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Initial Exam 2012-301 Draft Simulator Scenarios
	ML12214A335
Person / Time
Site:	Farley
Issue date:	07/23/2012
From:	; NRC/RGN-II
To:	; Southern Nuclear Operating Co
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Scenario #1 FA2OI 2301 Southern Nuclear JM Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #1 Validation time: 110 minutes Validated by David Shipman, Todd Smith and Doug Jinmierson The week of February 13, 2012 TRN Supervisor Approval: Gary Ohmstede Date: 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTHERN COMPANY

Appendix D Scenario #1 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 1 Op-Test No.: 2012-301 Examiners: Operators: SRO RO SOP Initial Conditions: 85% power, 831 ppm, MOL, ramping down at 2 MW/mm. Ramp is on HOLD to place the IMP PRESS LOOP in service per step 8.2 of UOP-3.1.

Turnover:

1 B MDAFW pump T/O for bearing replacement. (OOS 2 days, ETR 4 hrs)

MK5, SEISMIC PANEL ALARM, actions are in progress.

Current Risk Assessment is YELLOW and projected is YELLOW due to the 1 B MDAFW pump.

B Train On-Service B Train Protected.

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

1 R (RO) Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Place the IMP PRESS N (BOP) LOOP in service and increase ramp rate to 5 MW/mm and ramp down.

2 imf I (BOP) FT-485, CH IV 1 B SG Steam Flow transmitter, fails LOW ft485 TS (SRO) T.S 3.3.2 Condition 0 3 mt I (RO) PT-445 fails HIGH. PORV can be closed, but leaks by; block pt445 valve must be shut.

TS (SRO) T.S. 3.4.11 Condition A and 3.4.1 Condition A 4 mt C (BOP) 1 E SW pump trips; requires starting the 1 C SW pump.

Cncps wlfd TS (SRO) TS 3.7.8 Condition A; 3.8.1 Condition B cc8 5 lmf C (RO) Approx. 130 gpm RCS leak develops. AOP-1 .0 entered.

mal rcsla TS (SRO) T.S. 3.4.13 Condition A 6 lmf 1A MSIV closes requiring a reactor trip.

mal rcs2a C (RO) The reactor fails to automatically trip and must be manually tripped. (CT)

M (ALL) When the reactor trip occurs and transition made to ESP-0,1, a mt LB LOCA occurs.

cBK1D G02_c ol Farley June 2012 exam Page 2 of 12

Appendix D Scenario #1 Outline Form ES-D-1 8 Trg 3 C (RO) SW bus 1 L trips when SI occurs and requires emergency shutdown of 1 B DG per EEP.-O, Attachment 1 or EPB posted operator aid.

9 preset C (BOP) MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Scenario may be terminated after transition to ESP-1 .3 announced.

(N;ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2012 exam Page 3 ofl2

Appendix D Scenario 1 Simulator setup Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 IC-211 MOE, B Train on service, B Train Protected 85% Power Base IC is IC-58 -------

RUN

.

RUN simulator DO_NOT_RUN_THESE_IF_IC-211_IS_USED 0 0 Generic setup:

bat generic_setup_H LT.txt

0 0 Quick setup (all items with are included):

bat 20l2nrcexam 01 .txt

i*K

7 6 Block Phase A isolation train A imf csftyinj_cc7 open

9 8 M0V8100 does not close on Phase A isolation B Train:

imf cCVH100_d_cc8 open

9 8 HV8152 does not close on Phase A isolation B Train:

lmf ccvhl 52_d_ccl closed

9 8 HV3376 does not close on Phase A isolation B Train:

Imfchvh3376 d ccl closed

6 6 RTB A and B fails to open in auto but will manually CMFmalf I cBKRXTRP_cc5 / open CMFmalf / cbkrxtrp cc6 / open 3 2 PORV 445 sticks at 10% after being demanded closed: TRG 1 VLVS / RRC445A-S / 10 / trigger 1 8 7 Breaker DGO2-1 for IL bus trips on SI: TRG 3 CMFmalf / cBKI DGO2_col I trigger 3

0 0 MK5 failed on imf mk5 failon

0 0 Tag 1 B MDAFW pump irf cafpolb_d_cdl open Tiers and Commands

3 2 Event Trigger I monitors P1-444 < 2210 psig

trgset 1 pi444 < 2210

5 5 Event trigger 2 monitors LI-i 15 < 22%:

-

trgset 2 Iii 15 < 22 trg 2 imf mal-rcsi a 130 25

8 7 Event trigger 3 monitors 8803a (for SI):

-

trgset 3 rsi88O3a> 0.1 Farley June 2012 exam Page4ofl2

Appendix D Scenario 1 Simulator setup Form ES-D-l Place HOLD Tag on HS for lB MDAFW pump 1 HOLD tag Place Unit 1 Bypass and inoperable panel light to the up Unit 1 B-Train oosition (AUXILIARY FE EDWATER SYSTEM)

DEH Clear DEH alarms IMPLII SF I flop i NOT in cørvir 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 (100 gallon dilutions required for stablecounteract Xenon: 10 gallon borations durina ramo Recorders Reset recorders as required from back of oanel Provide a marked up copy of UOP-3.1 version 111.1 UOP-3.1 copy through step 82 complete and signed off as necessary.

-I FREEZE simulator Perform Booth Operators Setuø Checklist Open Simview file to be used for plant parameter data collection:

Simview! sv DataCollectionuvl sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 5 of 12

Appendix D Scenario 1 Booth Guide Form ES-D-l EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam

- - I....1 RUN simulator ON: hornflag Turn Horns ON/OFF ORNS ON = TRUE ann horn Start of 1 Seismic event annunciator MK5 is in alarm.

exam Crew will start the ramp Ramp is in progress at 85% power and increase ramp rate to 5 MW/mm NRC 2 FT-485, CH IV 1 B SG Steam Flow transmitter, fails LOW CUE imfft485 015 NRC CUE PT-445 fails HIGH. PORV can be closed, but leaks by; block valve must be shut. Imf pt445 2500 60 trig I sticks PORV 445A open NRC CUE Degrade 1 D SW pump imf nncpswl e-d 80 10 1E SW pump trips.

imf Cncpswl f_dcc8 closed NRC CUE Approx. 130 gpm RCS leak develops. AOP-1 .0 entered.

lmf mal-rcsla 125 120 NRC 6 1A MSIV closes. The reactor fails to trip.

CUE If SI occurs, put in LB LOCA below Farley June 2012 exam Page 6 of 12

Appendix D Scenario 1 Booth Guide Form ES-D-1 7 After When Rx trip occurs and ESP-0.1 entered, then initiate ESP-0.1 LB LOCA. Imf mal-rcs2a 60 entry or if SI occurs 8 preset SW bus 1L trips when SI occurs which requires emergency shutdown of 1 B DG CMFmalf! imf cBKl DGO2 col Check for TRIG 3 use button if needed 9 preset MOV-8100, HV-8152 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto.

Scenario may be terminated after transition to ESP-1 .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 NRC examOl Ensure data file created.

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

NOTE: file will be saved in the OPENSIM directory.

Farley June 2012 exam Page 7 of 12

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

EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 IF REQUESTED RADSIDE:

Not expected to remove power CMFremote I cRC800A_d_cdl I open 4 IF REQUESTED Alignment of 1C to auto-start for 1 E SW pump will not take place during this exam.

IF REQUESTED Clear TURB BLDG MISC alarm imf kf2 failoff Clear SGBD PROC PNL TRBL alarm 5 IF REQUESTED Clear Liq or WG panel alarm WHEN REQUESTED imf mk4 failoff Unit Two UO RESET FIRE ALARM MH1 ANN / MH1 failoff Fire alarm is reset fire alann was 1A-22 in Unit One CTMT 6 NONE REQUIRED 7 NONE REQUIRED 8 NONE REQUIRED 9 NONE REQUIRED Farley June 2012 exam Page 8 of 12

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

IF REQUESTED SM:

I will contact Corporate Farley Plant Support and request the plant walk downs be conducted.

I will contact maintenance to perform FNP-OMP112.1 I will get the condition reports required by the ARP generated.

2 WHEN REQUESTED SSS-plant, SM and Disjatcher:

Recognize and repeat back FT-485 failure, CR in the cue and that type of communications.

SM:

I give you permission to place the FRV back in AUTO.

3 IF REQUESTED RADSIDE:

Not expected to remove {After Local operator actions to open breaker FU-K4 are complete}

power I have opened breaker FU-K4 SM:

I understand we have an LCO for the PORV and that the block valve (8000A) had to be closed.

Work Week Co-ordinator I Understand there is a CR in Syncpower for PT-445 4 WHEN REQUESTED SSS I OUTSIDE:

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

iC 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 IE SW pump. (SOP-24.OD checklist)

SM! DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

5 IF REQUESTED SM! DISPATCHER:

ACKNOLWEDGE Tech Specs and CR that will be written and in the queue.

Farley June 2012 exam Page 9 of 12

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

WHEN REQUESTED RADSIDE:

The WHT level is in alarm.

6 NONE REQUIRED 7 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SMISSS:

I will align backup cooling to the condensate pumps.

SMISSS:

I will get someone to perform step 6 of EEP-1 ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling ROVER! SSS:

SW bus IL supply breaker DGO2-1 has an over current trip flag actuated on it.

Farley June 2012 exam Page 10 of 12

Scenario 1 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 85% power, 831 ppm, MOL, ramping down at 2 MW/mm Turnover:

1 B MDAFW pump T/O for bearing replacement. (OOS 2 days, ETR 4 hrs)

MK5, SEISMIC PANEL ALARM, actions are in progress.

Current Risk Assessment is YELLOW and projected is YELLOW due to the I B MDAFW pump

B Train On-Service B Train Protected.

Event 1 ARP for MK5 requires shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Verifiable actions: Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . RO will adjust rods or boron to control Tavg/Tref on program, BOP will place the IMP PRESS LOOP in service and set up ramp rate at 5 MW/mm and continue the ramp on the Main Turbine.

Event 2 FT485, CH IV I B SG Steam Flow transmitter, fails low. TS 3.3.2 Condition D Verifiable actions: Take manual control of I B FRV and control SGWL before a Rx trip occurs. Swap FT channels for FRV control and place the FRV back in AUTO.

Event 3 PT-445 fails high. Crew enters AOP-100. TS. 3.4.11 Condition A and 3.4.1 Condition A Verifiable actions: close PORV 445. PORV 445 discovered to be leaking by (RCS pressure continues to decrease) and PORV block valve must be closed.

Event 4 1 E SW pump trips. ARP for AE4 and AOP-1 0. TS 3.7.8 Condition B and 3.8.1 Condition B Verifiable actions: start IC SW pump.

Event 5 130 gpm RCS leak develops. AOP-1.0 entered. Leak will be large enough (approx.130 gpm) to have RO secure letdown and open LCV-1 15B/D. TS 3.4.13 Condition A Verifiable actions: Letdown will be secured. LCV-1 1 5B/D may be opened depending on if the ramp is secured or continues. Ramp may be increased if LCV-1 1 5B/D are opened.

Ctmt minipurge will be secured.

Event 6 1A MSIV closes. A reactor trip will be required.

Verifiable actions: Trip the reactor. (CT)

Event 7 When the reactor is tripped and ESP-0.1 entered, a LB LOCA occurs.

Event 8 When the SI occurs, 41 60V bus IL (SW bus) supply breaker trips. Results in loss of SW to I B DG and DG must be emergency shutdown.

Verifiable actions: Secure the I B DG in emergency shutdown mode.

Event 9 MOV-8100, HV-8I52 and HV-3376 do not close on Phase A isolation.

A Train Phase A does not work in Auto. (CT)

Verifiable actions: initiate Phase A isolation manually or close above 3 valves.

Scenario may be terminated after transition to ESP-1 .3 announced.

UOP-3.1/ MK5/ AOP-10 / AOP-100/ AOP-1 .0! GH2 / EEP-0! EEP-1/ FRP-P.1 I ESP-1 .3 Farley June 2012 exam Page 11 of 12

Scenario 1 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET 1 Actuate a manual Rx trip prior to SI (WOG CT E-0 - - A) (PRA 10.29

-

1RTOPMANRT---H)

2. Close containment isolation valves such that at least one valve is closed on each critical phase A penetration before the end of the scenario: (WOG CT E-0 - - 0)

(PRA 10.83 OCI_A_1--D---H or 10.30 ISAOPMANPHA--H)

Close M0V-8100 or MOV-81 12, HV-8152 or HV-8149A, B and C and HV 3376 or HV-3377.

A Train Phase A does not work in Auto or manual.

B Train valves listed above will not close on Phase A signal.

SCENARIO 85% power, the crew is required to ramp down to mode 3 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

OBJECTIVE!

OVERVIEW: The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-10, AOP-100, A0P-1.0 & Tech Specs

identify a LB LOCA, initiate a manual Rx Trip and manual phase A isolation or close 3 isolation valves, shutdown a EDG that has no SW supplied,

and then successfully enter EEP-1 .0 and announce transition to ESP-1 .3 Target Quantitative Attributes (Per Scenario; See Section O.5.d) Actual Attributes 1 Total malfunctions (58) 8

2. Malfunctions after EOP entry (12) 2

3. Abnormal events (24) 4

4. Major transients (12) 1

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

6. EOP contingencies requiring substantive actions (02) 0

7. Critical tasks (23) 2 Farley June 2012 exam Page 12 of 12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 1 Page 1 of 39 Event

Description:

Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

A ramp of 2 MW/mm 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/mm and ramp off line lAW UOP-3.1 in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Indications Available:

Annunciators: Other Indications:

SEISMIC PANEL ALARM (MK5) will be NONE in alarm when the crew takes shift Time Pos. Expected Actions/Behavior Comments ver 111.1 step 8.2; Decrease reactor power to minimum load for MK5 version 59.1 BOP (step 8.2 and following) 8.2.1 Verify Turbine on HOLD.

8.2.2 Check that the DEH computer point PIA, FIRST STAGE PRESSURE #1 has stable indication.

8.2.3 On the FEEDBACK STATUS DISPLAY, move the cursor to IMP PRESS LOOP OUT 8.2.4 Depress the SELECT key.

8.2.5 Verify IMP PRESS LOOP is highlighted in reverse video.

8.2.6 Depress the START key.

8.2.7 Verify FEEDBACK STATUS indicates IMP PRESS LOOP IN.

(step 8.3) Commence ramping the turbine at the desired rate.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 1 Page 2 of 39 Event

Description:

Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

I ime Pos xpectea Actionsll3ehavlor Lomments 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 5 MW! mm will be required to ramp unit off per the turnover sheet.

(step 8.4) Verify proper SGFP speed control.

- Monitor SGPF zP 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 5 the appropriate DEH controls MW/rn in.

. 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.

2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 1 Page 3 of 39 Event

Description:

Seismic event annunciator MK5 requires a reactor shutdown per UOPs to Mode 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

Time Pos. Expected Actions/Behavior Comments RO (Step 1.0) Borating per APPENDIX B Version 58

. 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 LK 112, setpoint as desired system lined up. The RO will 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 Fl-il 3 MAKEUP FLOW TO CHGNCT.

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

Boric acid flow returns to zero as displayed on Fl-il 3 MAKEUP FLOW TO CHGNCT.

MKUP TO CHG PUMP SUCTION HDR FCVI 13B closes.

BORIC ACID TO BLENDER FCV113A closes.

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

3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 2 Page 4 of 39 Event

Description:

FT-485, CH IV lB SG Steam Flow transmitter, fails LOW FT-485 will fail low. 1 B FRV will close and SG NR level will decrease.

