMT ISO alignment.

6.3.1 Check All MLB-3 lights lit.

6.3.2 IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.

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

[] FI 3229A

[] FI 3229B

[] FI 3229C o Total Flow FI 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.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 24 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO (step 8.4) WHEN SG narrow range level NOTE: [CA] step -

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 MDAFWP TO 1A/1B/1C SG B TRN

[] 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

[] TI 432D

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 25 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments 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) 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

[] FI 3229A

[] FI 3229B

[] FI 3229C COND VAC BKR AFW TOTAL FLOW MAN ISO (155 ft, TURB

[] FI 3229 BLDG)

[] N1N51V518A open IF MSIVs are closed THEN proceed to step [] N1N51V518B open 9.1.8 to break condenser vacuum COND VAC BKR VLVS

[] N1N51V519A/519B open BOP (step 9.1.5 RNO) IF MSIVs are open THEN isolate steam loads in the turbine building:

• MSRs reset (steps 9.1.5.1 and 9.1.5.2 RNO) these actions are performed by Systems Operators when RX trip is announced in step 7.

BOP (step 9.1.5.4 RNO) IF two SJAEs in service, THEN secure one SJAE

• 1A SJAE o A Section ISO closed o B Section ISO closed

• 1B SJAE o A Section ISO closed o B Section ISO closed

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 26 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments BOP (step 9.1.6 RNO) IF cool down continues THEN close main steam isolation and bypass valves.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B

[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SGMSIV - BYPASS

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 27 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior 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 TI-463 Check PRT parameters STABLE or FALLING.

[] PRT PRESS PI 472

[] PRT LVL LI-470

[] PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 NOTE: [CA] step -

psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.

1A(1B) LOOP SPRAY VLV

[] PK 444C

[] PK 444D Check any PRZR PORV ISO - OPEN RO (step 11) Check RCP criteria. RNO If HHSI flow greater than Check SUB COOLED MARGIN MONITOR 0 gpm THEN stop all RCPs.

indication - GREATER THAN 16°F{45°F} NOTE: Also required by SUBCOOLED IN CETC MODE Foldout page.

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

[] PI 402A

[] PI 403A

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 28 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior 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.

SRO (step 14) Check SGs not ruptured Check secondary radiation indication - NORMAL.

[] R-15 SJAE EXH

[] R-19 SGBD SAMPLE

[] R-23A SGBD HX OUTLET

[] R-23B SGBD TO DILUTION

[] R-15B TURB BLDG VNTL (BOP)

[] R-15C TURB BLDG VNTL (BOP)

[] R-60A MS ATMOS REL (BOP)

[] R-60B MS ATMOS REL (BOP)

[] R-60C MS ATMOS REL (BOP)

[] R-60D TDAFWP EXH (BOP)

[] No SG level rising in an uncontrolled manner.

(step 15) Check RCS intact. RNO Go to FNP-1-EEP-1,

• Check containment radiation - LOSS OF REACTOR OR NORMAL. SECONDARY COOLANT.

[] R-2 CTMT 155 ft

[] R-7 SEAL TABLE

[] R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

• Check containment pressure -

LESS THAN 3 psig.

• Check containment ECCS sump level - LESS THAN 0.4 ft.

Transition to EEP-1.0, version 31 At the discretion of Chief examiner, if critical tasks met scenario may be terminated here.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 29 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO (step 1) Check SUB COOLED MARGIN RNO 1.1 IF HHSI flow greater MONITOR indication - GREATER, than0 gpm THEN stop all THAN 16°F{45°F} SUBCOOLED IN RCPs.

CETC MODE. RCP

[] 1A

[] 1B

[] 1C BOP (step 2) Check SGs not faulted

- no press falling uncontrolled

- none less than 50 psig BOP (step 3) Checks intact SG levels Verifies any intact SG NR level > {48}

Controls MDAFW & TDAFW flows as necessary to maintain levels {48%-65%}

Stops TDAFW pump WHEN at least 2 SGs

>28%

BOP (step 4) Check SGs not ruptured [] R-15

- Check secondary radiation indication - [] 19 NORMAL. [] 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 SRO (step 6) directs step 6 be performed (1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> from start of event requirements - not available to perform in simulator-SRO calls for SSS or an extra to perform)

- Close recirc disconnects

- Establish 1A & 1B post LOCA H2 analyzer on service per ATT 2

- Plot H2 on Fig 1

- Check and control H2 concentration in Ctmt

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 30 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments SRO (step 7) Checks for SI termination criteria SI termination criteria may be RO and continues on without terminating SI due met but transition to ESP-1.1 is to inadequate RCS pressure & Pzr level incorrect.

RO (step 8) Checks containment spray system

- any CS pump started

- Reset containment spray signals.

CS RESET

[] A TRN

[] B TRN RO (step 9) Determines LHSI pumps should (step 9 RNO) Establish CCW NOT be stopped due to RCS Pressure < flow to RHR heat exchangers.

{435 psig}, RCS pressure stable or rising and CCW TO 1A(1B) RHR HX RHR pumps running with suction aligned [] Q1P17MOV3185A open from RWST [] Q1P17MOV3185B open

[] PI 402B

[] PI 403B BOP (step 11) Performs EEP-1 ATT 4, See Tab at end of scenario for VERIFYING 4160 V BUSSES ENERGIZED Attachment 4 actions. Page 45 SRO (step 12) Directs securing Unloaded DGs (extra, Unit two UO, or BOP)

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 31 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO (step 13) Begin evaluation of plant status.

(step13.1) Verify cold leg recirculation-AVAILABLE.

(step 13.1.1) Train A equipment available:

1A RHR Pump CTMT SUMP TO 1A RHR PUMP Q1E11MOV8811A CTMT SUMP TO 1A RHR PUMP Q1E11MOV8812A 1A RHR HX TO CHG PUMP SUCT Q1E11MOV8706A CCW TO 1A RHR HX Q1P17MOV3185A OR (step 13.1.2) Train B equipment available:

1B RHR Pump CTMT SUMP TO 1B RHR PUMP Q1E11MOV8811B CTMT SUMP TO 1B RHR PUMP Q1E11MOV8812B 1B RHR HX TO CHG PUMP SUCT Q1E11MOV8706B CCW TO 1B RHR HX Q1P17MOV3185B (step13.2) Begin taking ECCS logs BOP 13.3 Evaluate RCS sampling requirements.

13.3.1 Consult TSC staff to evaluate need for RCS sampling.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 32 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments BOP 13.4 Check no intersystem LOCA outside CTMT.

13.4.1 Check auxiliary building radiation -

NORMAL.

[] R-3 RADIOCHEMISTRY LAB

[] R-4 1C CHG PUMP RM

[] R-5 SFP RM

[] R-6 SAMPLE RM AREA

[] R-8 DRUMMING STATION

[] R-10 PRF

[] R-17A OR R-17B CCW BOP 13.4.2 Check auxiliary building room sumps - HI LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO. (BOP)

BOP 13.4.3 Check WHT and FDT levels -

NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

RO 13.4.4 Check PI600A(B) 1A(1B) RHR PUMP DISCH PRESS - LESS THAN 450 psig.

BOP 13.5 Verify at least one train of PRF in operation using FNP-1-SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

13.6 Verify VCT level - GREATER THAN 5%.

RO 14 Check LHSI flow in progress.

14.1 Check RCS pressure - LESS THAN 275 psig{435 psig}.

1C(1A) LOOP RCS NR PRESS

[] PI 402B

[] PI 403B

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 33 of 48 Event

Description:

LBLOCA Time Pos. Expected Actions/Behavior Comments RO 14.2 Verify both LHSI flows - GREATER THAN 1.5x103 gpm.

1A(1B)

RHR HDR FLOW

[] FI 605A

[] FI 605B BOP 15 Check when to transfer to cold RNO 15.1 Return to step 13.

leg recirculation.

15.1 Check RWST level - LESS THAN 12.5 ft.

RWST LVL

[] LI 4075A

[] LI 4075B SRO 15.2 Go to FNP-1-ESP-1.3, TRANSFER TO COLD LEG RECIRCULATION.

At the discretion of Chief examiner scenario may be terminated here.

Op Test No.: FA2013301 Scenario # 5 Event # 9 Page 34 of 48 Event

Description:

FRP-P.1 FRP-P.1 entered due to LBLOCA.

Indications Available:

Annunciators: Recognize indications P.1

-

• CSF Indicators on IPC

• STA evaluation Time Pos. Expected Actions/Behavior Comments FRP-P.1, RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK CONDITIONS, Ver 20 SRO Direct entry into FRP-P.1 RO (step 1) Check RCS pressure GREATER RNO THAN 275 psig{435 psig}. IF LHSI flow greater than 1500

• PI 402B gpm then return to procedure

• PI 403B and step in effect.

• FI 605A

• FI 605B

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 35 of 48 Event

Description:

ESP-0.1 Actions ESP-0.1, Reactor Trip Response, rev 32 FOLDOUT PAGE criteria of ESP-0.1 to actuate SI and transition back EEP-0 is PZR level <4%.