Indications Available:

Annunciators: Recognize indications of FT-485 failing low:

- 1 B SG FEED FLOW> STM FLOW (JG2) - FT-485 fails low slowly meter slowly

-

- 1BSGLVLDEV(JF2) dropping to 0

- FRV position closing

- lB SG NR level .

Time Pos Expected Actions/Behavior Comments Section 1.5 a version 11 SRO Direct entry into AOP-1 00 and complete NOTE: Step I is an lOA step immediate operator actions RO (step 1) Maintain SG levels at 65%. NOTE: Step 1 is an Immediate IF required, THEN, take manual control of Operator Action and a SGFP speed control as necessary to restore continuing action step SG level to 65%

- SGFP master controller SK-509A OR

- SGFP individual controllers as needed.

{] SK-509B

[ J SK-509C IF required, THEN take manual control of the affected feedwater regulating valves Take manual control of 1 B

[] 1A SG FW FLOW FK-478 FRV and open to match SF

[1 1 B SG FW FLOW FK-488 and FE 1] 1 C SG FW FLOW FK-498 SRO If a loss of main feedwater occurs, then This should not result in a loss perform the actions of AOP-1 3, 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 SO level 28%

- Main Turbine and Feed Pump Trip 82% SO level 4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # I Event # 2 Page 5 of 39 Event

Description:

FT-485, CH IV lB SG Steam Flow transmitter, fails LOW (step 3) 1r a ramp is in progress, THEN Ramp will be in progress place Turbine on HOLD Expect the boration to be secured if in continuous boration.

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

Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW SIG CHIlI CHIV CHIlI CHIV A SIG Fl-474 Fl-475 Fl-477 Fl-476 B SIG Fl-484 Fl-485 Fl-487 Fl-486 FT-485 has failed low C SIG Fl-494 Fl-495 Fl-497 FI-496 Check for failed or erroneous readings on the following SG pressure indicators S/G CHII CHIlI CHIV A SIG P1-474 P1-475 P1-476 B SIG P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496 SRO/ (step 4.3) IF the alarm(s) was due to a BOP SGWLC System controlling channel failure, THEN select the unaffected channel and BOP will verify proper system verify proper system response response (step 4.3.1) Places switches FS/488Z and ALL switches mv be oleced in FS/488Y for lB SG in the Ill position: Channel Ill oosition (either way is correct)

FT-484 (STM Flow) & FT-487 (FEED Flow)

S RO (step 5) Refer to Tech Specs 3.3.2 for any LCO requirements.

T.S. 3.3.2 Condition D anolicable TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE 5

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 2 Page 6 of 39 Event

Description:

FT-485, CH IV lB SG Steam Flow transmitter, falls LOW Table 3.3.2-1 ESFAS Instrumentation Function 4e High steam flow in two steam lines coincident w/ 10-10 Tavg Applicable in Modes 1, 2 and 3 with MSIVs open required channels 2 per stm line condition D CD CONDITION REQUIRED ACTION COMPLETI a

ON TIME

0. One channel 0.1 inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

Place channel in trip.

OR 78hrs 0.2.1 Be in MODE 3.

AND S4hrs 0.2.2 Be in MODE 4.

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

S RO (step 8) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition reoort.

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

6

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 3 Page 7 of 39 Event

Description:

PT-445 fails HIGH. PORV can be closed, but leaks by; block valve must be shut.

PT-445 will fail high. The PORV will close but have significant leakby. The block valve must be closed and tech specs evaluated.

Indications Available:

Annunciators: Indications of PT-445 failing High:

- PRZR PORV TEMP HI (HA5) - P1-445 failing high

- PRZR SAFETY VLV TEMP HI (HA4) - PORV 445 indicating open

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

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

- PRZR PRESS HI-LO (HC1) - Tl-465; Tl-467; Tl-469 Code Safety

- PRT PRESS HI (HE5) Tailpiece temps I Time Pos. Expected Actions/Behavior Comments 1 , ver 11, section 1.1 SRO Direct entry into AOP-100 RO (step 1) Take manual control of the following Steps I and 2 are lOAs equipment as necessary:

- PORV 445A handswitch

- Block valve MOV-8000A

- Pzr heaters (step 2) IF pressurizer pressure is *Spray valves verified decreasing due to a mechanically stuck open functioning properly (closed) sorav valve PCV444C or PCV444D No actions required RO (step 3) If the PORV is open then close the NOTE: RNO actions PORV when RCS pressure is < 2310 psig. IF the PORV will not close, THEN perform the following:

IF pressurizer pressure is decreasing due to a Stuck open PORV, THEN close the associated PORV Block Valve.

IF PORV Block valve will not close, THEN trip the reactor and go to EEP-0.0, Reactor Trio or Safety Iniection The above RNO actions may not be done here as the leak may not be noticed at this time.

7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 3 Page 8 of 39 Event

Description:

PT-445 fails HIGH. PORV can be closed, but leaks by; block valve must be shut.

Time Pos. Expected ActionslBehavior Comments RO (step 4) IF an alarm was caused by a Closes block valve MOV CONTROL instrument (P1-444/445) OR 8000A component failure, THEN perform the following as required to restore RCS pressure to desired value.

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

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

RO (step 6) References required Technical Specifications:

3.4.1 for DNBR limits RCS pressure < 2209 psig CONDITION A 3.4.11 for PORVs Conditions A TECHNICAL SPECIFICATION 34.1, 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 ta method, and the limit specified in the COLR SRO CONDITION REQUIRED ACTION COMPLETIO N TIME A. One or A. I Restore RCS ONB more RCS parameter(s) to within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNB limit.

parameters not within limits.

TECHNICAL SPECIFICATION 3.4.11, Pressurizer Power Operated Relief Valves (PORVs)

Each PORV and associated block valve shall be OPERABLE SRO CONDITION REQUIRED ACTION COMPLETIO N TIME A. One or A. I Close and maintain 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months more PORVs power to associated inoperable block valve.

and capable of being manually cycled.

SRO (step 7) Notify the Shift Manager 8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 3 Page 9 of 39 Event

Description:

PT-445 fails HIGH. PORV can be closed, but leaks by; block valve must be shut.

Time Pos. Expected ActionslBehavior Comments SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition reoort.

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

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

. Refer to SOP-0.0, VERSION 149.1; General Instructions To Operations SECTION 30 Personnel, for reporting Requirements.

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

9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 4 Page 10 of 39 Event

Description:

IE SW pump trips.

1E SW pump will trip. SW pressure will lower but remain operable. IC SW pump is available to start and then tech specs evaluated.

Indications Available:

Annunciators: Recognize indications 1 E SW PUMP TRIP

- SW PRESS A TRN LO (AD4) - Yellow flag above I E SW pump handswitch

- SW PRESS B TRN LO (AD5) - Pl-3001A/B SW TO CCW HX PRESS,

- SW PUMP TRIPPED (AE4) reading low

- SW TO AUX BLDG HDR PRESS A OR B TRN_LO_(AE5)

Time Pos Expected Actins/Behaviór comments ersio,A BOP Announce alarm and enter ARP-AE4 SRO Direct entry into ARP BOP (step 1) Check Indications and determine 1 E SW pump has a yellow trip which SW oumo trioed flaa BOP (step 2) Start the IC SW oumi SRO (step 3) REFER to AOP-1O. version 16. if entered actions listed below S RO (step 4) Direct SSS entry into SOP-24.0 step 4.6 to align 1C SW pump for auto start to replace the 1 E SW pump BOP (step 5) Dispatch personnel to the 1 E SW Sends SSS and Outside SO pump and breaker DLO4, 1 E SW PUMP 4160V BREAKER version 16 BOP (step 1) Verify DFO2, iF 4160 V bus tie to 1K 4160 V bus and DGO2, 1G 4160 V bus tie to 1 L 4160 V bus, are closed BOP (step 2) Start any available SW pump BOP (step 3) Check pressure in both SW trains

>60 psig, then go to procedure and step in affect.

10

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 1 Event# 4 Page 11 of 39 Event

Description:

IE SW pump trips.

Time Pos. Expected Actions/Behavior Comments SRO (step 7 of ARP AE4) Refer to tech spec 3.7.8 for LCO requirements TECHNICAL SPECIFICATION 31.8 - Service Water System (SWS)

Two SWS trains shall be OPERABLE.

SRO 3.7.8 Condition A applies due to the IE SW pump being tripped and the IC SW pump not being selected to auto start for the IE SW pump CONDITION REQUIRED COMPLETION ACTION TIME A. OneSWS A.l-NOTES 72days train inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, AC Sources Operating, for emergency DG made inoperable by SWS.

Restore SWS train to OPERABLE status.

TECHNICAL SPECIFICATION 3.8.13 AC SourcesOperating SRO From 3. 7.8 Condition A above, 3.8.1 has to be entered. Condition B applies.

SRO CONDITION REQUIRED COMPLETION ACTION TIME 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 4 Page 12 of 39 Event

Description:

IE SW pump trips.

Time Pos. Expec ed ActionslBe avior Comments B. One DG set 8.1 Perform SR 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months inoperable 3.8.1.1 for the AND The bolded conditions are required offsite Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months circuit(s). Thereafter the most likely path the AND SRO will evoke.

8.2 Declare 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from B.1 and B.2 and B.3.1 required discovery of feature(s) Condition B supported by concurrent with the inoperable inoperability of DG set redundant required inoperable feature(s) when its required redundant feature(s) is inoperable AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months B.3.1 Determine OPERABLE DG set is not inoperable due to common cause failure.

OR 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 8.3.2 Perform SR 3.8.1.6 for OPERABLE DG set.

AND 10 days 8.4 Restore DG AND 13 days from set to discovery of failure OPERABLE to meet LCO status SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry After rech Spec analysis and at the discretion of the Lead Examiner move to Event #5.

12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 5 Page 13 of 39 Event

Description:

130 gpm RCS leak develops A 130 gpm RCS leak will develop over 2 minutes. This will cause entry into AOP-1.0 and take subsequent actions. Tech Spec evaluation is not needed or required and can be asked on follow-up if desired.

Indications Available:

Annunciators: Indications of an RCS leak:

- CHG HDR FLOW HI-LO (EA2) - Li-112B and 115, VCT LVL, decreasing

- RMS HI RAD (FH1) - Fl-122, CHG FLOW increasing

- LT-459, PRZR LEVEL, decreasing Time Pos. Expected Actions/Behavior Comments ver. 20.0 SRO Directs performance of ARPs

- EA2, CHG HDR FLOW HI-LO

- FHI, RMS HI RAD (R-2, 7, & 12: CTMT radiation alarms in)

BOP Closes minipurge supply and exhaust fan Per FH1 if R-11 or 12 is in dampers and stops the ctmt minipurge fans. alarm RO Reports pressurizer level is dropping with charging maximum.

Should diagnose and announce RCS leak.

SRO Directs entry into AOP-1 and directs actions per RO & BOP rows below:

RO (step 1) Maintain pressurizer level stable at NOTE: This is a continuing or near programmed level by: action step Control charging flow: Take manual control of OR charging flow Reduce letdown flow OR remove 1 orifice Isolating letdown remove all orifices 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 5 Page 14 of 39 Event

Description:

130 gpm RCS leak develops (step 2) Maintain VCT level > 20% . -

i t- s is a continuing action step Ensures Reactor makeup is in AUTOMATIC to maintain VCT level> NOTE: RMUW status is 20% dependent upon previous actions RNO- if VCT level cannot be maintained QI E21 LCVI I 5B open QIE2ILCV1I5D open

>20%, then align chg pump suctions to RWST TO CHG PUMP MOVS RWST and Q1E21LCVII5C closed QI E21 LCV1 1 5E closed VCT OUTLET ISO MOVS RO (step 3) Determine leak rate based on flow balance flow)

+ (seal injection flow)

- (letdown flow)

- (#1 seal leakoff flow)

= (RCS leak rate)

SRO (step 4) Leak rate should be determined to NOTE: This is a continuing be gieater than 120 gpm. action step

- Tech Spec 3.4.13 should be evaluated> I LCO 3.4.13 Cond. A identified gpm unidentified leakage. as a MANDATORY LCO.

SRO (step 5) Informs Shift Manager of Leak rate NOTE: This is a continuing for classification and notification per EIP-8 & action step ElP9.0

- need for CTMT entry to look for leak source

- T.S. requires fix leak in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or shutdown in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months LCO 3.4.13 Cond. A is a MANDATORYLCO This is classified as unidentified leakage TECHNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKA GE shall be limited to:

a. No pressure boundary LEAKAGE;

b. I gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; 14

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 5 Page 15 of 39 Event

Description:

130 gpm RCS leak develops SRO CONDITION REQUIRED ACTION COMPLETION TIME A. RCS A. I Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months operational within limits.

LEAKAGE not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

WHEN letdown is secured, LCV-115B and D opened and the ramp is either restarted or ramp rate increased and under control, THEN at the discretion of the Lead Examiner move to Event #6.

15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 1 Event # 6 Page 16 of 39 Event

Description:

IA MSIV fails closed, No auto Reactor trip IA MSIV will close causing a Main Turbine trip, A Reactor trip will be required. If an SI occurs at this step the LB LOCA will be put in immediately.

Indications Available:

Annunciators: Indications:

- RX TRIP CAUSED BY TURB TRIP (GF4) - Secondary Valve Indication Panel

- TURB AUTO STOP OIL TURB TRIP (GH2) - MS ISO 3369A CLOSED indication

- DEH screen GVs and TVs closed Pos. Expected ActionslBehavior Comments

, ver 33 SRO Direct actions required by GH2 NOTE: The auto Rx trip is

. Direct a reactor trip based on blocked This is a CRITICAL indications TASK to TRIP the reactor when parameters call for a reactor trip RO Place RX TRIP ACTUATION handswitch to the TRIP position.

SRO Direct operators to perform the lOAs of EEP-O RO! Immediate Operator actions of EEP-O Immediate Action steps of BOP (step 1) Check reactor trip. EEP-O Check all reactor trip breakers and reactor NOTE: Reactor will trip trip bypass breakers OPEN.

- automatically if setpoint Check nuclear power FALLING.

- reached.

check rod bottom licihts LIT

-

16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # I Event # 6 Page 17 of 39 Event

Description:

IA MSIV fails closed, No auto Reactor trip Pos. Expected ActionsIBehavoi Comments (step 2) Check turbine TRIPPED.

-

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

4160 V ESF busses AT LEAST ONE

-

ENERGIZED A Train (F 41 60V bus) power available lights NOTE: NO DGs will be running lit at this point if manual safety OR injection has not been initiated.

B Train (G 4160V bus) power available lights lit Verify operating diesel generators are being supplied from at least one SW pump.

(step 4) Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[1 ACTUATED status light lit

[] MLB-1 1-1 lit 1] MLB1 1 11 lit The Large Break LOCA will occur when ESP-0.1 is entered and at the discretion of the Lead Exam ner.

ver32 RO (step 1) Check RCS temperature NOTE: this is a continuing

- Stable at or approaching 547°F action step

- TAVG IA(IB,1C) RCS LOOP

[] TI 412D

[] TI 422D STM DUMP

[]_TI_432D BOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step status.

- Verify FRV5 closed

- Defeat the MADFWP auto start on SGFP trip 17

Appendix D Operator Action Form ES-D-2 Op Test No: FA2O1 2301 Scenario # 1 Event # 6 Page 18 of 39 Event

Description:

IA MSIV fais closed, No auto Reactor trip Pos. Expected ActionslBehavior Comments BOP (step 2.2) - MDAFWP AUTO/DEFEAT - Verify BOTH SGFPs fl IA in DEFEAT tripped

[1 1 B in DEFEAT - Verify total AFW flow to the SGs >395 gpm RO (step 3) Verify ALL RX TRIP breakers OPEN RO (step 4) Check emergency Boration not required

- All rods FULLY INSERTED

- RCSTavg>525°F BOP (step 5) Announce Unit 1 Reactor Trip 18

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 19 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

The Large Break LOCA will come in after the 1A MSIV closes. The crew will see RCS pressure decreasing. When the safety injection occurs, DGO2-1 for the IL 4160V bus will trip open. This will result in a loss of SW to the lB DG and it will require an emergency shutdown.