When SI is actuated return to PAGE 21 RO (step 1) Check RCS temperature

• IF any RCP running, THEN check RCS average temperature -

STABLE AT OR APPROACHING 547 F BOP (step 1.1.1 RNO) Verify steam dumps closed

• STM Dump Interlock A and B Train to OFF RESET BOP (step 1.1.2 RNO Verify atmospheric reliefs closed. MS ATMOS REL VLV

• PC 3371A

• PC 3371B

• PC 3371C BOP (step 1.1.3 RNO) IF MSIVs are open THEN NOTE: steps in 1.3.1 RNO isolate steam loads in the turbine building other than listed actions are while continuing with RNO step 1.1.4. dispatched outside of the

• Resets MSRs control room BOP (step 1.1.3.4 RNO) IF two SJAEs in service, THEN secure one SJAE

• 1A SJAE o A Section ISO closed o B Section ISO closed

• 1B SJAE o A Section ISO closed o B Section ISO closed BOP (step 1.1.3.5 RNO) Verify SG blowdown -

ISOLATED 1A(1B,1C) SGBD

• Q1G24HV7614A closed

• Q1G24HV7614B closed

• Q1G24HV7614C closed

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 36 of 48 Event

Description:

ESP-0.1 Actions BOP (step 1.1.4 RNO) IF cooldown continues, THEN minimize total AFW flow. NOTE: This may have been AFW FLOW to 1A(1B,1C) SG already directed to be

• FI 3229A controlled via operator aid

• FI 3229B posted on MCB

• FI 3229C AFW TOTAL FLOW

• FI 3229 o Control TDAFWP FCV 3228 Reset SIC 3405 adjusted BOP (step 1.1.5 RNO) IF cooldown continues THEN close main steam isolation and bypass valves.

1A(1B,1C) SG MSIV - TRIP

[] Q1N11HV3369A

[] Q1N11HV3369B

[] Q1N11HV3369C

[] Q1N11HV3370A

[] Q1N11HV3370B

[] Q1N11HV3370C 1A(1B,1C) SG MSIV - BYPASS

[] Q1N11HV3368A

[] Q1N11HV3368B

[] Q1N11HV3368C

[] Q1N11HV3976A

[] Q1N11HV3976B

[] Q1N11HV3976C

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 37 of 48 Event

Description:

ESP-0.1 Actions (step 2) When RCS average temperature less than 554F THEN verify feedwater status (step 2.1) Verify main feedwater flow control and bypass valves- CLOSED 1A(1B,1C) SG FW FLOW

• FCV 478

• FCV 488

• FCV 498 1A(1B,1C) SG FW BYP FLOW

• FCV 479

• FCV 489

• FCV 499 (step 2.2) Defeat MDAFWP auto start on SGFP trip.

• 1A in DEFEAT

• 1B in DEFEAT (step 2.3) Verify both steam generator feed pumps - TRIPPED

Op Test No.: FA2013301 Scenario # 5 Event # 7 Page 38 of 48 Event

Description:

Attachment 1 of FRP-S.1 Time Pos. Expected Actions/Behavior Comments 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 1-1 lit

[] MLB-1 11-1 lit BOP (step 3) Verify MFW status Verify main FRVs and bypass valves - valves CLOSED.

1A(1B,1C) SG STOP VLVFW FLOW

• FCV 478

• FCV 488

• 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 11-1 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 (1C or 1B) amps > 0

Op Test No.: FA2013301 Scenario # 5 Event # 7 Page 39 of 48 Event

Description:

Attachment 1 of FRP-S.1 BOP (step 6) Verify RHR PUMPs - STARTED.

• RHR PUMP 1A and 1B amps > 0 (step 7) Verify each train of CCW - STARTED.

BOP Verify one CCW PUMP in each train- STARTED.

A train HX 1C or 1B CCW FLOW

• FI 3043CA > 0 gpm OR

• FI 3043BA > 0 gpm B train HX 1A or 1B CCW FLOW

• FI 3043AA > 0 gpm OR

• FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

• Q1P16FI3009AA > 0 gpm

• Q1P16FI3009BA > 0 gpm

• Q1P16FI3009CA > 0 gpm (step 8) Verify each SW train - HAS TWO SW PUMPs STARTED.

• A train (1A,1B or 1C)

• B train (1D,1E or 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 A train

• 1A

• 1B B train

• 1C

• 1D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

• Q1P16MOV3024A

• Q1P16MOV3024B

• Q1P16MOV3024C

• Q1P16MOV3024D

Op Test No.: FA2013301 Scenario # 5 Event # 7 Page 40 of 48 Event

Description:

Attachment 1 of FRP-S.1 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 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 psig.

End of attachment 1 of FRP-S.1

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 41 of 48 Event

Description:

Attachment 2 of EEP-0 Cue: BOP will accomplish when at step 5 of EEP-0 Attachment 2 of EEP-0 AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.

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

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

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.

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

[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow - greater than 3

1.5 X10 gpm

[] 1A RHR HDR FLOW FI-605A

[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

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

[] B train (1D,1E or 1C)

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 42 of 48 Event

Description:

Attachment 2 of EEP-0 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 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

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

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 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

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 43 of 48 Event

Description:

Attachment 2 of EEP-0 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

[] 1A

[] 1B B train

[] 1C

[] 1D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 44 of 48 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED. RNO 8.1 Verify MDAFW Verify both MDAFW Pumps - STARTED Pumps deliver flow to each

[] 1A MDAFW Pump amps > 0 SG.

[] 1B MDAFW Pump amps > 0 8.1.1 Manually start MDAFW AND Pumps

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm 8.1.2 Verify AFW flow path to

[] FI-3229C indicates > 0 gpm AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open (Step 8.2) Check TDAFW Pump start required.

Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 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

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 45 of 48 Event

Description:

Attachment 2 of EEP-0 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

[] 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

[] 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.

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 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 [] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 46 of 48 Event

Description:

Attachment 2 of EEP-0 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

[] N1C11E005A

[] N1C11E005B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] 1B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 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-0-SOP-0.0, APPENDIX B, accomplish this.

TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN 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

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 47 of 48 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Seen Next Page Two Train ECCS Alignment Verification.

End of Attachment 2

Op Test No.: FA2013301 Scenario # 5 Event # 8 Page 48 of 48 Event

Description:

Attachment 4 of EEP-0 Time Pos. Expected Actions/Behavior Comments Attachment 4 of EEP-0 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 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

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2013-301 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, call Unit 2 at 2434 or page the Unit 2 Unit Operator.

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 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]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 75% power, 1177 ppm, MOL 10,000 MWD/MTU Status TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - B Train STP-27.1 completed 2 Protected hours ago 1.0  ; 109.1 No adj. ; 63.7  ; FSP-20,0  ;

Status of Special Testing General Information

1. Shift Goal is to ramp unit to 100% power.

2. Current Risk Assessment is YELLOW and projected is YELLOW due to maintenance on 1A MDAFW pump and 1C DG

3. UOP-3.1 ver 112.4, is complete through step 5.19

4. 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

5. 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

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

7. Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

8. Unit 2 is at 100% power with no major issues.

9.

Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status 70 gallon dilutions every 10 minutes to maintain #3 RHT - On Service current conditions.

WGS - secured LCO Status 3.8.1 Condition B for 1C DG, STP-27.1 completed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago 3.7.5 Condition B for 1A MDAFW Pump 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 ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes

Scenario #6 FA2013301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-36 NRC EXAM SCENARIO #6 Validation time: 100 minutes Validated by McCaffery, Sorrell, Phillips The week of February 18, 2013 TRN Supervisor Approval: Gary Ohmstede Date: 3-13-13 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3

Appendix D Scenario #6 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 6 Op-Test No.: FA2013-301 Examiners: Operators: SRO RO BOP Initial Conditions: 85% power, ramping to 18% power, 915 ppm, MOL.

Turnover:

• Ramping unit to 18% power for containment entry to add oil to the 1B RCP.

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs).

• 1A MDAFW T/O 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 YELLOW and projected is YELLOW.

• A Train On-Service - B Train Protected.

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

SPLIT TRAIN ALIGNMENT Event Malf. No. Event Type* Event Description No.

R (RO) Ramp down at 2 MW/min -ramp on hold with 2 MW/min in and 1 N (BOP) HOLD not LIT- BOP will have to place the IMP PRESS LOOP in service, enter ramp rate and target, depress GO Irf loa- C (RO) 1C charging pump high lube oil temperature. Will have to be secured ccw059 and 1A or 1B Chg pump started.

2 TS (SRO) TS 3.5.2 Condition A 3 Preset I (BOP) 1B SGFP develops speed oscillations -can be controlled in manual.

4 Imf lk459f- I (RO) LK-459F, PRZR LVL CONTROLLER, fails LOW d

imf mal- C (BOP) 1C RCP Thermal Barrier leak ccw6c 5

TS (SRO) TS 3.4.13 Condition A (until leak is isolated) 6 irf loa- M (ALL) Vacuum degrades requiring a RX trip cfw049 Preset C (RO) Reactor will not automatically trip; manual RX trip will occur upon operation of the second hand switch.