A Train Phase A will not work and 3 isolation valves on B Train will not close so the BOP will have to isolate ctmt.

Indications Available:

Annunciators: Indications of LB LOCA Various and numerous - Pzr level

- RCS pressure

- Radiation monitor (R-217/1 1/12)

Time, I Pos. Expected ActionslBehavior Comments

,rev43 RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.-

Check nuclear power FALLING.

-

Check rod bottom lights LIT. -

(step 2) Check turbine TRIPPED.-

TSLB2 14-1 thru 4 lit NOTE: 3 DGs will be running (step 3) Check power to 4160 V ESF when the SI is initiated busses. manually.

4160 V ESF busses AT LEAST ONE

- OATC will check SW header ENERGIZED pressure, ctmt cooler flows and CCW Hx SW flows and SW A Train (F 41 60V bus) power available lights pump lights.

lit OR For this event 41 60V bus IL B Train (G 4160V bus) power available lights de-energizes due to a lit tripped breaker and the RNO column used to shut down Verify operating diesel generators are being the I B DG per Attachment I supplied from at least one SW pump.

Attachment I SECURING A DIESEL GENERATOR WITH A SAFETY INJECTION SIGNAL PRESENT (step 1.1) Verify SI reset NOTE: Since the SI just came

[] MLB-1 1-1 not lit in this takes 60 seconds before

[1 MLB-1 1 1-1 not lit it will reset 19

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 20 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments (step 1.2) Place the 1 B DG MODE SELECTOR SWITCH to MODE 2.

(step 1 .3) Depress the I B DG DIESEL EMERG START RESET pushbutton.

(step 1.4) Depress the 1 B DG STOP pushbutton.

[1 DIESEL STOP light lit (step 1.5) Place the 1 B DG MODE SELECTOR SWITCH to MODE 3.

(step 1.6) Depress the 1 B DG DIESEL EMERG START RESET oushbutton.

Resume EEP-O actions RO! (step 4) Check SI Status. SINCE this is a return to BOP Check any SI actuated indication. EEP-O, FRP-P.1 will be BYP & PERMISSIVE SAFETY INJECTION applicable and the transition

[1 ACTUATED status light lit should be made upon

[] MLB-1 1-1 lit recognition of a RED CSFST.

[] MLB-1 11-1 lit See page 25 for FRP-P.1 SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to perform [IFI1LI T1XK Attachment 2 starting on En Attachment 2. nacie 31 below (step 6) Check containment pressure- HAS NOTE: [CA] step For a LB RO REMAINED LESS THAN 27 psig LOCA ctmt pressure will rise

>27 psig RO (step 6.1 RNO) Verify Phase B CTMT ISOL MLB-3 1-1 and 6-1 will be LIT

- ACTUATED

[] MLB-3 1-1 lit

[1 MLB-3 6-1 lit RO (step 6.2) Stop all RCPs. Secures ALL RCPs RCP

[j IA

[] 1 B

[1 1 C 20

Op Test No.: FA201 2301 Scenario # 1 Event # 7-9 Page 21 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos. ExpectédActionslBéhavior Comments RO (step 6.3) Verify PHASE B CTMT ISO alignment. All MLB-3 lights will be LIT (step 6.3.1) Check All MLB-3 lights lit.

IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.

RO (step 6.4.1) Check containment spray flow in Both CS pumps will be running both trains greater than 0 gpm. and flow will be >0 gpm CS FLOW

[1 Fl 958A

[1 Fl 958B RO (step 7) Announce Unit I reactor trip and safety injection RO (step 8) Check AFW status.

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

[1 Fl 3229A

[1 Fl 3229B

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

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

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

21

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 22 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments RD (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

[1 B TRN reset MDAFWP TO lA/lB/iC SG B TRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[1 RESET reset TDAFWP SPEED CONT

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

IF no RCP running, THEN check RCS cold leg temperature STABLE AT OR

-

APPROACHING 547°F.

RCS COLD LEG TEMP RECORDER F] TI 410 22

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 23 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior 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

[]ATRN in OFF RESET

[1 B TRN in OFF RESET (step 9.1 .2) Verify atmospheric reliefs closed on MCB

[1 Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO IA(1B,1C)SG fi Fl 3229A fl Fl 3229B

[1 Fl 3229C AFW TOTAL FLOW

[] Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.6. accomplish this task 23

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 24 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

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

WHEN pressurizer pressure less than 2335 NOTE: [CA] step psig, THEN verify both PRZR PORVs closed.

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

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

[] PRT PRESS P1 472

[1 PRT LVL Ll-470

[1 PRT TEMP Tl-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing. NOTE* CA S ep I A(1 B) LOOP SPRAY VLV

[]PK444C

[]PK444D Check any PRZR PORV ISO OPEN -

RO (step 11) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45F}

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

Control charging pump miniflow valves 1300 psig.

based on RCS pressure.

IC(1A) LOOP RCS WR PRESS

[] P1 402A

[J P1 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.

[] Check no SG pressure FALLING IN AN

UNCONTROLLED MANNER OR LESS THAN 50 psig.

24

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 25 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos. Exoected Actions/Behavior Comments SRO (step 14) Check SGs not ruptured.

[1 Check secondary radiation indication -

NORMAL.

[] Checks rad monitors R-15, 19, 23A and B, 1 5B and C, and 60 A, B, C, D

[1 No SG level rising in an uncontrolled manner.

SRO (step 15) Check RCS intact. NOTE: Phase B Ctmt isolation Check containment radiation -

signal will be in and transition

[] R-2 CTMT 155 ft to EEP-1 .0 required

[] R-7 SEAL TABLE

[1 R-27A CTMT HIGH RANGE (BOP)

[] R-27B CTMT HIGH RANGE (BOP)

Trnifin to EEP-1.O U Check containment pressure LESS THAN 3 psig.

[] Check containment ECCS sump level LESS THAN 0.4 ft.

I SRO Direct entry into FRP-P.1 RO Check RCS pressure > 435 psig RNO CHECK RHR FLOW

-

1C(1A) LOOP RCS NR PRESS >1500 gpm

[1 P1 402B If yes U P1 403B then return to EEP-1 .0 Rev 30 RO (step 1) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR RCPs will already be secured indication GREATER THAN 16F{45F}

-

SUBCOOLED IN CETC MODE.

BOP (step 2) Check SOs not faulted.

Check no SG pressure FALLING IN AN

UNCONTROLLED MANNER OR LESS THAN 50 psig.

25

Op Test NoW: FA2012301 Scenario # 1 Event # 7-9 Page 26 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments BOP (step 3) Check intact SG levels.

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

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

Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[1 A TRN reset

[j B TRN reset MDAFWP TO IN1 B/iC SG B TRN

[1 FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[] RESET reset TDAFWP SPEED CONT

[1 SIC 3405 adjusted BOP (step 4) Check secondary radiation [} R-15 indication NORMAL.

-

[] 19 Checks rad monitors [] 23A and B

[] 15B and C, 1 60A,B,C,D RO (step 5) Check pressurizer PORVs Check any PRZR PORV ISO power available NOTE: [CA] step WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.

[] Verify both PRZR PORVs CLOSED

Check PRZR PORV temperature STABLE OR FALLING.

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

[j PRT PRESS P1 472

[] PRT LVL Ll-470

[1 PRT TEMP Tl-471

[j Check at least one PRZR PORV ISO -

OPEN 26

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 27 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments SRO (step 6) Perform the following within I NOTE: These steps will be hour of start of event, passed off to the Shift

[] Close recirculation valve disconnects using Manager ATTACHMENT 1.

[] Establish 1 A and 1 B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.

[] Plot hydrogen concentration on FIGURE 1.

Check containment hydrogen concentration

[} LESS THAN 3.5%.

fl Less than 0.5%

SRO (step 7) Evaluate SI termination criteria

[] Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}

SUBCOOLED IN CETC MODE.

Check secondary heat sink available.

[] >395 gpm AFW flow OR

[]> 31%{48%} SGNR level

[1 Check RCS pressure STABLE OR

-

RISING

[1 Check pressurizer level GREATER THAN I 3%{43%}.

Continue to stei 8 since a known LOCA exists RO (step 8) Check containment spray system. NOTE: [CA] step Check any CS PUMP STARTED.

-

Reset containment spray signals.

CS RESET

[] A TRN

[] B TRN NOTE: [CA] step WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , AND containment pressure is less than 16 psig, THEN stop both CS PU M Ps.

27

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 28 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments RO (step 9) Check if LHSI Pumps should be NOTE: [CA] step stopped. RCS pressure will be < 435

- Check RCS pressure GREATER psig THAN 275 psig{435 psig}

[] PT-402 AND 403 (step 9.1.1 RNO) Establish CCW flow to RHR Hxs CCW TO IA(IB) RHR HX

[] QIPI7MOV3185A open

[] QIP17MOV3185B open BOP (step 10) Check no SG pressure FALLING -

IN AN UNCONTROLLED MANNER.

RO (step 11) Check RCS pressure LB LOCA U PT-402 AND 403 If oressure is risina then return to steu I Perform Attachment 4 to Verify 4160 V I iusses energized.

BOP (step 12) Attachment 4 Check DFO1 closed YES Verify DFO2 closed - YES Check DG15 closed - YES Verfiy DGO2 closed - YES Verify all RCP busses - ENERGIZED.

[] 1A4160 V bus- YES

[] 1B4160V bus- YES

[] 1C 4160 V bus- YES Check 1 E 41 60V busENERGIZED-YES Check 1D 4160V bus- ENERGIZED-YES BOP (step 13) Check diesel generators. NOTE: [CA] step Monitor any loaded diesel generator for NOTE: Securing unloaded proper voltage, frequency and load. DGS will be accomplished by the extra operator or the BOP Secure any unloaded diesel generators using if time permits. This is FNP-0-SOP-38.0, DIESEL GENERATORS. generally not the case and the DGs will continue to run.

28

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 29 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos Expected ActionslBehavior Comments SRO (step 14) eain øuIiifinr of Dlant NOTE: This is Foldout page Verify cold leg recirculation capability - criteria as well AVAILABLE.

Train A equipment available:

[1 1A RHR Pump

[1 CTMT SUMP TO IA RHR PUMP QI El 1 M0V881 1A

[1 CTMT SUMP TO 1A RHR PUMP QIE1 1MOV8812A

[1 IA RHR HX TO CHG PUMP SUCT Q1E11MOV87O6A

[1 CCWTO1ARHRHX QI P1 7MOV31 85A OR Train B equipment available:

[1 lB RHR Pump

[1 CTMT SUMP TO I B RHR PUMP Q1E11MOV88IIB

[1 CTMT SUMP TO 1 B RHR PUMP Ql Eli MOV88 128

[118 RHRHXTOCHG PUMP SUCT QI El I MOV87O6B

[] CCWTO1BRHRHX Ql P17MOV31858 SRO (step 14.2) Direct extra operator to begin taking ECCS logs.

SRO (step 14.2) Evaluate RCS sampling Notifies SM requirements.

Consult TSC staff to evaluate need for RCS sampling.

IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-O-CCP-l 300, CHEMISTRY AND ENVI RONMENTAL ACTIVITI ES DURING A RADIOLOGICAL ACCIDENT SRO (step 14.4) Check no intersystem LOCA [] R-3 RADIOCHEMISTRY BOP outside CTMT. LAB

[1 Check auxiliary building radiation - [] R-4 1C CHG PUMP RM NORMAL. [1 R-5 SFP RM

[1 R-6 SAMPLE RM AREA

[1 R-8 DRUMMING STATION

[] R-l0 PRF

[] R-17A OR R-17B CCW 29

Op Test No.: FA2012301 Scenario # 1 Event # 7-9 Page 30 of 39 Event

Description:

Large Break LOCA, 4160V bus IL trips and Phase A on A Train does not work.

Time Pos. Expected ActionslBehavior Comments BOP [] Check auxiliary building room sumps HI - (on the BOP)

LVL ALARMS CLEAR AND NO SUMP PUMPS RUNNING IN AUTO.

Will call Radside SO

[j Check WHT and FDT levels -

NO EXCESSIVE OR UNEXPLAINED LEVEL RISE.

RO Check PI600A(B) 1A(1B) RHR PUMP DISCH PRESS LESS THAN 450 osia.

BOP (step 14.5) Verify at least one train of PRF in operation using FNP-1-SOP-60.0, PENETRATION ROOM FILTRATION SYSTEM.

RO (step 14.6) Verify VCT level GREATER THAN 5%.

RO (step 15) Check LHSI flow in progress RCS pressure will be <435 Check RCS pressure LESS THAN

- psig 275 psig {435 psig}.

1C(1A) LOOP RCS NR PRESS

[1 P1 402B

[1 P1 403B Verify both LHSI flows GREATER

- LHSI flows will be> 1500 THAN 1.5x10 3 gpm. gpm 1A(1B) RHR HDR FLOW

[1 Fl 605A

[1 Fl 605B RO (step 16) Check when to transfer to cold leg recirculation.

Check RWST level - LESS THAN 12.5 feet SRO Direct transition to FNP-1-ESP-1 .3, TRANS FER TO COLD LEG RECIRCULATION.

When the decision to transfer to ESP-1 .3 announced, then terminate the exam.

30

Op Test No.: FA2012301 Scenario # 1 Event # 7 Page 31 of 39 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-O Attachment 2 of EEP-O AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected ActinsiBehviór Corn ments (Step 1) Verify one CHG PUMP in each train STARTED.

-

BOP fl A train (1A or 1 B) amps> 0

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

-

RHR PUMP

[1 1A amps > 0 Ii lB amps > 0 BOP (Step 3) Verify Safety Injection Flow.

(Step 3.1) Check HHSI flow GREATER

-

THAN 0 gpm.

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

THAN 275 psiq{435 psig).

BOP (step 3.3) Check LHSI flow greater than

1.5 XlO gpm 3

[1 1A RHR HDR FLOW Fl-605A

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

[jAtrain (1A,1B or 1C)

[1 B train (ID,1E or IC) 31

Op Test No.: FA2012301 Scenario # I Event # 7 Page 32 of 39 Event

Description:

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

STARTED.

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

A train HX 1 C or 1 B CCW FLOW

[jFI 3043CA>Ogpm OR

[j Fl 3043BA> 0 gpm B train HX IA or lB CCW FLOW

[] Fl 3043AA>Ogpm OR

[1 Fl 3043BA> 0 gpm Verify SW flow to associated CCW HXs SW FROM IA(1B, 1C)CCW HX fl QIPI6FI3009AA> 0 gpm

[] QIPI6FI3009BA> 0 gpm

[1 QIPI6FI3009CA> 0 cgm (Step 5.3) Check instrument air available.

Verify at least one air compressor started.

AIR COMPRESSOR

[] 1A

[] I B

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

32

Op Test No.: FA2012301 Scenario # 1 Event # 7 Page 33 of 39 Event

Description:

Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197 U 3198D

[j 31980

[] 3196

[1 3198A

[1 31988 Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 28670 FULL-3198A& 3198D

[1 28660 fl 28670 CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 31980

[] 2866D

[j 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

-

CTMT CLR FAN SI OW SPEED Atrain

[j1A

[] 1 B B train

[1 1 C

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

-

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

[] Q1P16MOV3O24A

[1 Q1P16MOV3O24B U Q1P16MOV3O24C

[1 Q1P16MOV3O24D 33

Op Test No.: FA2012301 Scenario # 1 Event # 7 Page 34 of 39 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (step 8) Verify AFW Pumps STARTED.