7 C (BOP) The Main Turbine will not trip in auto or manual, closing GVs in manual one GV sticks, required to close MSIVs. (CT)

Preset M(ALL) TDAFW pump will trip 1 minute after it starts.

8 The 1B MDAFW pump begins to experience degraded head.

Terminate event when condensate flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2013 exam Page 2 of 11

Appendix D Scenario 6 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS 0 0 Load in IC-216 and sim IC snap directory Base IC- 58 RUN RUN simulator 0 0 Generic setup:

bat 36exam/generic_setup_HLT.txt 0 0 Quick setup (all items with

• are included):

bat 36exam/2013nrcexam_6.txt PRESETS Event Malfunction

• means in Bat file No.

7 Fail RTB from opening in auto

• imf cbkrxtrp_cc6 open imf cbkrxtrp_cc5 open 7 MCB side Rx Trip Switch fails to cause trip

• imf cbkrxtrp_opos1 open 7 Prevent manual trip of main turb.

• imf mal-tur24 7 Main turbine fails to auto trip:

• imf mal-tur2 8 Trip TDAFW pump after one minute on after pump speed TRG 2 above 3500rpm imf mal-fwm1c (2 60) 8 Degrades head of B MDAFW pump to 95% degraded over 30 TRG 3 seconds after TDAFW pump trips imf nafp01b-d_th (3 5) 95 30 7 ALL MSIVs will not close on auto closure

• imf crsh001a_cc5 open imf cmsh002a_d_cc5 open imf crsh001b_cc5 open imf cmsh002b_d_cc5 open imf crsh001c_cc5 open imf cmsh002c_d_cc5 open 0 Tag Out 1A MDAFW Pump

• irf cafp01a_d_cd1 open 0 1C DG Tagged out

• irf cBK1DH07_d_cd1 open irf cBK2DH07_d_cd1 open irf cBK1DH07_d_cd2 open irf cBK2DH07_d_cd2 open Farley June 2013 exam Page 3 of 11

Appendix D Scenario 6 Presets Form ES-D-1 Triggers and Commands 8 Event Trigger 1 GV2 reaches 25% going closed, it sticks at TRG 1 20% open trgset 1 "rehgvpz(2) < 25" trg 1 "imf mal-tur15f 20 1" 8 Event Trigger 2 Triggers trip of TDAFW pump after startup TRG 2 trgset 2 "oafp02 > 3500" 8 Event Trigger 3 Degrades the head of the B MDAFW pump TRG 3 trgset 3 "jmfwm1c > 0" 1 Event Trigger 4 Charging pump 1C trip due to high LO temp TRG 4 trgset 4 "tchspoil(3) > 175" trg 4 "imf cCVP01C_d_cc15 closed" Farley June 2013 exam Page 4 of 11

Appendix D Scenario 6 Simulator setup Form ES-D-1 MCB setup 1C DG MSS Place in Mode 3 Place HOLD Tag on 1C DG MSS 1 HOLD TAG Place HOLD Tag on 1C DG DG output breakers DHO7-1 and 2 HOLD TAGS DHO7-2 Place Unit 1 and Unit 2 Bypass and inoperable panel lights to Unit 1 A-Train the up position (EMERGENCY POWER SYSTEM) Unit 2 A Train Place Unit 1 Bypass and inoperable panel lights to the up Unit 1 A-Train position (Auxiliary Feedwater System)

Place HOLD Tag on 1A MDAFW pump H/S 1 HOLD TAG DEH Clear DEH alarms Verify Impulse loop is NOT in service Select OPS 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 Cae clearrecorders.cea Provide a marked up copy of UOP-3.1 version 112.4 up UOP-1.3 copy to step 8.2.

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 / 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 June 2013 exam Page 5 of 11

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 RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1 Start of Ramp down at 2 MW/min -ramp on hold ramp on hold exam with 2 MW/min in and HOLD not LIT- BOP will have to enter ramp rate and target, depress GO 2 NRC 1C charging pump high lube oil temperature. Will have to CUE be secured and 1A or 1B Chg pump started.

TS 3.5.2 Condition A 3 NRC 1B SGFP develops speed oscillations -can be controlled CUE in manual.

cae \\36exam\senario6v2.cae 4 NRC LK-459F, PRZR LVL CONTROLLER, fails LOW CUE imf lk459f-d 0 20 5 NRC 1C RCP Thermal Barrier leak CUE TS 3.4.13 Condition A (until leak is isolated) imf mal-ccw6c 15 20 6 NRC Vacuum degrades requiring a RX trip CUE irf loa-cfw049 1000 30 7 Preset Reactor will not automatically trip; manual RX trip will occur upon operation of the second hand switch.

Farley June 2013 exam Page 6 of 11

Appendix D Scenario 6 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Preset The Main Turbine will not trip in auto or manual, closing GVs in manual one GV sticks, required to close MSIVs.

(CT) 8 Preset TDAFW pump will trip 1 minute after it starts.

Preset The 1B MDAFW pump begins to experience degraded head.

Terminate event when condensate flow to SGs accomplished (CT) and FRP-H.1 transition criteria reached.

End of Exam HORNS OFF FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of Ensure data file created.

exam2013sen6grpX.txt NOTE: Substitute grpX with grp1, grp2, or grp3 as appropriate.

NOTE: file will be saved in the OPENSIM directory.

When Control board data no longer needed Then Clear recorders for exam security Cae clearrecorders.cae Farley June 2013 exam Page 7 of 11

Appendix D Scenario 6 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 NONE REQUIRED 8 WHEN REQUESTED MAINTENANCE PERSONNEL: When requested to place jumpers to defeat FW isolation.

REMOTE / N21 / LOA-CFW047 / installed After five minutes, I&C reports:

Jumpers are installed per the attachment in FRP-H.1.

SO: When requested open SGFP bypass valve and isolate mini flows.

irf loa-cfw021 1 30 irf loa-cfw015 0 20 irf loa-cfw016 0 20 8 WHEN REQUESTED SO : When requested for MCC Operations After 3 minutes report On station to operate breakers Buttons open the respective breakers irf cmf3232a_d_cd1 open irf cmf3232b_d_cd1 open irf cmf3232c_d_cd1 open Farley June 2013 exam Page 8 of 11

Appendix D Scenario 6 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME ACTIONS ALL AS REQUIRED SSS, SM and Dispatcher:

(Standard Repeat back failure, procedure entered, plant status, CR in the cue communications to and that type of communications.

inform supervision) 1 NONE REQUIRED 2 1 minute after requested Unit 1 Radside 1C Charging pump oil temperature is and rising slowly 3 WHEN REQUESTED TBSO:

The 1B SGFP is speeding up and slowing down. I cant tell why from out here. I dont see any other apparent problems.

4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 NONE REQUIRED 8 WHEN REQUESTED ROVER:

The TDAFWP linkage is broken and cannot be reset The 1B MDAFWP is running normally Farley June 2013 exam Page 9 of 11

Scenario 6 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 85% power, ramping to 18% power, 915 ppm, MOL.

Turnover:

• Ramping unit to 18% power for containment entry to add oil to the B RCP.

• 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

• 1A MDAFW T/O 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 YELLOW and projected is YELLOW,

• A Train On-Service - B Train Protected.

• Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Ramp down in power at 2 MW/min to 18% power.

Verifiable actions: RO will adjust rods or boron to control Tavg/Tref on program, BOP will place impulse loop in service, set target and ramp, and start a ramp on the Main Turbine.

Event 2 1C charging pump HIGH lube oil temperature. The 1C Chg pump will be tripped if temperature reaches 175°F. TS 3.5.2 Condition A Verifiable actions: 1C charging pump will have to be secured and 1A or 1B Chg pump started. If the charging pump trips, then letdown will be secured and re-established.

Event 3 1B SGFP develops speed oscillations and fails to minimum speed if left in Auto after 6 minutes.

Verifiable actions: Take manual control of SGFP speed and control SGWL.

Event 4 LK-459F, PRZR LVL CONTROLLER fails LOW Verifiable actions: RO will take manual control of charging and adjust seal injection flows.

Event 5 1C RCP Thermal Barrier leak, RCS into the CCW system. TS 3.4.13 Condition A (until leak is isolated)

Verifiable actions: Establish excess letdown, secure normal letdown, re-establish normal letdown and secure excess letdown, Isolate CCW cooling to thermal barrier to stop the leak.

Event 6 Degrading Vacuum, Auto Main Turbine and Rx trips are blocked. (SGFPs will trip on low vacuum at approx. 11 to 12 minutes)

Event 7 Reactor will not automatically trip; manual RX trip will occur upon operation of the second hand switch.

Main Turbine will not trip automatically or manually, Manual Fast action will be used to close GVs, One GV sticks open requiring MSIV closure (CT)

Verifiable actions: RO will trip the reactor. BOP will close the MSIVs Event 8 TDAFW pump will trip 1 minute after when it starts.

The 1A MDAFW is tagged out.

1B MDAFWP pump begins to experience degraded head.