-

Verify both MDAFW Pumps STARTED-

[] IA MDAFW Pump amps> 0

[1 18 MDAFW Pump amps> 0 AND

[J Fl-3229A indicates > 0 gpm

[J FI-3229B indicates> 0 gpm

[1 FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

LJTSLB U Setooint UI Coincidence L RCP Bus TSLB2 1-1 U12680 V 1/2 Detectors JndoItci 1-2 1-3 on 2/3 Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-1 ,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3 BOP (step &3) Verify TDAFWP started.

[1 MLB-4 1-3 lit

[1 MLB-4 2-3 lit

[1 MLB-4 3-3 lit TDAFWP SPEED fl SI 3411A> 3900 rpm TDAFWP SPEED CONT

[1 SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWP TO 1A(1B,1C) SG

[1 Qi N23HV3228A in MOD

[1 Qi N23HV3228B in MOD

[1 Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT

[1 HIC 3228AA open

[1 HIC 3228BA open I] HIC 3228CA oren 34

Op Test No.: FA2O1 2301 Scenario # 1 Event# 7 Page 35 of 39 Event

Description:

Attachment 2 of EEP-O Tinie Pos. Expected ActionslBehavior comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

-

IA(1B,1C) SG FW FLOW

[jFCV478

[1 FCV 488

[1 FCV 498 Verify both SGFPs TRIPPED.

-

Verify SG blowdown ISOLATED.

-

1A(1B,1C) SGBD ISO

[1 Q1G24HV7614A closed

[1 Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,1C) SGBD SAMPLE STEAM GEN ISO

[1 MLB1 19-2 lit Q1P15HV3328 closed

[1 MLB1 19-3 lit Q1P15HV3329 closed

[1 MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psi 9 2/3 TSLB4 19-2,3,4 1,4 Hi stm flow >40% on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543F 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. RNO (Step 11.1) Verify PHASE A CTMT ISO - Step 11.2 Verify PHASE A ACTUATED. CTMT ISO alignment using BOP [] MLB-2 1-1 lit ATTACH 3, PHASE A CTMT fl MLB-2 11-1 lit ISO CRITICAL TASK: to actuate 1 1.2 Check all MLB-2 lights - LIT. A Train phase A or close MOV-8100, HV-8152 and HV 3376 35

Op Test No.: FA2012301 Scenario # 1 Event # 7 Page 36 of 39 Event

Description:

Attachment 2 of EEP-0 Time Pos.

Expected ActiohslBéhavir 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.

IA(1B) MG SET SUPP BKR

[j N1C11EOO5A

[] NICI1EOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[] 1A

[] lB Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[hA

[1 1 B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO Actions Following A Reactor Trip Or accomplish this.

Safety Injection.

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

CRACS Mode Selector Switch

[IATRAIN

[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR

[] 810- OPEN

[] 914- OPEN 36

Op Test No.: FA2012301 Scenario # 1 Event# 7 Page 37 of 39 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.

End of Attachment 2 37

Op Test No.: FA2O1 2301 Scenario # 1 Event # 7 Page 38 of 39 Event

Description:

Attachment 4 of EEP-O Tame I Pos I Expected ActaonslBehavior I Comments Attachment 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.

[] Check DFO1 closed

[] Verify DFO2 closed

[] Check DG15 closed

[j Verfiy DGO2 closed

[j Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.

fl Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.

-

CHG PUMP DISCH HDR ISO

[] QIE2IMOV8132A

[] QIE2IMOV8I32B

[1 QIE2IMOV8133A

[j QIE2IMOV8I33B CHG PUMP SUCTION HDR ISO

[] Q1E21MOV8I3OA

[] QIE21MOV813OB

[1 QIE21MOV8I3IA

[] QIE2IMOV8I3IB (Step 1 .7) Verify all post accident containment air mixing system fans STARTED. (BOP)

-

POST ACCIDENT MIXING FAN

[j IA

[j I B

[] 1 C

[] I D RX CAV H2 DILUTION FAN

[1 IA

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

38

Op Test No.: FA2012301 Scenario # 1 Event # 7 Page 39 of 39 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 39

Appendix D Crew Briefln sheet Form ES-D-2 Op-Test No.: FA2012-301 Page 1 of 4 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

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

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

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

Assign operating positions.

Ask for and answer questions.

Appendix D Turnover sheet Form ES-D-2

[X]Unitl [ lUnit2 Shift: Date Off-going SS Oncoming SS j [ ]N [ X] D I Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.

Security Keys A, 5, D, SW, X on key ring. SS Unit 85% power, 831 ppm Cb, MOL, 10,000 MWD/MTU Status Xenon is buHding in. Ramp is on HOLD to place the IMP PRESS LOOP in service per step 8.2 of UOP-3.1.

STPs/Evolutions: B Train On-Service B Train Protected 1.0; 109.1 Noadj.; 63.7; FSP-20,0 Status of Special Testing

1. MK5 is in alarm. A ramp was in progress at 2 MW/mm. Increase the ramp rate to 5 MW/mm to be in mode 3 in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months per the direction of the Shift Manaqer.

2. The makeup line has water in it.

3. The crew is in UOP-3.1, ver 111.1, at step 8.2. The Impulse Loop is NOT in service.

4. The seismic printout has been obtained and an ALERT classification has been declared. Emergency callout has just been performed. MK5 actions are in progress. The plant walk downs are complete and no equipment damage has been discovered.

5. 1 B MDAFW umo T/O for bearina reolacement. (OOS 2 days. ETR 4 hr&)

6. Current Risk Assessment is YELLOW and projected is YELLOW due to the 18 MDAFW pump.

7.

8.

9.

Equipment Status Maintain VCT cias oressure 25-30 osici Reactivity Plan Waste Manager ent Status Last shift was oerforminci:

.

I I

3 RHT On Service

10 ciallon borations as needed durina the ramo.

100 gallon dilutions while stable. WGS secured LCO Status 3.7.5 Condition B Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over

{XjYes [XjYes [X]Yes {X]Yes [X]Yes [X]Yes

RESPONSE SPECTRA ANALYSIS FOR SAA-3 RECORDER A (S/N 31281) EVENT A00 1 EVENT DATE: 6IDD/2012 HH:MM:SS, FREEFIELD SELECTED EXCEEDANCE CRITERIA: OBE SV, CAV and OBE PSA SPECTRA CHANNEL I: L=S Computed CAV = 0.0 17 g-s, CAV Design Limit = 0.000 g-s CAV EXCEEDED***

OBE Limit Value 0.050 g, OBE SV Limit = 0.081 mIs. Damping = 0.050

=

Spectral acceleration exceeded OBE design criteria at 6 periods Spectral acceleration greater than 2/3 OBE design criteria at I periods Spectral velocity exceeded OBE design criteria at 0 periods.

CHANNEL 2: V=UP Computed CAV = 0.0 10 g-s, CAV Design Limit = 0.000 g- s CAV EXCEEDED***

OBE Limit Value = 0.033 g, OBE SV Limit = 0.054mIs. Damping = 0.050 Spectral acceleration exceeded OBE design criteria at 7 periods Spectral acceleration greater than 2/3 OBE design criteria at 1 periods Spectral velocity exceeded OBE design criteria at 0 periods CHANNEL 3: T=W Computed CAV = 0.0 16 g-s, CAV Design Limit = 0.000 g-s CAV EXCEEDED***

OBE Limit Value = 0.050 g, OBE SV Limit 0.08 1 mIs, Damping = 0.050 Spectral acceleration exceeded OBE design criteria at 9 periods Spectral acceleration greater than 2/3 OBE design criteria at 1 periods Spectral velocity exceeded OBE design criteria at 0 periods

OBE CRITERIA HAS BEEN EXCEEDED *

Both CAV & at least one of OBE response spectral *

acceleration or spectral velocity criteria must be *

exceeded to trigger OBE alarm. *

Snectral Acceleration Design Values vs. Measured Values (units=g)

indicates OBE design exceeded, + indicates >2/3 OBE design value Period Ch. 1 Ch. 2 Ch. 3 Ch. 4 (sec) Design Meas. Design Meas. Design Meas. Unused 0.030 0.050 Q773* 0.033 0.583* 0.050 0.963*

0.033 0.050 0.689* 0.033 0.461* 0.050 0.792*

0.040 0.050 0.289* 0.033 0.357* 0.050 Q*334*

0.050 0.050 0.279* 0.033 0.267* 0.050 Q475*

0.067 0.050 0.190* 0.033 0.164* 0.050 0.343*

0.083 0.053 0.138* 0.033 0.116* 0.053 0.248*

0.100 0.060 0.525* 0.044 0.210* 0.065 Q*435*

0.125 0.085 0.471* 0.057 0.138* 0.085 0.343*

0.150 0.105 0.664* 0.070 0.088* 0.105 0.419*

0.200 0.105 0.606* 0.070 0.055+ 0.105 0.384*

0.250 0.105 0.753* 0.070 0.034 0.105 0.412*

0.333 0.105 Q73Q* 0.070 0.017 0.105 Q435*

0.400 0.105 0.462* 0.070 0.018 0.105 0.277*

0.500 0.105 0.202* 0.070 0.008 0.105 0.137*

0.667 0.080 0.233* 0.054 0.004 0.080 0.172*

0.800 0.065 0.192* 0.044 0.004 0.065 0.124*

1.000 0.052 0.000 0.035 0.003 0.052 0.069*

SDectral Velocity OBE Design Values vs. Calculated Values (units = m/s)

indicates DEE design exceeded Period Ch. 1 Cli. 2 Cli. 3 Cli. 4 (sec) Design Design Design Meas. Unused Meas. Meas.

0.500 0.081 0.032 0.054 0.019 0.081 0.044 0.540 0.081 0.036 0.054 0.017 0.081 0.043 0.583 0.081 0.037 0.054 0.016 0.081 0.043 0.630 0.081 0.035 0.054 0.017 0.081 0.044 0.680 0.081 0.031 0.054 0.019 0.081 0.046 0.735 0.081 0.026 0.054 0.022 0.081 0.048 0.794 0.081 0.021 0.054 0.025 0.081 0.051 0.857 0.081 0.017 0.054 0.027 0.081 0.053 0.926 0.081 0.019 0.054 0.029 0.081 0.055 1.000 0.081 0.024 0.054 0.030 0.081 0.055

Scenario #2 FA2012301 Southern Nuclear JM Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #2 Make sure rods are in manual Look at temp and make sure it is high vs Tavg/Tref Validation time: 114 minutes Validated by David Shipman, Todd Smith and Doug Jimmerson The week of February 13, 2012 TRN Supervisor Approval: Gary Ohmstede Date: 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTHERN OMPANV

Appendix D Scenario #2 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 2 Op-Test No.: 2012-301 Examiners: Operators: SRO RO BOP Initial Conditions: 57% power, 1109 ppm, MOL, ramping up, ready to place the lB SGFP on service. (IC-51)

Turnover:

1 ..2A DG TIO for governor wjOS 2 days, ETR 4 iiL

Current Risk Assessment is and projected is

A Train On-Service A Train Protected.

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

1 N (BOP) Place the I B SGFP on service.

R (RO) Ramp up 5% reactor power. (if desired) 2 lmf I (RO) LT-459, pressurizer level, fails LOW, letdown secures.

1t459 TS (SRO) TS 3.3.1 Condition M N (RO) Restore Letdown and charging to normal.

cP405 I (BOP) Hydrogen Temperature controller, CP-4055K fails LOW.

5K-A 4 lmf I (RO) LT-1 15, VCT level controller, fails HIGH.

1t115 5 mt I (BOP) FT-495, selected steam Flow Transmitter for 1C SG fails HIGH.

ft495 TS (SRO) Tech Spec 3.3.2. Condition 0 6 lmf Loss of BOTH SGFPs 1A SGFP controller failure, SK-509B fails HIGH, manual control is available; No ramp down required due to power level. Regain control of SGWL.

Trgl M (ALL) lB SGFP trips 120 seconds after 1A SGFP controller lower PB is depressed and 300 sec later the driver fuse blows.

7 preset C (ALL) Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered. (CT)

C (BOP) The Main Turbine will not trip in auto or manual, closing GVs in manual required. (CT)

Farley June 2012 exam Page 2 of 15

Appendix D Scenario #2 Outline Form ES-D-1 8 imf M (ALL) SB LOCA (PZR steam space LOCA) when ESP-O.1 step 2 is mal- reached.

prsl 10 A Train SI will not AUTO actuate and MOV-8803B will not open C (BOP) (CT)

Terminate in EEP-1 .0 when transition to ESP-1 .2 announced.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2012 exam Page 3 of 15

Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 MOE, A Train on service, A Train protected, Load in IC-212 and sim IC snap directory Base IC is IC-51 RUN simulator 0 0 Generic setup:

bat generic_setup_HLT txt

0 0 Quick setup (all items with are included):

bat 20l2nrcexam 02 txt

ii:

0 0 IACRDM set fails to trip:

CMFmalf / c52MGA_cr3 0 0 RTB A and B fail to open

CMFmalf I cBKRXTRP_cc2l / closed CMFmalf I cbkrxtrp_cc22 I closed 8 9 Automatic SI blocked on A train:

imfcsftyinj_ccl open 8 9 MOV- 8803B will not AUTO open

Imf csi88O3bdcc5 open 0 0 Prevent AUTO trip of main turbine

MALE / T I MAL-TUR2 0 0 Prevent Manual trip of main turbine

MALE / T / MAL-TUR24 6 0 1 B SGFP trips 120 seconds after x21 1068L is taken to lower TRG I MaIf/imfmal-fwmllb (1 120) 6 0 1A SGEP controller driver blown fuse TRG 1 Cnh/ imf sk5O9B-V (1 300) 3 0 LJ3 will come into alarm at 48°C TRG 2 imf 1j3 failon 0 0 Tag 1-2A DG output breakers for Unit 1 & 2

rack out 1-2A DG DEO8-1 rack out 1-2A DG DFO8-2 CMEremote / cbkldf08d_cdl / open CMEremote I cbk2dfO8_d_cdl I open Farley June 2012 exam Page4ofl5

Appendix D Scenario 2 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS Triggers arid Commands 6 0 Event Trigger 1: monitors when SK5O9B is taken to lower

trgset 1 x21 I068L and starts a 120 sec clock to trip the 1 B SGFP and blows the controller driver fuse in 300 sec.

3 0 LJ3 comes in alarm when H2 temp >48°C

trig 2 activates TI-4067 > 4&C trgset 2 ti4067 > 48 Farley June 2012 exam Page 5 of 15

r setup Form ES-D-1 A DG selector switch F Place HOLD Tag 1 -2A MSS 1[ )TAG Place HOLD TaQ on 1-2A DG outout breakers 2 HOLD TAGS Place Unit 1 and unit 2 Bypass and inoperable panel Unit I A-Train lights to the up position (EMERGENCY POWER Unit 2 A Train SYSTEM)

DEH Clear DEH alarms IMPULSE LOOP is in service Select POWER OPS PRIMARY on MCB monitor IPC Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity soreadsheet orovided Recorders Verify memory disks cleared Provide a marked up copy of UOP-3.1 version 111.1 UOP-3.1 copy through step 5.11 complete. Mark SOP-21.0, v.108.3 up to steø 4.4.11.