Establish Condensate Pump flow to the SGs. (CT)

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

ARP / AOP-16 / AOP-100/ AOP-1/ AOP-8 / EEP-0/ FRP-H.1 Farley June 2013 exam Page 10 of 11

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

1. Failure of the turbine to trip. Manually actuate Main Steam line isolation before a severe (orange path) challenge develops to either the subcriticality or the integrity CSF: (WOG CT E - P)

• Close ONE MSIV in each Main Steam Line.

2. 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). (1AF-FTS-PUMP-H) (WOG CT FR-H.1 - - A)

• Verify flow to A, B, or C SG using condensate pumps.

SCENARIO The team should be able to:

OBJECTIVE/

• Respond to a failed equipment and instruments and complete the appropriate OVERVIEW: ARPs, AOP-100, and Tech Specs

• Respond to an RCS Leak per AOP-1 and then a loss of vacuum event where the Rx will not trip automatically and the Main Turbine will not trip

• The crew will have to establish water flow to the SGs with the condensate pumps per FRP-H.1.

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

1. Total malfunctions (5-8) 8

2. Malfunctions after EOP entry (1-2) 3

3. Abnormal events (2-4) 4

4. Major transients (1-2) 2

5. EOPs entered/requiring substantive actions (1-2) 0

6. EOP contingencies requiring substantive actions (0-2) 1

7. Critical tasks (2-3) 2 Farley June 2013 exam Page 11 of 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 1 Page 1 of 46 Event

Description:

Ramping Down for CTMT entry A ramp of 2 MW/min is in progress. The turnover sheet has the crew place the IMP PRESS LOOP in service per UOP-3.1 section 8.2 and then increase the ramp rate to 5 MW/min and ramp off line IAW UOP-3.1 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.

Indications Available:

Annunciators: Other Indications:

NONE Time Pos. Expected Actions/Behavior Comments UOP-3.1, Power Operation, ver 112.4 step 8.2; Decrease reactor power to minimum load BOP (step 8.2.1) Verify Turbine on HOLD.

(step 8.2.2) Check that the DEH computer point PIA, FIRST STAGE PRESSURE #1 has stable indication.

BOP (step 8.2.3) On the FEEDBACK STATUS DISPLAY, move the cursor to IMP PRESS LOOP OUT (step 8.2.4) Depress the SELECT key.

(step 8.2.5) Verify IMP PRESS LOOP is highlighted in reverse video.

BOP (step 8.2.6) Depress the START key.

(step 8.2.7) Verify FEEDBACK STATUS indicates IMP PRESS LOOP IN.

ALL Re-commences Ramp by coordinating with the BOP to establish Main Turbine Target and ramp rate.

(step 8.3) A Ramp rate of at least 2 MW/ min will be required to ramp unit off per the turnover sheet.

BOP (step 8.4) Verify proper SGFP speed control.

- Monitor SGPF differential pressure

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 1 Page 2 of 46 Event

Description:

Ramping Down for CTMT entry Time Pos. Expected Actions/Behavior Comments 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: The ramp rate will be 2 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.

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 59.1

• Set the boric acid integrator to the desired NOTE: A continuous boration quantity (expect >350 gallons) is allowed by appendix C

• Adjust LTDN TO VCT FLOW controller, which maintains the Boric Acid system lined up. The RO will LK 112, setpoint as desired take the MSS to START each

• M/U mode selector to STOP time a boration is required

• MKUP MODE SEL SWITCH to BOR or

• MKUP MODE CONT SWITCH to START. set the system up to borate (Step 1.6) Verify proper boration operation by continuously. (approx 700 gal observing the following: continuous boration)

• On service boric acid pump started.

• MKUP TO CHG PUMP SUCTION HDR FCV113B opens.

• BORIC ACID TO BLENDER FCV113A opens.

• Boric acid flow is displayed on FI-113 MAKEUP FLOW TO CHG/VCT.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 1 Page 3 of 46 Event

Description:

Ramping Down for CTMT entry Time Pos. Expected Actions/Behavior Comments 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 FCV113B closes.

• BORIC ACID TO BLENDER FCV113A closes.

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

~3 minutes to first alarm for Event 2.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 4 of 46 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 temperature will be at 160°F. Then 2 minutes later the temperature will be at 170°F. We will trip the pump at 175°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 Actions/Behavior Comments Annunciator Response Procedure, ARP-1.5, EA3 Ver 58.0 SRO Direct entry into the ARP and evaluate securing the 1C charging pump.

RO Call the Radside SO to look at the 1C 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 DE1, 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.

SOP-2.1 is on the next page AOP-16 is on PAGE 6 Tech Spec requirements on PAGE 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 5 of 46 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, CVCS Plant Startup and Operation, ver 130.4 (step 4.8) Starting a Charging Pump or Swapping a Charging Pump When RCS Temp is > 180°F:

(step 4.8.1) Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB (step 4.8.2) Check open mini-flow isolation Q1E21MOV8109A or B.

(step 4.8.3) Verify Q1E21MOV8106, CHG PUMP MINIMFLOW ISO, is open.

(step 4.8.4) Verify a 1C or 1B CCW pump is running.

(step 4.8.5) Verify FCV-122, CHG FLOW CONTROLLER, and HIK 186, SEALWTR INJ CONTROLLER are closed if no other chg pump is running RO (step 4.8.6) Start 1A OR 1B Charging pump (step 4.8.7) Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation (step 4.8.8) WHEN charging pump comes up to speed, THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

RO (step 4.8.9) Locally verify that the selected charging pump room cooler is delivering actual air flow.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 6 of 46 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 4.8.10) IF swapping chg pumps, then perform the following:

- Adjust FCV-122, CHG FLOW CONTROLLER, to obtain chg flow proper flow

- Place FCV-122, CHG FLOW CONTROLLER, 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 secured SRO IF RCS pressure is between 2215 and 2255 NOTE: This will be assigned to psig, Direct STP-8.0, RCP seal injection an extra operator leakage test to be performed AOP-16, CVCS Malfunction, ver 18:

RO (Step 1) Verify charging flow adequate to RNO - close all LTDN ORIF cool letdown. ISOs CHG FLOW [] Q1E21HV8149A

[] FI-122A [] Q1E21HV8149B LTDN HX OUTLET FLOW [] Q1E21HV8149C

[] FI-150 REGEN HX OUTLET TEMP

[] TI-140 BOP (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained (Step 4) [CA] Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.

[] PI-121

[] AMMETER FOR RUNNING CHG PUMP

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 7 of 46 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 5) Check charging pump - RUNNING RNO STEP 5 (step 5) RNO Start an available charging pump as follows:

(step 5.1) Check VCT level and pressure adequate.

(step 5.2) Verify charging suction flowpath aligned:

VCT OUTLET ISO valves

• Q1E21LCV115C - OPEN

• Q1E21LCV115E - OPEN OR RWST TO CHG PUMP valves

• Q1E21LCV115B - OPEN

• Q1E21LCV115D - OPEN (step 5.3) Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB.

(step 5.4) Check open miniflow isolation for charging pump to be started:

• 1A CHG PUMP MINIFLOW ISO, Q1E21MOV8109A

• 1B CHG PUMP MINIFLOW ISO, Q1E21MOV8109B

• 1C CHG PUMP MINIFLOW ISO, Q1E21MOV8109C (step 5.5) Verify CHG PUMP MINIFLOW ISO, Q1E21MOV8106, is open.

(step 5.6) Verify the following are closed:

• CHG FLOW FK 122

• SEAL WTR INJECTION HIK 186 (step 5.7) Verify a CCW pump is running in 1A and 1C CCW pumps are same train aligned to supply charging pump running to be started.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 8 of 46 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 RNO Step 5 Continued (step 5.8) Start selected charging pump.

(step 5.9) Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation.

(step 5.10) WHEN charging pump comes up to speed, THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.

(step 5.11) Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP.

RO (Step 6) Check Charging flow FK-122 RNO controlling in AUTO with flow indicated 6.1 Place FK-122 in manual and adjust as required to maintain pressurizer level at program level.

6.2 Adjust SEAL WTR INJECTION HIK-186 as required to maintain RCP seal injection flow 6-13 gpm.

RO (Step 7) Check DE3 clear

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 9 of 46 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 Normal Letdown will have been Letdown: removed from service so it will Check normal CVCS letdown - AFFECTED be placed in service.

BY MALFUNCTION

- LTDN HX OUTLET FLOW, FI-150, NO FLOW INDICATED (Step 8.2) Minimize RCS makeup:

Manually close charging flow control:

CHG FLOW

[] FK-122 (Step 8.2.2) Minimize seal injection between 6-13 gpm (Step 8.2.3) Direct Chemistry to shutdown the zinc addition system (ZAS)

(Step 8.3) Dispatch personnel to investigate NA - this is known cause of the Letdown malfunction RO (Step 9) Determine if normal letdown should be re-established:

Check normal letdown malfunction(s) -

CORRECTED RO (Step 9.2) Verify all letdown orifice isolation valves - CLOSED LTDN ORIF ISO 45 GPM

• Q1E21HV8149A LTDN ORIF ISO 60 GPM

• Q1E21HV8149B

• Q1E21HV8149C (Step 9.3) Place LTDN HX OUTLET TEMP TK 144 on service:

• Place controller in AUTO

• Set to maintain temperature 90 to 115°F

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 10 of 46 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 9.4) Verify VCT HI LVL DIVERT VLV LCV-115A alignment:

• Position indicator VCT light - LIT

• Handswitch in - AUTO (Step 9.5) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

• Handswitch in - VCT

• VCT light - LIT

• DEMIN light - NOT LIT (Step 9.6) IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's from the PRIP.

• Q1E21HV8175A

• Q1E21HV8175B RO (Step 9.7) Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN RO (Step 9.8) Verify LTDN LINE ISO valves -

OPEN

• Q1E21LCV459

• Q1E21LCV460 (Step 9.9) Place LP LTDN PRESS PK 145 on service:

• Place controller in MANUAL

• Adjust demand signal to 50% or less

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 11 of 46 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 9.10) Initiate minimum charging flow:

(Step 9.10.1) Verify CHG FLOW FK 122 in

- MAN (Step 9.10.2) Establish minimum charging flow based on orifices to be placed on service:

1 Orifice - 18 gpm OR 2 Orifices - 40 gpm (Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:

• Q1E21HV8149B OR

• Q1E21HV8149C RO (Step 9.12) IF desired, THEN place the second orifice on service by OPENING:

Q1E21HV8149A (Step 9.13) Initiate actions to restore letdown flow to the demins per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 12 of 46 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 9.14) [CA] IF all backup heaters energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing.

(Step 9.15) Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -

BETWEEN 260-450 PSIG (Step 9.15.1) Set controller between 4.3 and 7.5 (Step 9.15.2) Check letdown flow - STABLE (Step 9.15.3) Place PK 145 in AUTO (Step 9.15.4) Control Letdown pressure as desired RO (Step 9.16) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.

• TI-116 VCT TEMP

• TI-143 DIVERT LTDN HX TEMP

• TI-144 CCW LTDN HX TEMP (Step 9.17) Refer to SOP-2.1, CVCS system PLANT STARTUP AND OPERATION, for further guidance on Letdown system control (step 10) Determine status of letdown flow: Check letdown flow - established SRO (step 10.2) Go to procedure and step in effect Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

Notify the Shift Manager

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 2 Page 13 of 46 Event

Description:

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

Time Pos. Expected Actions/Behavior Comments ARP-1.5, EA3 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 <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO 13.1.5 admin LCO and mandatory LCO while swapping chg pumps from one train to the other Condition A. Two charging pumps shall be operable and this is a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO.

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

B Train ECCS is INOPERABLE until the 1B chg pump is aligned to B Train and the 1C Chg pump is tagged out or a jumper is installed to permit the 1B 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 REQUIREMENT 13.1.5, Charging Pumps - Operating Two charging pumps shall be OPERABLE.

This is an admin LCO to start. When the 1B 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.

• LOSF determination required within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> per 3.8.1 .

At the discretion of the Lead Examiner move to Event 3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 3 Page 14 of 46 Event

Description:

1B SGFP controller oscillation failure 1B SGFP automatic speed controller will oscillate speed. The net effect causes SGWL to decrease because speed falls faster than it rises.

Indications Available:

Annunciators: Recognize indications of 1B SGFP controller

- DEH TRBL (LB1) failing:

- 1A, 1B, 1C SG LVL DEV (JF1, JF2, - ALL FRVs go open JF3) - 1A and 1B SGFP will slow down / speed up

- ALL SG levels (net effect)

Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.4, ver 12 (AOP-13, ver 30, can be entered as well but it takes longer to take action.)

BOP (step 1) Take manual control of SGFP speed NOTE: Step 1 is an Immediate by: Operator Action and a Place SK 509A, 509B or 509C, 1A/B SGFP continuing action step SPEED CONT, in Manual and raise demand as necessary.

Take manual control of all FRV valves

• 1A SG FW FLOW FK-478

• 1B SG FW FLOW FK-488

• 1C SG FW FLOW FK-498 IF a loss of main feedwater occurs, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWATER SRO (step 2) If adverse trends in the SG level exists then establish trip criteria If an automatic action is required or set NOTE: if the SGFP trips at points is approached: 82% level then the reactor Trip the reactor and go to EEP-0 would be tripped at this point.

BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 3 Page 15 of 46 Event

Description:

1B SGFP controller oscillation failure Time Pos. Expected Actions/Behavior Comments BOP (step 4) Adjust speed back to within the 150 psid normal operating range for the feed flow/steam flow P required for the existing power level.

BOP (step 5) Check Steam Dumps in the Tavg mode 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 4 Page 16 of 46 Event

Description:

LK-459F, PRZR LVL CONTROLLER, Fails LOW 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-112/115, VCT level

- LT-459, 460, 461, Actual Przr level Time Pos. Expected Actions/Behavior Comments AOP-100, Instrumentation Malfunction, section 1.2 ver 12.0 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 next page AOP-100 steps below:

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

[] Adjust as necessary using HIK 186, RCP SEAL INJECTION FLOW CONTROLLER SRO (step 3) Determine if a pressurizer level NOTE: LK-459F has failed transmitter/indicator loop has failed

[] Failed or erroneous reading on LI459, LI460 or LI461 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 4 Page 17 of 46 Event

Description:

LK-459F, PRZR LVL CONTROLLER, 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 AOP-16.0, CVCS Malfunction, Ver 18.0 RO (Step 1) Verify CHG flow adequate to cool Closes HV8149 A, B and C letdown CHG FLOW - FI-122A LTDN HX OUTLET FLOW - FI-150 REGEN HX OUTLET TEMP - TI-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 pump operation

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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 4 Page 18 of 46 Event

Description:

LK-459F, PRZR LVL CONTROLLER, Fails LOW Time Pos. Expected Actions/Behavior Comments RO (Step 7) Check DE3 clear (Step 8) Determine Status of Normal Letdown:

Manually close charging FK-122, CHG FLOW controller.

Minimize seal injection between 6-13 gpm Direct Chemistry to shutdown the zinc addition system (ZAS)

RO (Step 9.2) Verify all letdown orifice isolation valves - CLOSED LTDN ORIF ISO 45 GPM

[] Q1E21HV8149A LTDN ORIF ISO 60 GPM

[] Q1E21HV8149B

[] Q1E21HV8149C (Step 9.3) Place LTDN HX OUTLET TEMP TK 144 on service:

[] Place controller in AUTO

[] Set to maintain temperature 90 to 115°F (Step 9.4) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

[] DEMIN light - LIT

[] Handswitch in - AUTO (Step 9.5) Verify LTDN HI TEMP DIVERT VLV Q1E21TCV143:

[] Handswitch in - VCT

[] VCT light - LIT

[] DEMIN light - NOT LIT (Step 9.6) IF necessary, THEN OPEN both LTDN LINE PENE RM ISO's from the PRIP.

[] Q1E21HV8175A

[] Q1E21HV8175B

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 4 Page 19 of 46 Event

Description:

LK-459F, PRZR LVL CONTROLLER, Fails LOW Time Pos. Expected Actions/Behavior Comments RO (Step 9.7) Verify LTDN LINE CTMT ISO Q1E21HV8152 - OPEN (Step 9.8) Verify LTDN LINE ISO valves -

OPEN

[] Q1E21LCV459

[] Q1E21LCV460 (Step 9.9) Place LP LTDN PRESS PK 145 on service:

[] Place controller in MANUAL

[] Adjust demand signal to 50% or less (Step 9.10) Initiate minimum charging flow:

(Step 9.10.1) Verify CHG FLOW FK 122 in

- MAN (Step 9.10.2) Establish minimum charging flow based on orifices to be placed on service:

1 Orifice - 18 gpm OR 2 Orifices - 40 gpm (Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:

[] Q1E21HV8149B OR

[] Q1E21HV8149C (Step 9.12) IF desired, THEN place the second orifice on service by OPENING:

[] Q1E21HV8149A (Step 9.13) Initiate actions to restore letdown flow to the demins per FNP-1-SOP-2.1, CHEMICAL AND VOLUME CONTROL SYSTEM PLANT STARTUP AND OPERATION

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 4 Page 20 of 46 Event

Description:

LK-459F, PRZR LVL CONTROLLER, Fails LOW Time Pos. Expected Actions/Behavior Comments RO (Step 9.14) [CA] IF all backup heaters NOTE: [CA] step -

energized due to pressurizer level deviation, THEN verify two sets of backup heaters in ON prior to level deviation clearing.

RO (Step 9.15.1) Set controller between 4.3 and 7.5 (Step 9.15.2) Check letdown flow - STABLE (Step 9.15.3) Place PK 145 in AUTO (Step 9.15.4) Control Letdown pressure as desired (Step 9.16) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.

[] TI-116 VCT TEMP

[] TI-143 DIVERT LTDN HX TEMP

[] TI-144 CCW LTDN HX TEMP (Step 9.17) Refer to SOP-2.1, CVCS system PLANT STARTUP AND OPERATION, for further guidance on Letdown system control (step 10) Determine status of letdown flow: Check letdown flow - established SRO (step 10.2) Go to procedure and step in effect 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 5.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 5 Page 21 of 46 Event

Description:

Thermal Barrier Leak Leak from RCS to the CCW system via the thermal barrier. This is a difficult leak location.