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

Simview I sv DataCollection.uvl sv DataCoUecton.uv If needed, adjust sim time back to 00:00:00 SIM VIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 6of15

Appendix D Scenario 2 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Priorto 0 RUN Start data collection for Simview file On DataCoIIectionuvI file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam

. JN simulator

hornflag Turn Horns ON/OFF ON = TRUE ann horn Start of 1 Place lB SGFP on service. Ramp up 5% power may be exam desired (NRC discretion)

NRC LT-459, pressurizer level, fails LOW, letdown secures.

2 CUE lmf It459 0 20 Restore Letdown.

3 Hydrogen Temperature controller, CP-4055K fails LOW.

lmfCP4O55K-A 0 30 Turn LJ3 off at 47°C - decreasing NRC LT-1 15, VCT level controller, fails HIGH.

CUE lmfltllS 10020 5 FT-495, selected steam Flow Transmitter for 1 C SG fails HIGH.

lmfft495 575 20 6 Loss of BOTH SGFPs 1A SGFP controller failure, SK 509B fails HIGH, manual control is available; No ramp down required due to power level. lmf 5K509B-A 10 20 preset lB SGFP trips 120 seconds after 1A SGFP controller TRIG 1 (120 sec lB Farley June 2012 exam Page7ofl5

Appendix D Scenario 2 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND lower PB is depressed and 300 sec later the driver fuse SGFP trips) blows. (300 sec 1A SGFP controller fuse blows) 7 preset Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

The Main Turbine will not trip in auto or manual, closing GVs in manual required.

8 SB LOCA (PZR steam space LOCA) when ESP-0.1 step 2 is reached. imf mal-prsl 850 120 A Train SI will not AUTO actuate and MOV-8803B will not open.

Terminate in EEP-1 .0 when transition to ESP-1 .2 announced.

End of Exam HORNS OFF

-.j FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.

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

NOTE: file will be saved in the OPENSIM directory.

Farley June 2012 exam Page8ofl5

Appendix D Scenario 2 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 1 WHEN REQUESTED Go to Local SGFP annunciator panel and reset one switch to clear KB2 (this will allow KB2 to come in later in scenario)

Loacfw0O3 true 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 WHEN REQUESTED 7 3 minutes after Locally open reactor trip breakers requested CMFmalf/ cBKRXTRP_cc2l / open CMFmalf / cBKRXTRP_cc22 / open 7 WHEN REQUESTED TBSO:

I have locally tripped the main turbine.

MALF I T I MAL-TUR2 / DELETE MALE / T/ MAL-TUR1 If required, EXPERT COMMAND: SET JEHTRLOA = TRUE Farley June 2012 exam Page 9 of 15

Appendix D Scenario 2 Local Operator Action sheet Form ES-D-1 Local operator actions:

EVENT NO. TIME ACTIONS 7 IF REQUESTED TBSO:

I have opened the condenser vacuum breaker isolation valves N1N51V5I8A and 518B.

REMOTE! N21 / LOA-CFWO12/100 /20 sec ramp 8 WHEN REQUESTED SSS I RADSIDE:

I have performed steps 1 and 2 of attachment 1 of EEP-1 and need you to perform step 3 of attachment 1.

CAE ECCS_disc_delayed.cae 8 WHEN REQUESTED Unit Two UO; RESET FIRE ALARM MH1 ANN I MH1 failoff Farley June 2012 exam Page lOofl5

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

I NONE expected 2 WHEN REQUESTED SSS-plant, SM:

LT-459 Pressurizer level, Recognize and repeat back LT459 failure, CR in the cue and that fails LOW type of communications.

Work Week Coordinator:

Ill get the CR on LT-459 planned and worked.

Ill get I & C to place bistables in trip within the hour.

3 Hydrogen Temperature NONE expected controller 4 NONE expected 5 WHEN REQUESTED Work Week Coordinator:

Ill get the CR on FT-495 planned and worked.

Ill get I & C to place bistables in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

6 NONE expected SEE LOCAL OPERATOR ACTION PAGE for actions taken and provide the below feedback when requested 7 3 MINUTES AFTER [BOOTH] OPEN the Rx trip bkrs using the buttons on LOCAL REQUESTED OPERATOR ACTIONS PAGE, Then report the following:

ROVER:

I have locally Opened Unit one Reactor Trip breakers IF REQUESTED [BOOTH] DELETE MAL-Tur2 and Mal-tur24 using the buttons on LOCAL OPERATOR ACTIONS PAGE, check the Intercept valves have closed, Then report the following:

TBSO:

I have locally tripped the main turbine.

IF REQUESTED [BOOTH] OPEN valves 518A&B using the buttons on LOCAL OPERATOR ACTIONS PAGE, Then report the following:

TBSO:

I have opened the condenser vacuum breaker isolation valves N1N51V518A and 5188.

Farley June 2012 exam Page 11 of 15

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

8 WHEN REQUESTED SM:

I will make the classifications and notifications.

EXTRA CONTROL ROOM OPERATOR:

Both CRACS mode selector switches are in ON.

SM/SSS:

I will get someone to perform step 6 of EEP-1 I will get an extra operator to secure the running DGs ANY CALL TO SHIFT CHEMIST:

Acknowledge to requirement for sampling.

FarleyJune 2012 exam Page 12 of 15

Scenario 2 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 57% power, 1109 ppm, MOL, ramping up, ready to place the lB SGFP on service.

Turnover:

1-2A DG T/O for governorw .005 2 days, ETR4

Current Risk Assessment is and projected is

A Train On-Service A Train Protected.

Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.

Event I Place 18 SGFP on service and ramp up 5% power. (if desired)

Verifiable actions: Open SGFP stop valves and increase speed on SGFP to BOILER control, then place the SGFP on the controller in AUTO. SOP-21.0, section 4.4.12 ver 108.3 Ramp up 5% power at 2 MW/mm. (if desired)

Event 2 LT-459 Pressurizer level, fails LOW and letdown secures.

Verifiable actions: RO Must take manual control of Charging to maintain pressurizer level less than tech spec (63.5%) and restore letdown and charging to automatic. Charging flow will go to full flow, and with LT-1 15 failure VCT level will decrease until the running charging pump trips, if allowed. There will be no auto makeup and no RWST rollover due to LT-115 FH.

AOP-100 TS 3.3.1 Condition M Event 3 Hydrogen Temperature controller failure LOW.

Verifiable actions: Place the H2 temperature controller in manual and raise the demand to lower H2 temperature to within the band. AOP-100 actions.

Event 4 LT-115, VCT level controller, fails HIGH.

Verifiable actions: LCV-1 1 5A must be swapped to VCT position and Makeup will be in manual vs automatic.

Event 5 FT-495, selected steam Flow transmitter for C SG fails HIGH.

Verifiable actions: Take manual control of the 1C FRV and then select channel Ill instruments to control 1 C SG functions. TS 3.3.2. Condition D Event 6 LOSS of Both SGFPs. IA SGFP controller fails HIGH. AOP-13 OR 100 will be entered to decrease the IA SGFP speed. The 18 SGFP will trip 120 seconds after the 1 A SGFP controller is placed in manual and the lower PB is depressed, then the driver fuse blows at 300 sec on IA SGFP (fails to minimum speed) requiring the crew to manually trip the reactor per AOP-l 3.

Verifiable actions: place controller for the IA SGFP in manual and lower to control SG Levels. The team should use guidance of AOP-1 3/1 00 and take manual control of the 1A SGFP speed. If no action taken or if a slow response the SGFPs will trip on Hi Hi SGWL Event 7 The reactor does not trip using either Rx trip switch. The team will attempt to open MG set breakers. The 1A MG breaker will not open. The team will enter FRP-S.l and insert rods in manual or auto (RO) (CT)

The main turbine will not trip in auto or manual, so the team will close governor valves to trip the turbine (BOP) and then emergency borate (RO or BOP) (CT) (Within 10 minutes following attempts to insert control rods by opening CRDM MG breakers)

Farley June 2012 exam Page 13 of 15

Scenario 2 detailed summary Appendix D Form ES-D.-1 sheet Event 8 Pzr Steam space LOCA when ESP-O.1 is reached.

Align HHSI to either A or B Train by manually actuating a SI on A Train or manually opening MOV-8803B. (CT>

Terminate in EEP-1 .0 when transition to ESP-1 .2 announced.

ARP/ SOP-21 0/ AOP-1 00/ AOP-1 3/ FRP-S.1/ EEP-0/ ESP-0.1/EEP-1 .0/ESP-1 .2 Farley June 2012 exam Page 14 of 15

Scenario 2 Critical Task sheet Appendix D Form ES-D-1 Sheet 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 10.29, 1RTOPMANRT---H)

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) (PRA- 10.38, 1TTOPMCBETSW-H)

Manually trip main turbine prior to SGs boiling dry

3. Establish flow from at least one HHSI pump before transition out of E-0.

(WOG CT E-0 - - I)

SCENARIO Normal plant operation, degraded grid, a loss of all SGFPs, ATWT, followed by a OBJECTIVE! Steam space LOCA.

OVERVIEW:

The team should be able to:

recognize and respond to failures of various instruments and components per ARPs, AOP-13 and AOP-100

Recognize the symptoms of an ATWT and implement the steps of FRP-S.1, EEP-0.0, ESP-0.1 & EEP-1.0 Target QuanttaUve Attributes (Per Scenario; See Section D.5.d) Actual Attributes

1. Total malfunctions (58) 10

2. Malfunctions after EOP entry (12) 4

3. Abnormal events (24) 4

4. Major transients (12) 2

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

6. EOP contingencies requiring substantive actions (02) 1

7. Critical tasks (23) 3 Farley June 2012 exam Page 15 of 15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 1 Page 1 of 45 Event

Description:

Place lB SGFP on service Place I B SGFP on service Indications Available:

Time : Pos Expected ActionslBehavior Comments r 108.3 Section 4.4 ALL steps including 4.4.11 are complete (step 4.4.12) Reset the SGFP overspeed trip as follows:

4.4.12.1 Reset the SGFP overspeed trip by depressing TURBINE LATCH pushbutton.

4.4.12.2 Verify that the turning gear trips (if running).

4.4.12.3 Verify the LP and HP GOV valves indicate closed.

(step 4.4.13) Open the SGFP low pressure stop valve by depressing the LOW PRESSURE STOP VALVE OPEN pushbutton.

(step 4.4.14) Open the SGFP high pressure stop valve by depressing the HIGH PRESSURE STOP VALVE OPEN pushbutton.

(step 4.4.15) check the following valves open:

E lB SGFP MINIFLOW (SECONDARY VALVE IND PANEL)

L 1BSGFP RECIRC FCV INLET ISO Ni N21V502B El lB SGFP SUCTION ISO N1N21V526B steps 4.4.16 and 4.4.17 are information steps (step 4.4.18) RoIl the SGFP to minimum controller speed by depressing the INCREASE SPEED pushbutton.

1

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 1 Page 2 of 45 Event

Description:

Place lB SGFP on service Time Pos. Expected ActionslBehavior Comments (step 4.4.19) Monitor the BN TURB VIB Turbine vibrations are MCR DISPLAY: monitored (step 4.4.20) WHEN the Boiler Control SGFP 1 B controller SK-509C light illuminates, THEN turbine speed control is transferred to the SGFP controller.

(step 4.4.21) Reset SGFP first out panel 1 B SGFP first out panel reset (step 4.4.22) Verify no alarms are cutout on the SGFP Turbines Local Alarm Panel.

(step 4.4.23) Verify the LP GOV valve AND HP GOV valve has the proper position indication for plant conditions.

Step 4.4.24 is NA (step 4.4.25) Open the SGFP DISCH Ni N21V503B.

VALVE Ensure the Increase Speed light is illuminated prior to increasing speed using SK-509C (step 4.4.26) Slowly increase the speed of Verify that oncoming SGFP the oncoming SGFP with SK-509C in discharge pressure increases MANUAL.

(step 4.4.27) WHEN discharge pressures Verify that both SGFPs and speeds are approximately the same on continue to share the feed flow both SGFPs, THEN transfer the SK-509C requirements equally.

controller to AUTO.

When the lB SGFP is on service and at the discretion of the Lead Examiner move to event #2.

2

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 2 Page 3 of 45 Event

Description:

LT-459, pressurizer level, fails LOW, letdown secures PT-459 will fail LOW. This Level Transmitter is channel I and is the primary control channel selected since the PRZR LVL CONT SWITCH is selected to the I/Il position. This will cause letdown to secure and charging to go to full flow. AOP-100 actions will be taken. Letdown will be placed back in service using AOP-IOO.

Indications Available:

Annunciators: Indications of LT-459 failing LOW

- PRZR LVL LO HTRS OFF LTDN SEC - LI-459 failing low (HA3) - Backup Heater Breakers open

- PRZR LVL DEV LO (HB2) - P1-i 45 Ltdn HX outlet pressure

- PRZR HTR CONT TRBL (HD4) - Ll-460 and 461 t

- Fl-I 22 charging flow t

- FK-122 demand t

- Fl-iSO letdown flow goes to 0 gpm

- LCV-459 goes closed

- Ll-112B&Ll 115 VCT Level Time Pos. Expected ActionslBehavior Comments section 1.2 SRD 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-459 closed)

Informs SRO if an Instrument Failure has occurred. ARP directs entry into AOP-iOO.

SRO SRO will direct entry to AOP-100.

RD Determines and reports LT-459 failure to SRO 3

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 2 Page 4 of 45 Event

Description:

LT-459, pressurizer level, fails LOW, letdown secures Time Pos. Expected ActionslBehavior Comments RO (step 1) Checks pressurizer level on or trending to program value. (Actual PRZR level increasing)

RNO: manual control of charging flow taken

- FK-122, CHG FLOW CONTROLLER, in manual and charging flow reduced RO (Step 2) Check RCP seal injection flows

- Adjusts SI flow to 6-13 gpm by using HIK-186, SEAL WTR INJECTION CONTROLLER.

SROI (step 3) Determine if a PRZR level Determines Ll-459 failed low RO transmitter I indicator loop has failed.

LI-459, Ll-460, or Ll-461 SROI (Step 3) IF selected PRZR level control RO channel failed THEN select and unaffected channel.

Controlling channel I I II is affected

- RO directed to select channel Ill I II on LS-459Z, PRZR LEVEL CONTROL CHANNEL SWITCH Channel 459 selected, change IF required THEN select an unaffected to CH 461 or 460 channel on the PRZR level recorder control switch LS/459Y, PRZR LEVEL RECORDER INPUTS SWITCH SROI (step 4) Check letdown in service RO - Orifice isolation valves one or more open HV-8149A,B,C, LTDN ORIF ISO VLVS Letdown NOT in service

- Flow indicated on Fl-I 50, LTDN HX OUTLET FLOW.

4

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 2 Page 5 of 45 Event

Description:

LT-459, pressurizer level, fails LOW, letdown secures Time Pos. Expected ActiohslBehavior Comments RO (step 4 RNO) Establish normal letdown as follows:

- Verify closed all letdown orifice isolation valves

. HV-8149A

. HV-8149B

. HV-8149C

- Verify LP LTDN PRESS PK 145 in manual and demand adjusted to 50% or less.

IF necessary THEN open LTDN LINE PENE Action not required RM SOs HV-8175A and B from PRIP, RO - Verify open LTDN LINE CTMT ISO HV 8152

- Verify open both LTDN LINE ISO LCV 459 and 460 Will open LCV-459

- Verify FK-122 in Man and establish required minimum charging flow for one Manual control of FCV-122 orifice to be placed on service. (18 lower PB depressed and GPM) flow decreased

- Open LTDN ORIF ISO 60 GPM HV 8149B or C to establish approx. 60 gpm letdown flow RO (step 5) Check letdown flow established:

- Check letdown flow indicated FI-150

- Place PK-145 in auto.