Indications Available:

Annunciators: Indications of the leak:

RCP SEAL INJ FLOW LO (DD1) Li-112B and 115, VCT LVL, decreasing SEAL WTR INJ FLTR HI DP (DC4) FI-122, CHG FLOW increasing CHG HDR FLOW HI-LO (EA2)

RMS HI RAD (FH1)

CCW SRG TK LVL HI (AA4 & AB4)

Time Pos. Expected Actions/Behavior Comments ARP-1.1 ANNUNCIATOR RESPONSE, AA4/AB4 ver. 53.1 BOP (step 1) Check level HI or LOW - step 4 if HI BOP (step 4.1) Determine source of in-leakage and isolate if possible.

(step 4.2) Check Radiation Monitors R-17A and R-17B for increasing count rates.

(step 4.3) Verify the following make up valves are closed.

• MKUP TO CCW FROM DW STOR TK Q1P17MOV3030A

• MKUP TO CCW FROM DW STOR TK Q1P17MOV3030B

• MKUP TO CCW FROM RMW Q1P17MOV3031A

• MKUP TO CCW FROM RMW Q1P17MOV3031B (step 4.4) IF desired, THEN close CCW SRG TK DEMIN INLET ISO N1P11V045.

(step 4.6) IF CCW Surge Tank level raise is due to RCS leakage, THEN refer to AOP-1.0 AOP-1.0, RCS LEAKAGE, ver. 21.0 SRO Directs entry into AOP-1 and directs actions per RO & BOP rows below:

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 5 Page 22 of 46 Event

Description:

Thermal Barrier Leak Time Pos. Expected Actions/Behavior Comments 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 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, Q1E21LCV459 and Q1E21LCV460

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% Q1E21LCV115B open Q1E21LCV115D open

- RNO- if VCT level can not be maintained RWST TO CHG PUMP MOVS

>20%, then align chg pump suctions to and RWST Q1E21LCV115C closed Q1E21LCV115E closed VCT OUTLET ISO MOVS RO (step 3) Determine leak rate based on flow balance

___________(charging flow)

+___________(seal injection flow)

-___________(letdown flow)

-___________(#1 seal leakoff flow)

=___________(RCS leak rate)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 5 Page 23 of 46 Event

Description:

Thermal Barrier Leak Time Pos. Expected Actions/Behavior Comments SRO (step 4) Leak rate should be determined to NOTE: [CA] step be ~15 gpm.

Tech Spec 3.4.13 should be evaluated:

- > 1 gpm unidentified leakage if location of leak is NOT known.

OR

- >10 gpm identified if location is known.

NOTE TO LEAD EXAMINER:

IF the leak is NOT isolated, THEN LCO 3.4.13 Cond A is a MANDATORY LCO.

IF the leak IS isolated, THEN there is no MANDATORY LCO.

SRO (step 5) Informs Shift Manager of Leak rate NOTE: [CA] step for classification and notification per EIP-8 &

EP-110

- need for CTMT entry to look for leak source

- T.S. requires fix leak in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> or shutdown in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> SRO (step 6) WHEN RCS leak rate greater than 50 gpm, THEN align 1A and 1B post LOCA containment hydrogen analyzers for service using Attachment 1.

NOTE:

• The intent of step 7 is to provide a systematic leakage search plan. Steps 7.2 through 7.12 may be done in any order.

• IF at any time the location of an RCS leak is discovered or reported, THEN actions to isolate the leak should be taken immediately.

• WHEN all leakage sources have been identified, THEN continue with step 8 and further leakage identification actions may be terminated.

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, VCT HI LVL DIVERT VLV, in the VCT position SRO (step 7.3) Check containment sump level -

NOT RISING EXCESSIVELY

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 5 Page 24 of 46 Event

Description:

Thermal Barrier Leak Time Pos. Expected Actions/Behavior Comments BOP (step 7.4) Check containment radiation -

NORMAL 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) NOTE: Crew may not a) Establish excess letdown using SOP-2.7 complete this entire step.

Once leak location is b) Secure normal letdown. understood, should proceed to steps to isolate it.

c) IF CCW parameters return to normal, THEN return to step 3.

d) Establish normal letdown using SOP-2.1 e) Secure excess letdown.

f) IF seal injection supplied NOTE: This step will isolate to all RCPs, THEN isolate CCW from RCP the leak thermal barrier heat exchangers.

CCW FROM RCP THRM BARR

[] Q1P17HV3045 closed

[] Q1P17HV3184 closed g) IF CCW parameters do NOT return to normal, THEN restore CCW from RCP thermal barrier heat exchangers.

CCW FROM RCP THRM BARR

[] Q1P17HV3045 open

[] Q1P17HV3184 open RO (step 7.8) Check PRT conditions normal.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 5 Page 25 of 46 Event

Description:

Thermal Barrier Leak Time Pos. Expected Actions/Behavior Comments BOP (step 7.11) Isolate RCS sampling as follows:

Close the following valves located on U1 BOP PNL L:

• PRZR Stm Sample Iso Q1P15HV3104

• PRZR Liq Sample ISO Q1P15HV3103

• RCS Loops 2&3 Sample Iso Q1P15HV3765

• ACCUM Sample ISO Q1P15HV3766 SRO (step 8) WHEN the RCS leakage source NOTE: [CA] step identified, THEN take appropriate actions to isolate the leak.

LCO 3.4.13 Cond. 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; SRO CONDITION REQUIRED ACTION COMPLETION TIME A. RCS A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> operational within limits.

LEAKAGE not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

When leak is isolated, or Tech Specs are evaluated and a decision is made to shutdown, then at the discretion of the Lead Examiner, move to Event 7.

Tech Specs can be discussed at the end of the scenario since if/when the leak is isolated the LCO will no longer be applicable.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 6 Page 26 of 46 Event

Description:

Vacuum degrades, trip required Vacuum degrades over 4 minutes requiring a trip. The SGFPs will trip if no action is taken approx.

11-12 minutes into the event.

Indications Available:

Annunciators: Recognize indications of degrading vacuum

- LB1 DEH TRBL - Condenser pressure increasing

- KK1 TURB COND VAC LO

- KK2 TURB COND VAC LO-LO Time Pos. Expected Actions/Behavior Comments ARP-1.10, Annunciator Response Procedure, KK1/KK2 Ver 70.2 SRO/ (KK1 step1) Perform the actions required by BOP FNP-1-AOP-8.0, PARTIAL LOSS OF CONDENSER VACUUM.

BOP (KK1 step2) IF condenser pressure approaches the setpoint for KK2, (refer to KK2), THEN ensure the OPERATOR ACTIONS for KK2 are understood.

BOP (KK2 step1) Determine if the alarm is valid.

SRO/ (KK2 step 2) IF reactor power is greater than BOP or equal to 35%, THEN trip the reactor and perform the actions required by EEP-0, BOP (KK2 step 3) IF reactor power is less than 35%, THEN trip the turbine and perform the actions required by FNP-1-AOP-3.0, TURBINE TRIP < P-9 SETPOINT.

AOP-8.0 PARTIAL LOSS OF COND VACUUM Ver 22.1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 6 Page 27 of 46 Event

Description:

Vacuum degrades, trip required Time Pos. Expected Actions/Behavior Comments BOP (step 1) Monitor Condenser pressure (step 1.1) IF annunciator KK1, TURB COND VAC LO in alarm OR setpoint exceeded, THEN increased monitoring of condenser pressure is required:

• 1.485 psia when < 25% turbine power

• 2.901 psia when > 47.9% turbine power

• Varies Linearly Between 25%

(1.485 psia) and 47.9% (2.901 psia)

BOP (step 2) Monitor turbine trip criteria.

(step 2.1) Check condenser pressure less than annunciator KK2, TURB COND VACLO-LO setpoint for existing turbine power using MWe or PT-446/447:

• 1.885 psia when < 25% turbine power

• 3.8 psia when > 55.9% turbine power

• Varies Linearly Between 25%

(1.885 psia) and 55.9% (3.8 psia)

BOP (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.

3.1 IF the rate of condenser pressure increase is significant and approaching annunciator KK1, TURB COND VAC LO setpoint, THEN reduce load prior to reaching annunciator KK1 setpoint.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 28 of 46 Event

Description:

Entry to EEP-0 based on Condenser Vacuum RX trip is successful on second hand switch, One Governor valve sticks requiring MSIVs to be closed.

Indications Available:

Annunciators: Indications of RX trip

- Various and numerous - Nuclear power decreasing

- Rod bottom lights

- Control Room Lighting Time Pos. Expected Actions/Behavior Comments EEP-0, Reactor Trip or Safety Injection, rev 44 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. NOTE: First hand switch fails, Check nuclear power - FALLING. second hand switch is Check rod bottom lights - LIT. successful.

(step 2) Check turbine - TRIPPED. RNO TSLB2 14-1 thru 4 lit 2.1 Place main turbine emergency trip switch to TRIP for at least 5 seconds.