. Verify that PK-145 set between 4.3-7.5 to maintain 260-450 psi9 letdown pressure Checks these indicators:

. Place PK-1 45 in Auto TI-Il 6 VCT Temp

. Verify LTDN HX outlet temp Tl-143 Divert letdown HX temp maintained at approximately 100°F. Tl-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 5

ADDendix D Qoerator Action Form ESD-2 Op Test No.: FA2012301 Scenario # 2 Event # 2 Page 6 of 45 Event

Description:

LT-459, pressurizer level, fails LOW, letdown secures Time Pos. Expected Actions/Behavior Comments TECHNICAL SPECIFICATION 3.3.1, Reactor Trip System (RTS)

Instrumentation The RTS instrumentation for each Function in Table 3.3. 1-1 shall be OPERABLE.

Table 3.3. 1-1 Reactor Trip System Instrumentation Function 9 Pressurizer Water Level High

- Applicable in Mode I >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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

M. I Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M. 2 Reduce THERMAL 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months POWER to < P-7.

SRO (step 7) Notify Shift Manager RO (step 8) WHEN plant conditions permit THEN restore components to automatic control as follows:

Restore charging flow control to automatic per SOP-2.1, Chemical and Volume Control System Plant Startup and Operation version 125, section 4.6.2 6

Appendix D Operator Action Form ES-D-2 Op Test No: FA2O1 2301 Scenano # 2 Event # 2 Page 7 of 45 Event Descripflon: LT459, pressurizer level, fails LOW, letdown secures Time Pos. Expected ActionslBehavior Comments RO (step 4.6.2.1 and following)

- Place LK-459F, PZR LVL Controller, in manual

- Verify Pzr level is wll 3% of setpoint as indicated on LR-459

- Manually adjust the output meter on LK 459F to equal the position of the meter pointer on CHG FLOW Fl-i 22A

- Place LK-459F in AUTO

- Place FK-122 in AUTO Continiic AUP-IflA irfinn hr RO (step 8.2) Restore control of pressurizer heaters:

- 1A PRZR HTR GROUP BACKUP

- lB PRZR HTR GROUP BACKUP

- ID 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 letdown restored and Tech Specs addressed and at the discretion of the Lead Examiner move to Event #3.

7

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 3 Page 8 of 45 Event

Description:

Hydrogen Temperature controller CP-4055K fails LOW Indications Available:

Annunciators: 11-4067, HYDROGEN TEMP, increasing

- H2 PRESS HIGH (LJ3) DEH screen alarm comes in

- DEH TRBL (LBI)

LJ3 BOP (step 1) Check H2 TEMP controller (CP 4055K on MOB) to insure proper setpoint.

BOP (step 2) Verify validity of alarm from computer point indication.

NOTE; The MOB indication (T14067) comes from DEH computer point GIOGAVG, which is an average of points HCOUT2I R and HOOUT22R.

Historically, there has been a 5-7°C difference between the MOB indication and the point feeding the alarm, such that the alarm may be in with a MOB indication of 42-43°C.

SRO (step 4) Enter AOP-1 00, section 1.9 Section_1 9 RO (step 1) Check main generator hydrogen IOA step temperature controller functioning properly in AUTO.

[] HYDROGEN TEMP, CP-4055K 8

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 3 Page 9 of 45 Event

Description:

Hydrogen Temperature controller CP-4055K fails LOW Time Pos. Expected ActionslBehavior Comments S RO (step 1 RNO) Maintain main generator Take manual control of hydrogen temp < 46°C using manual control HYDROGEN TEMP, CP of hydrogen temperature controller.

4055K and open valve.

BOP (step 4) Notify the Shift Manager.

RO (step 5) Direct appropriate personnel to determine and correct the cause of the high hydrogen temperature alarm.

SRO Write a CR and call dispatcher to plan work order When Hydrogen temperature is being controlled and at the discretion of the Lead Examiner move to Event #4.

9

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 4 Page 10 of 45 Event

Description:

LT-115 fails HIGH.

LT-1 15 will fail high. This will cause the VCT to divert to the RHTs and the VCT level will decrease. Auto makeup will not start to refill the VCT.

Indications Available:

Annunciators: Recognize indications of LT-11 5 failing HIGH

- LTDN DIVERTED TO RHT-VCT LVL HI - LI-i 12, VCT level, decreasing (DF2)

- VCT LVL HI-LO (DF3)

Time Pos. Expected ActionslBehavior Comments SRO Directs RO to perform Actions of DF2 or DF3 RO (Step 1) Determine if VCT level is high or low as indicated by LI-il 5 and LI-il 2B, VCT LEVEL, on the MCB.

RO determines LI-i 15 is failed (step 5) Places VCT HI LEVEL DIVERT HIGH, goes to step 5 VALVE, LCV-i 1 5A in the VCT mode.

- Manually makeup for VCT level control in accordance with SOP-2.3 IF LI-i 15 has failed, THEN initiate steps to have the instrumentation repaired.

The following automatic actions are inhibited:

1) Auto VCTIRCS makeup

2) Auto opening of RWST to charging pump suction on VCT low level

3) Auto VCT outlet isolations closing on lo VCT level SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)

Notify the Shift Manager At the discretion of the Lead Examiner move to Event #5.

10

Appendix D Operator Action Form ES-D-2 FT-495, selected steam flow transmiffer for 10 SG fails high. the team should select channel III instruments to control 10 SG functions. Team is expected to perform actions of AOP-1 00.

Indications Available:

Annunciators: Indications of FT-495 failing HIGH:

- 10 SG Stm Flow> Feed Flow (JB3) - FI-494 Steam Flow t

- MS Line HI Stm Flow Alert (JB4) - TSLB 4 18-4 LIT

- 10 SG LVL DEV (JF3) - 10 FRV FK-498 Demand t

- FI-497 & 496 Feed Flow 1C SG t

- 10 SG level LI-494, 495, 496

- A&BSGIeveI

- SGFP speed t

- SGFP suction pressure Time Pos Expected ActionslBehavior Comments ver_11,_section_1.5 SOP Announces Receipt of MOB Alarms May notice F 1-495, steam flow transmitter for 10 SG, Failed High and inform SRO.

SRO Instructs BOP/RO to perform Immediate Operator Actions of AOP-1 00 11

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 5 Page 12 of 45 Event

Description:

FT-495, selected steam Flow Transmitter for C SG fails HIGH Time Pos. Expected ActionslBehavior Comments BOP (step 1) Maintain SG levels at 65%. NOTE: Step I is an Immediate IF required, THEN, take manual control of Operator Action and a SGFP speed control as necessary to restore continuing action step SG level to 65%

. SGFP master controller SK-509A OR

. SGFP individual controllers as needed.

{ I SK-509B

{ I SK-509C IF required, THEN take manual control of the affected feedwater regulating valves

[I 1A SO FW FLOW FK-478

[1 1 B SG FW FLOW FK-488

[1 1 C SO FW FLOW FK-498 SRO If a loss of main feedwater occurs, then This should not result in a loss perform the actions of AOP-1 3, Loss of Main of MEW 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% SO level BOP (step 3) IF a ramp is in progress, THEN No ramp will be in progress place Turbine on HOLD 12

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 5 Page 13 of 45 Event

Description:

FT-495, selected steam Flow Transmitter for C SG fails HIGH Time Pos Expected Actions!Behavior Comments SRO/ (step 4) Determine if an instrument failure BOP has occurred.

Check for a failed or erroneous indications from the following Steam flow or feed flow indicators.

STM FLOW FEED FLOW SIG CHIlI CHIV CHIlI CHIV A SIG Fl-474 Fl-475 Fl-477 Fl-476 B SIG Fl-484 Fl-485 Fl-487 Fl-486 C SIG Fl-494 FI-495 FI-497 Fl-496 Check for failed or erroneous readings on the following SG pressure indicators Sf0 CHll CHIlI CHIV FT-495 has failed high A SIG P1-474 P1-475 P1-476 B SIG P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496 SRO/ IF the alarm(s) was due to a SGWLC System BOP controlling channel failure, THEN select the unaffected channel and verify proper system response Places switches FS/498Z and FS/498Y for BOP will verify proper system 1C SO in the III position: FT-494 (STM Flow) response

& FT-497 (FEED Flow)

SRO (step 5) Refer to Tech Specs 3.3.2 for any LCO requirements.

T.S. 3.3.2 Condition D applicable TECHNICAL SPECIFICATION 3.3.2, ESFAS Instrumentation The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE Table 3.3.2-1 ESFAS Instrumentation Function 2e High steam flow in two steam lines coincident w/ 10-10 Tavg

Applicable in Modes 1, 2 and 3 with MSIVs open required channels 2 per stm line condition D 13

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 5 Page 14 of 45 Event

Description:

FT-495, selected steam Flow Transmitter for C SG fails HIGH Time Pos. Expeci d ActionslBehavior Comments CONDITION REQUIRED ACTION COMPL ETION TIME D. One channel D.1 NOTE inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

Place channel in trip. 72 hrs OR D. 2.1 Be in MODE 3. 76 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 addressed and at the discretion of the Lead Examiner move to Event #6.

14

Appendix D Operator Action Form ES.D-2 Op Test No.: FA2012301 Scenario # 2 Event # 6 Page 15 of 45 Event

Description:

1A SGFP controller failure, SK-509B, fails HIGH, manual control is available; No ramp down required due to power level. Regain control of SGWL. Loss of BOTH SGFPs.

1A SGFP controller, SK-509B, fails HIGH, and its controller can be shifted to manual and control of the 1A SGFP speed is possible. The crew will enter AOP-13 and take manual control of the IA SGFP. 80 seconds after the IA SGFP lower PB is depressed the lB SGFP will trip and 1A SGFP will controller will lose power 40 seconds later.

Indications Available:

Annunciators: Indications of B SGFP Speed Oscillation

- 1A SG LVL DEV (JF1) - 1A SGFP Speed increases

- 1 B SG LVL DEV (JF2) - FRV-controller FK-496, 497, 498 demand

- 1C SG LVL DEV (JF3) lowering

- FK-509B SGFP speed controller demand is rising ver 11, I ver32 SRO Directs RO or BOP to address ARPs as time permits

- IA,1B,&1CSGLVLDEV (JF1,2&3)

SRO Directs entry into AOP-l00, section 1.4, and performance of immediate actions, then directs subsequent actions AOP-1 3 actions on bottom of page 16 15

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 6 Page 16 of 45 Event

Description:

1A SGFP controller failure, SK-509B, fails HIGH, manual control is available; No ramp down required due to power level. Regain control of SGWL. Loss of BOTH SGFPs.

(step 1) Maintain SG level at the referenced Step 1 is an Immediate level of 65%. Operator action Take manual control of SGFP speed control NOTE: Step 1 is a continuing SK-509B taken to manual action step This controller will shift to manual IF required, THEN, take manual control of SGFP speed control as necessary to restore SG level to 65%

SGFP master controller SK-509 IF required, THEN take manual control of the affected feedwater regulating valves

[] IA SG FW FLOW FK-478

[] 1 B SG FW FLOW FK-488

[] 1 C SG FW FLOW FK-498 SRO (step 1.3) IF a loss of main feedwater has occurred, THEN perform the actions required by AOP-13.O, LOSS OF MAIN FEEDWATER.

SRO (step 2) Set manual trip criteria on SG level (high and low trip setpoints are 82% & 28%

respectively)

BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.

lB SGFF will trip 8 D seconds after the 1A SGFP lower PB is depressed. This will initiate AOP-13 entry.

I v 32 SRO (step 1) Check only one SGFP running This is an SRO decision only -

one is running since the lB SGFP tripped.

16

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 6 Page 17 of 45 Event

Description:

1A SGFP controller failure, SK-509B, fails HIGH, manual control is available; No ramp down required due to power level. Regain control of SGWL. Loss of BOTH SGFPs.

Time Pos. Expected ActionslBehavior Comments BOP (step 1.1) Check generator load >540 MW NOTE: the answer is NO, Main Generator load will be approx485MW RNO send the user to step 3 SRO (step 3) Check indication of any SGFP 1 B SGFP tripped malfunction BOP Take manual control of SGFPs, FRVs as necessary to control SG water level 1A SGFP trips 40 seconds after lB SGFP trips yflr

.. 32 Go to step 2 SRO Recognize LOSS of BOTH SGFPs Direct Step 2 of AOP-1 3

- Perform the lOAs of AOP-1 3 RO (Step 2) Check Rx power less than 5% NO >5% power RO (step 2 RNO)Trip the reactor using RT Reactor does not trip handswitches See next page for Event 7, FRP-S.1 actions.

17

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 18 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

Since Both SGFPs trip, the crew has tried to manually trip the reactor per AOP-1 3. When the crew tries to trip the reactor, the reactor trip breakers will not open and the CRDM MG set breakers will not open. The Main Turbine will not trip in auto or manual.

Indications Available:

Annunciators: Indications of BOTH SGFP Trips

- IA or lB SGFP Tripped (KC3) - SGFP Speed Decreasing

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

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

- SG STM Flow> Feed Flow (JB1, JB2, increasing JB3) - SG Levels decreasing version 43 SRO Reactor trip Direct the reactor trip and enter EEP-O RO/ Immediate Operator actions of EEP-O Immediate Action steps of BOP (step 1) Check reactor trip. EEP-O Check all reactor trip breakers and reactor NOTE: Reactor will NOT trip trip bypass breakers OPEN.

-

Check nuclear power FALLING.

-

check rod bottom lights LIT. -

TRIP CRDM MG set supply breakers. RNO: Reactor is not tripped 1A(1B) MG SET SUPP BKR by RTBs or CRDM MG sets.

[1 N1CI1EOO5A

[1 NICIIEOO5B (step 1.3 RNO) FRP-S.1 entered ver25 SRO Direct entry into FRP Si and complete Step I and 2 are IOA steps IOAs.

18

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 2 Event # 7 Page 19 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

Pos. Expected ActionslBehavior omméiits RO (step 1) IF reactor still NOT tripped, THEN perform the following:

Insert control rods in manual control. Critical task OR Insert negative reactivity Verify rods insert in AUTO at greater than 48 steps per minute.

3 minutes from this phone Dispatch an operator to locally trip the call RTBs will be opened reactor trip and bypass breakers. from BOOTH BOP (step 2) Check Main Turbine tripped Critical task (step 2 RNO) Place MAIN TURB EMERG RNO step 2.2.1:

TRIP switch to TRIP for at least 5 seconds. Close GVs This action will not occur. TURBINE MANUAL depressed GV CLOSE depressed FAST ACTION depressed BOP (step 3) Verify AFW pumps running

-. Both MDAFWPs amps > 0

- TDAFWP speed > 3900 rpm RO (step 4) Initiate Emergency Boration of the RCS.

- Verify at least one CHG PUMP -

RUNNING.

- StartaBATpump

- Open MOV81O4

- Establish normal Ietdwn flow 8149A

and either 8149B or C open

- Check RCS pressure less than 2335 psig

- Establish normal charging flow> 40 gpm

- Verify adequate emergency boration flow of>3ogpmon_Fl-hO 19

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 2 Event # 7 Page 20 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

Pos. Expected Actions/Behavlor Comments BOP (step 5) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[] 3197

[1 3198D

[1 3198C

[1 3196

[] 3198A

[1 3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D

[1 2866C

[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[] 2866D

[1 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP BOP (step 6) Check SI actuated BYP & PERMISSIVE SAFETY INJECTION

[] ACTUATED status light lit

[] MLB-1 1-1 lit A safety injection may not have

[] MLB-1 1 1-1 lit occurred so Attachment 1 would not be done complete attachment 1 See attached sheets See Tab at end of scenario for for Attachment I of FRP-S.1 Attachment I actions. Page 42 20

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 21 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

Pos Expected ActionslBehavior Comments RO (step 7) Locally open the reactor trip Check ALL RTBs open and reactor trip bypass breakers.

Check Main Turbine tripped Locally place turbine Both of these actions will be directed to the overspeed lever to TRIP for at field least 5 seconds.

RO (step 8) Check if reactor still critical. NOTE: This is a continuing action step If RTBs are open or power range indication is < 5% power OR IR SUR is negative, then go to EEPO step 1 If not continue in this procedure.

SRO Trnitinn hk tn FPP-fl 21

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 22 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

Pos Expected Actions!Behavior Comments ROI Immediate Operator actions of EEP-0 Immediate Action steps of BOP Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

-

Check nuclear power FALLING.

-

check rod bottom lights LIT. -

Check turbine TRIPPED.

- EH pumps may be taken to TSLB2 14-1 thru 4 lit OFF here if it is decided the MT is not tripped. (intent is met Check power to 4160 V ESF busses. in FRP-S.1) 4160 V ESF busses AT LEAST ONE

-

ENERGIZED A Train (F & K) power available lights lit OR NOTE: NO DGs will be B Train (G & L) power available lights lit running unless a SI has occurred.

Verify operating diesel generators are being supplied from at least one SW pump.

Check SI Status.

Check any SI actuated indication.

BYP & PERMISSIVE SAFETY INJECTION

[j ACTUATED status light lit

[] MLB1 11 lit

[] MLB1 1 11 lit ver 32 actions below SRO SI is NOT required at this point, directs Directs actions in ESP-0.1 per transition at step 4 of EEP-0 to ESP-0.1, RO/BOP Actions listed below REACTOR TRIP RESPONSE 22

Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 2 Event # 7 Page 23 of 45 Event

Description:

Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.1 will be entered.

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

- Stable at or approaching 547°F action step

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

[] TI 412D

[] TI 422D STM DUMP

[] TI 432D Put in Pressurizer Steam Space LOCA at this point, Go to Event 8 BOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step status.

- Verify FRV5 closed

- Defeat the MADFWP auto start on SGFP trip BOP (step 2.2) - MDAFWP AUTO/DEFEAT - Verify BOTH SGFPs

[j 1A in DEFEAT tripped

[j lB in DEFEAT - Verify total AFW flow to the SGs >395 gpm RO (step 3) Verify ALL RX TRIP breakers OPEN RO (step 4) Check emergency Boration not required

- All rods FULLY INSERTED

- RCS Tavg >525° F BOP (step 5) Announce Unit I Reactor Trip Auto SI will occur on A Train 23

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 24 of 45 Event

Description:

Pzr steam space LOCA A Pzr steam space LOCA has occurred. B Train SI will not AUTO actuate and MOV-8803A will not open.

Indications Available:

Annunciators: Indications of LBLOCA Containment Rad monitors in alarm - RCS Pressure Decreasing CTMT Pressure HI-i Rx Trip SI (GF1) - SI Actuation PRZR LO Press Rx Trip SI (GB4) - Containment Pressure Increasing CTMT Press HI-i Alert (EEl) - Numerous CTMT Rad Monitors alarming RMSHIRAD(FF1)

Js Expected Actions/E havior Comments ALL Immediate Operator actions of EEP-0 Immediate Action steps of Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.

-

Check nuclear power FALLING.

-

check rod bottom lights LIT.-

Check turbine TRIPPED.

-

TSLB2 14-i thru 4 lit Check power to 4160 V ESF busses. NOTE: 3 DGs will be running 4160 V ESF busses AT LEAST ONE

- since an SI has occurred.

ENERGIZED A Train (F 41 60V 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.

24

Op Test No.: FA2O1 2301 Scenario # 2 Event # 8 Page 25 of 45 Event

Description:

Pzr steam space LOCA Time Pos Expected ActionslBehavior Comments Check SI Status.

Critical task to actuate A SI

Check any SJ actuated indication, on A Train or align HHSI BYP & PERMISSIVE SAFETY INJECTION cooling in Attachment 2

[1 ACTUATED status light lit SI will be in progress on B

[1 MLB-1 1-1 lit Train.

[1 MLB1 1 11 lit SRO, Announces EEP-0 Fold out Page items in RO, effect, directs/takes actions required OR

Subcooling <16°F [45}, stop all BOP RCPs

RCS Press < 1300 psig, close chg mini-flows

Ctmt pressure > 4 psig, use adverse numbers SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for

5. Attachment 2 and 4 actions.

Directs the BOP to perform Attachment 2. Page 32 RO (step 6) Check containment pressure- HAS Ctmt pressure will be pre REMAINED LESS THAN 27 psig event RO (step 7) Announce Unit 1 reactor trip and safety injection.

25

Op Test No.: FA2O1 2301 Scenario # 2 Event # 8 Page 26 of 45 Event

Description:

Pzr steam space LOCA Time Pos. Expeted Actions!Béhavior comments RO (step 8) Check AFW status.

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

[j Fl 3229A

[] Fl 3229B

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

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

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

RD (step 8.4) WHEN SO narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.

. Control MDAFWP flow.

MDAFWP FCV 3227 RESET

[] A TRN reset

[] B TRN reset MDAFWP TO IA/I B/IC SG B TRN

[] FCV 3227 in MOD Control TDAFWP flow.

TDAFWP FCV 3228

[1 RESET reset TDAFWP SPEED CONT

[] SIC 3405 adjusted 26

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 27 of 45 Event

Description:

Pzr steam space LOCA Time Pos Expected ActionslBehavior Comments RO (step 9) Check RCS temperature.

IF any RCP running, THEN check RCS average temperature STABLE AT OR

-

APPROACHING 547°F.

TAVG 1A(IB,IC) RCS LOOP

[] TI 412D

[1 TI 422D

[] TI 432D RO (step 9 RNO) IF RCS temperature less than NOTE: RNO column is not 547°F and falling, THEN perform the expected to be used for this following, scenario (step 9.1.1) Verify steam dumps closed.

STM DUMP INTERLOCK

[]ATRN in OFF RESET

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

[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO IA(IB,IC) SG

[] Fl 3229A

[1 Fl 3229B

[] Fl 3229C AFW TOTAL FLOW

[1 Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 NOTE: Will call TBSO to IF MSIVs are open, THEN isolate steam accomplish this task loads in the turbine building while continuing with RNO step 9.1.5.

27

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 28 of 45 Event

Description:

Pzr steam space LOCA Time Pos Expected ActionslBehavior Comments RO (step 10) Check pressurizer PORVs and NOTE: [CA] step--

spray valves.

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

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

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

[] PRT PRESS P1 472

[] PRT LVL Ll-470

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

1A(IB) LOOP SPRAY VLV

[]PK444C

[] PK444D Check any PRZR PORV ISO OPEN -

RO (step 11) Check RCP criteria.

Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16F{45F}

SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow criteria.

Control charging pump miniflow valves based on RCS pressure.

IC(IA) LOOP RCS WR PRESS

[] P1 402A

[] P1 403A Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.

28

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 29 of 45 Event

Description:

Pzr steam space LOCA Time Pos. Expected ActionslBehavior Comments SRO (step 13) Check SGs not faulted.

[1 Check no SG pressure FALLING IN AN

UNCONTROLLED MANNER OR LESS THAN 50 psig.

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

- Check secondary radiation indication [1 19 NORMAL. [1 23A and B

[] 15B and C,

- No SG rising in an uncontrolled manner [1 60 A, B, C, D SRO (step 15) Check RCS intact [j R-2

- Check ontainment radiation NORMAL [] R-7

[] R-27A

- Check CTMT pressure < 3 psig [j R-27B

- Check ECCS sump level <0.4 feet RO (step 1) Checks RCP stopped due to insufficient subcooling (SCMM<45°F)

BOP (step 2) Check SGs not faulted

- no press falling uncontrolled

- none less than 50 psig BOP (step 3) Checks intact SG levels 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 [j R-15

- Check secondary radiation indication - [j 19 NORMAL. [] 23A and B

[] 15B and C,

[j 60A,B,C,D 29

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 30 of 45 Event

Description:

Pzr steam space LOCA Time Pos. Expected Actions/Behavior Comments (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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 & lB post LOCA H2 analyzer on service per ATT 2

- Plot H2 on Fig 1

- Check and control H2 concentration in Ctmt SRO (step 7) Checks for SI termination criteria SI termination criteria may be RO and continues on without terminating SI due met but transition to ESP-1 .1 to inadequate RCS pressure & Pzr level is incorrect.

RO (step 8) Checks containment spray system No - go to step 9

- any CS pump started RO (step 9) Determines LHSI pumps should RESET SI and STOP RHR NOT be stopped due to RCS Pressure < pumps

{435 psig}, RCS pressure stable or rising and RHR pumps running with suction aligned from RWST BOP (step 12) Performs EEP-1 ATT 4, See Tab at end of scenario for VERIFYING 4160 V BUSSES ENERGIZED Attachment 4 actions. Page 45 SRO (step 13) Directs securing Unloaded DGs (extra, Unit two UO, or BOP) 30

Op Test No.: FA2012301 Scenario # 2 Event # 8 Page 31 of 45 Event

Description:

Pzr steam space LOCA Time Pos Expected ActionslBehavior Comments (step 14) Begins evaluation of plant status, Determines both trains of recirc equipment available

- Checks the following:

o BOTH RHRpumps o MOV-8811NB o MOV-8812A1B o MOV-8706NB o CCW MOV-31 85A1B SRO (step 14.2) Directs Unit two UO to assist BOP taking ECCS logs (step 14.2) Directs TSC to evaluate need for RCS sampling (step 14.2) checks for no intersystem LOCA outside Ctmt

- Aux building radiation NORMAL

- Aux building no hi sump levels & pumps not running

- WHT and EDT levels not rising unexplained (step 14.2) Verify at least one train of PRE in operation using SOP-60.0, PRE System(Attached)

(step 15) Checks LHSI flow in progress by RNO: transition to ESP-1.2 RCS PRESS <275 psig & LHSI flows >1500 gpm When the decision is made to transfer to ESP-1 .2, terminate the scenario.

31

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 32 of 45 Event

Description:

Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-O Time Pos Expected Actions/Behavior Comments (Step 1) Verify one CHG PUMP in each train - STARTED. 1A Chg pump will not be BOP []Atrain (IA or 1B) amps> 0 running if no actions have fl B train (I C or I B) amps> 0 been taken to actuate a SI BOP (Step 2) Verify RHR PUMPs - STARTED.

RHR PUMP

[]lAamps>0

[] lB amps> 0 BOP (Step 3) Verify Safety Injection Flow. HHSI flow will be 0 gpm if no (Step 3.1) Check HHSI flow GREATER

- actions have been taken to THAN 0 gpm. actuate a SI

[1 Fl 943 BOP (Step 3.1 RNO) Verify proper SI alignment If SI actuation has occurred CHG PUMPS TO REGENERATIVE HX manually then the following will

[] QIE21MOV81O7 closed not be done

[1 QIE21MOV81O8 closed RWST TO CHG PUMP

[] Q1E21LCVI15B open

[] QIE2ILCVII5D open VCT OUTLET ISO

[1 Qi E21 LCVI I 5C closed

[} QIE2ILCVI 15E closed HHSI TO RCS CL ISO

[] Qi E21 M0V8803A open

[] Qi E21 M0V8803B open Critical Task is to have one

CHG PUMP SUCTION HDR ISO HHSI pump running with the

[] QI E21 MOV8I 30A open corresponding MOV 8803A or

[] Qi E21 MOV81 30B open

[]Q1E21MOV8I3IA open 8 open

[1 Q1E21MOV8I3IB open CHG PUMP DISCH HDR ISO

[j Ql E21 MOV81 32A open

[] QIE2IMOV8132B open

[] QI E21 MOV81 33A open

[j Q1E2IMOV8133B open 32

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 33 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (Step 3.2) Check RCS pressure LESS - will be >435 psig THAN 275 psig{435 psig}.

BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.

[]Atrain (1A1B or 10)

[] B train (IDlE or IC)

BOP (Step 5) Verify each train of CCW - 1A COW pump will not be STARTED. running if no actions have (Step 5.1) Verify one COW PUMP in each been taken to actuate a SI train- STARTED Critical Task to ensure a

COW pump A train HX I C or I B 00W FLOW

[] Fl 3043CA> 0 gpm OR

[] Fl 3043BA> 0 gpm Btrain HX1Aor1B COW FLOW

[] Fl 3043AA> 0 gpm OR

[1 Fl 3043BA> 0 gpm Verify SW flow to associated COW HXs SW FROM IA(IB, IC) COW HX

[1 Q1P16FI3009AA> 0 gpm

[] Q1PI6FI3009BA> 0 gpm

[] Q1P16FI3009CA> Ogpm 33

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 34 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected Actions!Behavior Comments BOP (step 6) Verify containment ventilation isolation.

Verify containment purge dampers -

CLOSED.

[1 3197 U 3198D U 3198C U 3196 U 3198A U 3198B Verify containment mini purge dampers -

CLOSED.

CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D U 2866C U 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C

[1 2866D

[} 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 34

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 35 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (step 7) Verify containment fan cooler alignment.

Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.

-

CTMT CLR FAN SLOW SPEED A train

[J IA

[1 1 B B train

[1 IC

[JID Verify associated emergency service water outlet valves OPEN.

-

EMERG SW FROM 1A(1B,1c,ID) CTMT CLR

[] Q1P16MOV3O24A

[1 Q1P16MOV3O24B

[1 Q1P16MOV3O24C

[] Q1P16MOV3O24D BOP (step 8) Verify AFW Pumps STARTED.

-

Verify both MDAFW Pumps STARTED-

[1 IA MDAFW Pump amps> 0

[}1B MDAFW Pump amps> 0 AND

[] Fl-3229A indicates > 0 gpm

[1 FI-3229B indicates > 0 gpm

[1 Fl-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.

[Condition LITSLB [ Setoint L ConcdenL1 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 35

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 36 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (step 8.3) Verify TDAFWP started.

[] MLB-4 1-3 lit U MLB-4 2-3 lit

[] MLB-4 3-3 lit TDAFWP SPEED

[] SI 3411A> 3900 rpm TDAFWP SPEED CONT

[] SIC 3405 adjusted to 100%

Verify TDAFW flow path to each SG.

TDAFWP TO IA(IB,IC) SG

[] Q1N23HV3228A in MOD

[] QI N23HV3228B in MOD

[] Qi N23HV3228C in MOD TDAFWP TO 1A(1B,IC) SG FLOW CONT

[] HIC 3228AA open

[] HIC 3228BA open

[] HIC 3228CA open 36

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 37 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected Actions!Behavior Comments BOP (step 9) Verify main feedwater status.

Verify main feedwater flow control and bypass valves CLOSED.

-

IA(IB,1C) SG FW FLOW

[jFCV478

[1 FCV 488

[1 FCV 498 Verify both SGFPs TRIPPED.

-

Verify SG blowdown ISOLATED.

-

1A(1B,IC)SGBD ISO

[j Q1G24HV7614A closed

[] Q1G24HV7614B closed

[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -

ISOLATED MLB lights lit.

1A(1B,IC) SGBD SAMPLE STEAM GEN

ISO

[j MLB1 19-2 lit Q1P15HV3328 closed

[j MLB1 19-3 lit Q1P15HV3329 closed

[1 MLBI 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.

Sianal Setooint coincidence TSLB LO SG PRESS < 585 psi 9 2/3 TSLB4 19-2,3,4 Hi stm flow >40% ,4 on 2/3 TSLB4 1 6-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg <543°F 2/3 TSLB2 1 0-1 ,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.