2.2 IF turbine can NOT be tripped, THEN reduce GV position demand signal to zero from DEH panel.

[] TURBINE MANUAL depressed

[] GV CLOSE depressed

[] FAST ACTION depressed (CT)2.3 IF steam flow to main turbine is NOT secured, THEN close all main steam line isolation and bypass valves.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 29 of 46 Event

Description:

Entry to EEP-0 based on Condenser Vacuum Time Pos. Expected Actions/Behavior Comments RO/ (step 3) Check power to 4160 V ESF BOP busses.

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

RO/ (step 4) Check SI Status.

BOP (step 4.1) Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit

[] MLB-1 11-1 lit (step 4.2) Verify both trains of SI-ACTUATED.

[] MLB-1 1-1 lit AND [] MLB-1 11-1 lit SRO (step 5) Directs continuing into EEP-0 at step For Attachment 2 and 4

5. actions.

Directs the BOP to perform Go to page 39 Attachment 2 of EEP-0.

(Fold out page step 5) NOTE: [CA] step 5 Ruptured SG AFW Isolation. The action to Isolate AFW to the ruptured SG may be 5.1 Manually stop AFW flow to a SG if BOTH completed beyond this point.

conditions listed below occur:

Level increases in an uncontrolled manner or radiation in that SG is abnormal AND Narrow range level - GREATER THAN 31% {48%}

(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig (checked on IPC or PI950, 951, 952, 953,CNMT PRESSURE)

RO (step 7) Announce "Unit 1 reactor trip and safety injection".

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 30 of 46 Event

Description:

Entry to EEP-0 based on Condenser Vacuum Time Pos. Expected Actions/Behavior Comments SRO/ (step 8) Check AFW status. RNO RO Check secondary heat sink Available 8.1.1 Verify all available o Check total AFW flow > 395 gpm AFWpumps started.

[] FI 3229A

[] FI 3229B 8.1.2 Verify total AFW flow

[] FI 3229C o Total Flow FI 3229 greater than 395 gpm.

OR Check any SG NR level > 31% {48%} 8.1.3 IF total AFW flow less than 395 gpm, AND all SG WHEN all SG narrow range levels less than narrow range levels less than 31%{48%}, THEN maintain total AFW flow or equal to 31%(48%),

greater than 395 gpm. THEN go to FNP-1-FRP-H.1 WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.

SRO Direct transition to FRP-H.1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 31 of 46 Event

Description:

Transition to FRP-H.1 FRP-H.1, LOSS OF HEATSINK, Ver 27.0 SRO (step 1) Check secondary heat sink -

REQUIRED.

• Check RCS pressure > any non-faulted SG pressure on PT-402/403

• Check RCS hot leg temperatures

> 350°F on TR 413 SRO (step 2) Directs monitoring of bleed and feed criteria

• Check at least two SG wide range levels GREATER THAN 12% {31%}.

• Check pressurizer pressure < 2335 psig SRO (step 3) Direct I&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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 32 of 46 Event

Description:

Transition to FRP-H.1 BOP (step 5) Try to establish AFW flow to at least NOTE: [CA] Step one SG.

(step 5.1) Verifies blowdown isolated from all SGs 1A(1B,1C) SGBD ISO

• Q1G24HV7614A closed

• Q1G24HV7614B closed

• Q1G24HV7614C closed (step 5.2) Verifies SG blowdown sample valves isolated

• MLB4 6-4 lit

• MLB4 7-4 lit

• MLB4 8-4 lit (step 5.3) Recognizes AFW pumps not RNO available 5.3 PERFORM local start from Hot shutdown panels.

(BOOTH OPERATOR WILL

. PERFORM THESE ACTIONS if/when directed)

(step 5.4) Verify at least one flow path to at least one SG ALIGNED Checks OPEN MDAFP to 1A/B/C SG (where x = respective SG A, B or C)

- HV3227x MDAFW TO SG MOD

- HIC3227xA MDAFW FCVs adjusted

- HV3228x TDAFW to SG MOD

- HIC3228xA TDAFW FCVs adjusted

- MOV-3350x AFW STOP vlv OPEN

- MOV3764x MDAFW to SG OPEN (step 5.5) [CA] Check total AFW flow to SGs Continue efforts to establish greater than 395 gpm. AFW flow.

WHEN any feed flow established AND at least one SG narrow range level greater than 31%{48%} THEN go to procedure and step in effect RO (step 6) Stops all RCPs

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 33 of 46 Event

Description:

Transition to FRP-H.1 SRO (step 7) Try to establish main feedwater flow RNO Perform the following.

to intact SGs with one SGFP. a) Verify at least one CNDS PUMP - STARTED b) If unable to establish main feedwater flow and at least one condensate pump is started, THEN proceed to step 9 OBSERVE CAUTION PRIOR TO STEP 9.

RO (step 9) Try to establish condensate flow to NOTE: [CA] Step intact SGs.

9.1 IF SI has NOT actuated since RNO 9.1 Verify SI RESET.

reactor trip, THEN reset FW ISO. [] MLB-1 1-1 not lit

[] MLB-1 11-1 not lit NOTE: Step 9.8, pressurizer pressure reduction, should be performed in conjunction with steps 9.2 through 9.7.

BOP (step 9.2) Check feedwater isolation signal to intact SGs main feedwater regulating bypass valves defeated per ATTACHMENT 1.

BOP (step 9.3) Verify all main feedwater flow control and bypass valves - CLOSED IN MANUAL.

1A(1B,1C) SG FW FLOW

• FK 478

• FK 488

• FK 498 1A(1B,1C) SG FW BYP FLOW

• FK 479

• FK 489

• FK 499 BOP (step 9.4) Verify backup cooling aligned to condensate pumps per FNP-1-SOP-21.0.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 34 of 46 Event

Description:

Transition to FRP-H.1 BOP (step 9.5) Locally open SGFP BYP N1N21V509. (155 ft, TURB BLDG)

(step 9.6) Locally isolate SGFP miniflow valves. (155 ft, TURB BLDG)

SGFP 1A(1B) RECIRC FCV INLET ISO

• N1N21V502A closed

• N1N21V502B closed BOP (step 9.7) Perform the following.

9.7.1 Dispatch personnel to 1V 600 V MCC.

9.7.2 Place handswitch for main feedwater stop valves to intact SGs to OPEN and hold in that position.

• 1A(1B,1C) SG STOP VLV Q1N21MOV 3232A

• 3232B

• 3232C 9.7.3 WHEN main feedwater stop valves to intact SGs open, THEN direct personnel to open associated breakers.

• FV-K2

• FV-K3

• FV-L2 BOP (step 9.7.4) WHEN associated breaker open, THEN allow main feedwater stop valve handswitch to spring return.

RO (step 9.8) Reduce PRZR pressure to less than 1950 psig.

9.8.1 Check either condition for using RNO 9.8.1 Perform the auxiliary spray satisfied. following.

• Normal letdown in service. If normal letdown secured OR and THEN open only one

• No PRZR PORV available. PRZR PORV to reduce PRZR pressure to less than 1950 psig.

AND Proceed to step 9.9.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 35 of 46 Event

Description:

Transition to FRP-H.1 RO (step 9.8.2) Manually open both normal pressurizer spray valves.

1A(1B) LOOP SPRAY VLV

• PK 444C

• PK 444D RO (step 9.8.3) Open auxiliary spray valve.

RCS PRZR AUX SPRAY

• Q1E21HV8145 open RO (step 9.8.4) Verify flow path aligned CHG FLOW

• FK 122 manually open CHG PUMPS TO REGENERATIVE HX

• Q1E21MOV8107 open

• Q1E21MOV8108 open RCS NORMAL CHG LINE

• Q1E21HV8146 closed RCS ALT CHG LINE

• Q1E21HV8147 closed RO (step 9.8.5) Operate the following valves as required to reduce PRZR pressure to less than 1950 psig.

CHG FLOW

• FK 122 manually open 1A(1B) LOOP SPRAY VLV

• PK 444C manually open/closed

• PK 444D manually open/closed RCS PRZR AUX SPRAY

• Q1E21HV8145 open/closed RCS NORMAL CHG LINE

• Q1E21HV8146 open/closed RCS ALT CHG LINE

• Q1E21HV8147 open/closed RO (step 9.9) Maintain PRZR pressure at 1900-1950 psig.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 36 of 46 Event

Description:

Transition to FRP-H.1 RO (step 9.9.1) IF using auxiliary spray, THEN RNO 9.9.1 IF using a PRZR operate the following valves as required to PORV, THEN open only one control PRZR pressure. PRZR PORV to control PRZR CHG FLOW pressure.

• FK 122 manually open 1A(1B) LOOP SPRAY VLV

• PK 444C manually open/closed

• PK 444D manually open/closed RCS PRZR AUX SPRAY

• Q1E21HV8145 open/closed RCS NORMAL CHG LINE

• Q1E21HV8146 open/closed RCS ALT CHG LINE

• Q1E21HV8147 open/closed RO (step 9.10) WHEN pressurizer pressure less than 2000 psig, THEN perform the following.

9.10.1 Block low pressurizer pressure SI.

PRZR PRESS SI BLOCK - RESET

• A TRN to BLOCK

• B TRN to BLOCK 9.10.2 Verify blocked indication.

BYP & PERMISSIVE PRZR. SAFETY INJECTION

• TRAIN A BLOCKED light lit

• TRAIN B BLOCKED light lit

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 37 of 46 Event

Description:

Transition to FRP-H.1 (step 9.11) WHEN P-12 light lit (543F),

THEN perform the following.

9.11.1 Block low steam line pressure SI.

STM LINE PRESS SI BLOCK - RESET

• A TRN to BLOCK

• B TRN to BLOCK 9.11.2 Verify blocked indication.

BYP & PERMISSIVE STM LINE ISOL.

SAFETY INJ.

• TRAIN A BLOCKED light lit

• TRAIN B BLOCKED light lit 9.11.3 Bypass the steam dump interlock.

STM DUMP INTERLOCK

• A TRN to BYP INTLK

• B TRN to BYP INTLK (step 9.12) IF condenser available, RNO 9.12 Dump steam to THEN dump steam to condenser atmosphere. 9.12.1 Direct from intact SGs at maximum counting room to perform FNP-attainable rate.

0-CCP-645, MSIVs are closed so ARVs will be used. MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.

RNO 9.12.2 IF normal air available, THEN control atmospheric relief valves to dump steam from at least one intact SG at maximum attainable rate.

1A(1B,1C) MS ATMOS REL VLV

[] PC 3371A adjusted

[] PC 3371B adjusted

[] PC 3371C adjusted (step 9.13) WHEN SG(s) pressure reduced to less than 540 psig, THEN stop pressure reduction.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 8 Page 38 of 46 Event

Description:

Transition to FRP-H.1 (step 9.14) Maintain SG(s) pressure -

STABLE AT EXISTING VALUE.

(step 9.15) Verify at least one CNDS PUMP

- STARTED.

(step 9.16) Check SGFP BYP N1N21V509 -

OPEN. (155 ft, TURB BLDG)

(step 9.17) Initially open feedwater regulating bypass valves just off the closed seat to initiate flow and minimize any water hammer.

FW BYP FLOW FK

• 479 adjusted

• 489 adjusted

• 499 adjusted (step 9.18) Control feedwater regulating (CT) bypass valves to supply main feedwater to at least one intact SG.

(step 10) Check SG levels.

10.1 Verify feed flow to at least one SG.

• Check SG wide range level -

RISING.

OR

• Check core exit T/C temperature - FALLING.

(step 10.2) Check at least one SG narrow 10.2 Continue feeding SGs to range level - GREATER THAN restore at least one SG narrow 31%{48%}. range level greater than 31%{48%}.

Terminate scenario when FRP-H.1 is exited.

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 39 of 46 Event

Description:

Attachment 2 of EEP-0 Cue: BOP will accomplish when at step 5 of EEP-0 Attachment 2 of EEP-0 AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED.

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

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

RHR PUMP

[] 1A amps > 0

[] 1B amps > 0 BOP (Step 3) Verify Safety Injection Flow.

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

[] FI 943 BOP (Step 3.2) Check RCS pressure - LESS Operator should proceed to THAN step 4 275 psig{435 psig}.

BOP (step 3.3) Check LHSI flow - greater than 3

1.5 X10 gpm

[] 1A RHR HDR FLOW FI-605A

[] 1B RHR HDR FLOW FI-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

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

[] B train (1D,1E or 1C)

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 40 of 46 Event

Description:

Attachment 2 of EEP-0 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 1C or 1B CCW FLOW

[] FI 3043CA > 0 gpm OR

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

[] FI 3043AA > 0 gpm OR

[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(1B, 1C) CCW HX

[] Q1P16FI3009AA > 0 gpm

[] Q1P16FI3009BA > 0 gpm

[] Q1P16FI3009CA > 0 gpm BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[] 3198D

[] 3198C

[] 3196

[] 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

[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 41 of 46 Event

Description:

Attachment 2 of EEP-0 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

[] 1A

[] 1B B train

[] 1C

[] 1D Verify associated emergency service water outlet valves - OPEN.

EMERG SW FROM 1A(1B,1C,1D) CTMT CLR

[] Q1P16MOV3024A

[] Q1P16MOV3024B

[] Q1P16MOV3024C

[] Q1P16MOV3024D

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 42 of 46 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 8) Verify AFW Pumps - STARTED. RNO 8.1 Verify MDAFW Verify both MDAFW Pumps - STARTED Pumps deliver flow to each

[] 1A MDAFW Pump amps > 0 SG.

[] 1B MDAFW Pump amps > 0 8.1.1 Manually start MDAFW AND Pumps

[] FI-3229A indicates > 0 gpm

[] FI-3229B indicates > 0 gpm 8.1.2 Verify AFW flow path to

[] FI-3229C indicates > 0 gpm AND each SG.

[] Q1N23HV3227A in MOD

[] Q1N23HV3227B in MOD

[] Q1N23HV3227C in MOD MDAFWP TO 1A(1B,1C) SG FLOW CONT

[] HIC 3227AA open

[] HIC 3227BA open

[] HIC 3227CA open AFW TO 1A(1B,1C) SG STOP VLV

[] Q1N23MOV3350A open

[] Q1N23MOV3350B open

[] Q1N23MOV3350C open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764A open

[] Q1N23MOV3764D open

[] Q1N23MOV3764F open MDAFWP TO 1A(1B,1C) SG ISO (BOP)

[] Q1N23MOV3764E open

[] Q1N23MOV3764B open

[] Q1N23MOV3764C open (Step 8.2) Check TDAFW Pump start required.

Condition TSLB Setpoint Coincidence RCP Bus TSLB2 1-1 2680 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 43 of 46 Event

Description:

Attachment 2 of EEP-0 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

[] 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

[] 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.

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 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 [] MLB-2 1-1 lit

[] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.

11.3 Verify Excess Letdown Isolation valves closed.

[] Q1E21HV8153, EXC LTDN ISO

[] Q1E21HV8154, EXC LTDN ISO

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 44 of 46 Event

Description:

Attachment 2 of EEP-0 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

[] N1C11E005A

[] N1C11E005B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] 1B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[] 1A

[] 1B 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-0-SOP-0.0, APPENDIX B, accomplish this.

TB SO Actions Following A Reactor Trip Or Safety Injection.

BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[] A TRAIN

[] B TRAIN 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

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 45 of 46 Event

Description:

Attachment 2 of EEP-0 Time Pos. Expected Actions/Behavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, See Next Page Two Train ECCS Alignment Verification.

End of Attachment 2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2013301 Scenario # 6 Event # 7 Page 46 of 46 Event

Description:

Attachment 4 of EEP-0 Time Pos. Expected Actions/Behavior Comments Attachment 4 of EEP-0 TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DF01 closed

[] Verify DF02 closed

[] Check DG15 closed

[] Verfiy DG02 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

[] Q1E21MOV8132A

[] Q1E21MOV8132B

[] Q1E21MOV8133A

[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8130A

[] Q1E21MOV8130B

[] Q1E21MOV8131A

[] Q1E21MOV8131B (Step 1.7) Verify all post accident containment air mixing system fans - STARTED. (BOP)

POST ACCIDENT MIXING FAN

[] 1A

[] 1B

[] 1C

[] 1D RX CAV H2 DILUTION FAN

[] 1A

[] 1B (Step 1.8) WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.

BOP (Step 1.9) Verify SFP Cooling in service per Call Radside SO SOP-54.0, Spent Fuel Pit Cooling And Purification System.

End of Attachment 4

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2013-301 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, call Unit 2 at 2434 or page the Unit 2 Unit Operator.

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 1 [ ] Unit 2 Shift: Date Off-going SS Oncoming SS [ ]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 85% power, 915 ppm, MOL 10000 MWD/MTU Status Ramping down TARGET ZERO STPs/Evolutions: Every Day, Every Job Safely A Train On-Service - B Train STP-27.1 completed 2 Protected hours ago 1.0  ; 109.1 No adj. ; 63.7  ; FSP-20,0  ;

Status of Special Testing General Information

1. Shift goal is to place the IMP PRESS LOOP in service and ramp down to 18% power for containment entry to add oil to the 1B RCP.

2. Current Risk Assessment is YELLOW and projected is YELLOW due to maintenance on 1A MDAFW pump and 1C DG

3. UOP-3.1 ver 112.4 in progress at step 8.2

4. 1C DG T/O for governor work. (OOS 2 days, ETR 4 hrs)

5. 1A MDAFW T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)

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

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

8. Unit 2 PSS in OFF for Maintenance (OOS 2 hrs, ETR 2 hrs)

9. Unit 2 is at 100% power with no major issues.

Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Management Status 20 Gallon dilutions ever 20 minutes to maintain #3 RHT - On Service current conditions.

WGS - secured LCO Status 3.8.1 Condition B for 1C DG, STP-27.1 completed 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> ago 3.7.5 Condition B for 1A MDAFW Pump 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 ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes [ X ] Yes