(Step 11.1) Verify PHASE A CTMT ISO -

ACTUATED.

BOP [1 MLB-2 1-1 lit

[] MLB2 111 lit 11.2 Check all MLB-2 lights - LIT.

37

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 38 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior 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.

IA(IB) MG SET SUPP BKR

[1 N1C11EOO5A Fl NICIIEOO5B BOP (step 14) Secure secondary components.

Stop both heater drain pumps.

HDP

[1 1A

[] 1 B Check any condensate pump started.

IF started, THEN stop all but one condensate pump.

[1 1A

[] 1 B If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate Will call TBSO to pumps per FNP-O-SOP-O.O, APPENDIX B, accomplish this.

TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.

38

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 39 of 45 Event

Description:

Attachment 2 of EEP-O Time Pos Expected ActionslBehavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.

CRACS Mode Selector Switch

[]ATRAIN

[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.

230 KV BKR fl 810- OPEN

[] 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.

Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.

End of Attachment 2 39

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 40 of 45 Event

Description:

Attachment 4 of EEP-O (Step 1) Verify two trains of ECCS equipment aligned. (1.1 -1.5)

[] Check DFOI closed

[j Verify DFO2 closed

[) Check DG15 closed

[1 Verfiy DGO2 closed

[} Verify two trains of battery chargers energized Amps > 0 (Step 1 6) Verify two trains of ESF Critical Task initate A Train

equipment aligned. SI manually or align SI using

[] Check all MLB-1 lights LIT ATTACHMENT 9,SAFETY INJECTION ALIGNMENT.

Verify charging pump suction and discharge valves OPEN.

-

CHG PUMP DISCH HDR ISO

[] Q1E21MOV8132A

[1 Q1E2IMOV8I32B

[] Q1E21MOV8I33A

[1 Q1E21MOV8133B CHG PUMP SUCTION HDR ISO

[] QIE2IMOV8I3OA

[] QIE21MOV813OB

[] QIE2IMOV8I31A

[] Q1E21MOV8131B 40

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 41 of 45 Event

Description:

Attachment 4 of EEP-O Time Pos. Expected ActionslBehavior Comments (Step 1.7) Verify all post accident containment air mixing system fans STARTED. (BOP)

-

POST ACCIDENT MIXING FAN

[]IA

[1 1 B

[1 1 C

[j 1 D RX CAV H2 DILUTION FAN

[hA

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

BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54,O, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.

End of Attachment 4 41

Op Test No: FA2012301 Scenario # 2 Event # 7 Page 42 of 45 Event

Description:

Attachment I of FRP-S.1 Time Position Applicants Action or Behavior 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 fl ACTUATED status light lit

[j 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(IB,IC) SG STOP VLVFW FLOW fl FCV 478

[1 FCV 488

[1 FCV 498

- Verify both SGFPs TRIPPED.

-

- Verify SGBD isolated HV 7614A, B C closed

-

- Verify SGBD sample valves closed by MLB-4 6-4, 7-4 and 8-4 LIT BOP (step 4) Verify Phase A actuated MLB-2 1-1 and 11-1 Lit all MLB-2 lights LIT BOP (step 5) Verify one CHG PUMP in each train STARTED.

-

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

[] B train (1C or 1B) amps> 0 BOP (step 6) Verify RHR PUMPs STARTED.

-

RHRPUMP_lAandlBamps>0 42

OpTestNo.: FA2012301 Scenario# 2 Event# 7 Page 43 of 45 Event

Description:

Attachment I of FRP-S.I (step 7) Verify each train of CCW STARTED.

-

BOP Verify one COW PUMP in each train- STARTED.

A train HX 1 C or I B CCW FLOW

[J Fl 3043CA> 0 gpm OR

[] Fl 3043BA> 0 gpm B train HX lAor lB CCW FLOW

[] F! 3043AA> 0 gpm OR

[1 Fl 3043BA>Ogpm Verify SW flow to associated COW HXs SW FROM IA(1B, IC) COW HX

[] Q1P16F13009AA> 0 gpm

[j Q1P16FI3009BA> 0 gpm

[] Q1P16FI3009CA> 0 gpm (step 8) Verify each SW train - HAS TWO SW PUMPs STARTED.

U A train (1A1B or 10)

U B train (1D,IE or IC)

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 Li A train

[] 1A

[1 1 B Li B train

[] 1 C

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

-

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

[] Q1PI6MOV3O24A U Q1P16MOV3O24B

[1 QIPI6MOV3O24C 43

Op Test No.: FA2O1 2301 Scenario # 2 Event # 7 Page 44 of 45 Event

Description:

Attachment I of FRP-S.I fl Q1P16MOV3O24D BOP (Step 10) Check no MSL isolation actuation signal present.

Signal Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% ,4 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLB1 2-2,3,4 If a MSLI signal is present then close ALL MSIVs BOP (step 11) Check containment pressure -HAS REMAINED LESS THAN 27 psig.

End of attachment I of FRP-S.1 44

Op Test No.: FA2012301 Scenario # 2 Event # 7 Page 45 of 45 Event

Description:

Attachment 4 of EEP-1.O Time Pos Expected ActionslBehavior I Comments Attachment 4 of EEP-1 VERIFYING 4160 V BUSSES ENERGIZED (Step 1) Verify 4160 V busses energized.

[j Check DFO1 closed

[1 Verify DFO2 closed

[]Check DG15 closed

[1 Verfiy DGO2 closed

[1 Verify ALL RCP busses energized

- 1A, 1B, 1C4160V Bus

[1 Verify I DIE busses energized (step 1 .13) Verify instrument air aligned to containment. (BOP)

IATO PENE RM

[]N1P19HV3825 open

[]N1P19HV3885 open IA TO CTMT

[1 Q1P19HV3611 open End of Attachment 4 45

Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2012-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.

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

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

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

Assign operating positions.

Ask for and answer guestions.

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Scenario #3 FA2012301 Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #3 This scenario can be shortened by 10-15 minutes by having the UO place the CTMT cooler in service while the OATC & SS commence the startup.
Validation time: 120 minutes Validated by David Shipman, Todd Smith and Doug Jinmerson The week of February 13, 2012 TRN Supervisor Approval: Gary Ohmstede Date: 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTMERN COMPANY
Appendix D Scenario #3 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 3 Op-Test No.: 201 2-301 Examiners: Operators: SRO RO BOP Initial Conditions: 1A CTMT cooler is isolated and will be returned to service per SOP-12.1. 4%
power, UOP-1 .2, vi 02, completed thru step 5.57, Ready to perform step 5.58. EOL, 449 ppm Cb, 18,000 MWD; 1A SGFP on service. Aux steam from U -2.
Turnover:
Plant startup is on hold for turnover and will recommence after 1A CTMT cooler is RTS.
1A SGFP is on service, MFR bypass valves are on service.
1 C DG T/O for slow start investigation.
LCO 3.8.1 (1C DG).
Current Risk Assessment is JJJ1 and projected to remain
B train ols, B train protected.
SPLIT TRAIN ALIGNMENT Event Malf. Event Type* Event Description No. No.
1 N (BOP) Start the 1A Ctmt Cooler in fast speed per SOP-i 2.1 ver 41.0 2 R (RO) Commence Ramp up to 12% power.
3 lmf C (BOP) FK-479 FRV Bypass valve controller Auto output fails HIGH FK479-A LT461 I (RO) LT-461, controlling channel, fails HIGH. TS 3.3.1 Condition M TS (SRO) for >10% power. Admin <10%.
5 cpc2O2 TS (SRO) EA1I, 1A Pzr Heater breaker, trips open. TS 3.4.9.
7c_col Unit 2 will experience a safety injection during the 1A Pzr Htr failure.
This ensures 1-2A DO will align to Unit 2 later on and Unit 1 will experience a loss of all AC condition. (no action required) 6 lmf I (BOP) PT-464 fails HIGH.
pt464 7 imf C (RO) PK-444A, Pzr pressure controller, fails LOW PK444 A-A imf c (BOP) When 1A loop spray valve (PCV-444C) opens it will stick full open.
pk444c
-C Farley June 2012 exam Page 2 of 14
Appendix D Scenario #3 Outline Form S-D-1 8 Imf M (ALL) Dual unit LOSP at step 4 of ESP-0.1, ECP-0.0, Loss of ALL AC Power, entry required.
1 B DG fails to auto start. (No actions required)
(BOP) 2C DG can be manually started and will automaticaNy align to B Train emergency busses. (CT)
C (BOP) 1 D and 1 E SW pumps will not start on the sequencer. (CT) 9 Imf M (ALL) After 2C DG is started and ESP-0.1 re-entered, Steam break MAL- inside ctmt occurs from lB SG.
MSSI B C (RO) lB CS Pump does not auto start. (CT) preset C (BOP) 1A MSlVs do not auto close (CT)
Terminate when ESP-1.1, SI Termination, entered (N)ormal, (R)eactivity, (I)nstrument, (c)omponent, (M)ajor Farley June 2012 exam Page 3 of 14
Appendix D Scenario 3 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 Load in IC-213 and sim IC snap directory Base IC is IC-45 RUN RUN simulator 0 0 Generic setup:
bat generic_setup_HLT.txt Quick setup is in IC-223
0 0 Quick setup (all items with are included):
bat 20l2nrcexamO3.txt lB DG fails to auto start: If the box = TRUE than Set jdgblklb= the lB DG will NOT auto start i
7 10 ID and I E SW pump will not start on LOSP sequencer
imf Cncpswlf_d_cc5 open Inif Cncpswle_d_cc5 open 8 12 msiv 3369a and msiv 3370a fail to auto close
imf crsh00la_cc5 open imf cmsh002a d_cc5 open 7 0 lBDGfailstoAutoStart
DISPLAY!JDGBLKI B/FIND/SET = t set jdgblkl b = true 0 0 IC DG Tagged out
imf cBKl DHO7_d_cpl imf cBK2DHO7_d_cpl
? TGd none Farley June 2012 exam Page4ofl4
Form ES-P-i I.
Place HOLD Tag on 1C DG MSS 1 HOLD 17 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 Ensure the 1 B Ctmt cooler is selected 1 B CTMT CLR selected DEH Clear DEH alarms Select CRITICAL STARTUP PARAMETERS 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 uø rnmnaafr reactivity spreadsheet provided Recorders Verify memory disks cleared Provide a marked up copy of UOP-1.2 v102 completed thru UOP-1.2 copy steo 5.57, Ready to perform step 5.58.
FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview I sv DataCollection.uvl sv DataCoIIecton.uvI If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) 0 Minutes: clock(2) = 0 Seconds: cIock(1 = 0 sv sim clock.uvl VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 5 of 14
Appendix D Scenario 3 Booth Guide Form ES-D-l EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and then COLLECT to start collectinci data 0 Begin Exam RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF rIS ON = TRUE ann horn Start of Start the 1 exam 1A Ctmt Cooler in fast speed per SOP-12.1 the 2 Commence Ramp up to 12% power.
cooler is started NRC CUE FK-479 FRV Bypass valve controller Auto output fails HIGH.
lmf FK479-A 10 100 LT-461 fails HIGH.
ImfLT46l 10060 NRC CUE IA Pzr heater trips imf cpc2O27ccol Unit 2 will experience a safety injection during the IA Pzr Htr failure. This ensures I-2A DG will align to Unit 2 later on and Unit 1 will experience a loss of all AC condition. (no action required) IMF Csftyinj_cc2l closed Announce Unit 2 Rx trip and Safety Injection 6 PT-464 fails HIGH. IMF PT464 1200 100 Farley June 2012 exam Page6ofl4
Appendix D Scenario 3 Booth Guide Form ES-D-1 PUT IN AFTER bat 201 2nrcexam_trgset_1 .txt FAILURE Causes 1A loop spray valve to stick full open.
7 PK-444A, Pzr pressure controller, fails LOW IMF PK444A-A 10 20 When 1A loop spray valve (PCV-444C) opens it will stick full open.
8 Step 4 Dual unit LOSP at step 4 of ESP-0.1 or EEP-0 step 5, of ESP- ECP-0.0, Loss of ALL AC Power, entry required.
0.1 IMF MAL-EPS1 1 10 or step 5 1 B DG fails to auto start. (No actions required) of EEP 0 2C DG can be manually started and will automatically align to B Train emergency busses. (CT) 1 D and 1 E SW pumps will not start on the sequencer.
(CT) 9 Step 2 After 2C DG is started and ESP-0.1 re-entered or EEP-0 of ESP- step 5, Steam break inside ctmt occurs from I B SG.
0.1 IMF MAL-MSS1B 3 300 I B CS Pump does not auto start. (CT)
IA MSIVs do not auto close (CT)
Terminate when ESP-1 .1, SI Termination, 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 NRC examOl Ensure data file created.
grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
Farley June 2012 exam Page 7 of 14
Appendix D Scenario 3 Local Operator Action sheet Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 NONE REQUIRED 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 WHEN REQUESTED 7 IF REQUESTED 8 5 minutes after Close VOI7B TDAFW Pump isolation valve requested Remote n23 I Ioa-afwOO7 I 0 I 20 second ramp 8 IF REQUESTED Clear fire alarm imfmhl2 Clear MK4 LIQ PANEL alarm Imfmk42 Farley June 2012 exam Page 8 of 14
Appendix D Scenario 3 Local Operator Action sheet Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 8 If requested Start the 1 B EAC lrf Loa-casOl9 true Line up N2 to the PORVs Irf loa-casO22 80 25 Open HV2228 lrf loa-casO28 100 20 Farley June 2012 exam Page 9 of 14
Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
1 NONE expected 2 IF REQUESTED Have EM or OPS prepare to close Disconnect 915 per UOP-1 .2, step 5.60.7.
3 IF REQUESTED ROVER:
Acknowledges to check FCV-479 in the MSVR.
4 NONE expected 5 WHEN REQUESTED ROVER:
EA1 1 is open. (there are no indications available on this breaker)
DISPATCHER:
Acknowledges when informed that the CR is in the queue.
6 WHEN REQUESTED SSS-plant, SM and Dispatcher:
Recognize and repeat back PT-464 failure, CR in the cue and that type of communications 7 NONE expected 8 WHEN REQUESTED DB SO:
Acknowledges to check the 2C DG alarms and that type of communications 8 IF REQUESTED Extra Operator:
The fire alarm is 1A-22 and I have acknowledged it on the fire alarm panel.
Radside SO:
The WHT high level alarm is in.
8 WHEN REQUESTED SM:
I will make the classifications and notifications.
EXTRA CONTROL ROOM OPERATOR:
Both CRACS mode selector switches are in ON.
SM/SSS:
I will get an extra operator to secure the running DGs ANY CALL TO SHIFT CHEMIST:
Acknowledge to requirement for sampling.
Farley June 2012 exam Page 10 of 14
Appendix D Scenario 3 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
8 WHEN REQUESTED Rover:
Align 18 Emergency air compressor Radside SO:
Align backup N2 to the PORVs 9 WHEN REQUESTED Rover:
Isolate lB SG from the HSDP per step 4.5 of EEP-2.0.
Farley June 2012 exam Page 11 of 14
Scenario 3 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: IA CTMT cooler is isolated and will be returned to service per SOP-12.I 4%
power, UOP-I .2, vi 02, completed thru step 5.57, Ready to perform step 5.58.
EOL, 449 ppm Cb, 18,000 MWD; IA SGFP on service. Aux steam from U-2.
Turnover:
Plant startup is on hold for turnover and will recommence after IA CTMT cooler is RTS.
1A SGFP is on service, MFR bypass valves are on service.
1C DG TIO for slow start investigation.
LCO 3.8.1 (1C DG).
Current Risk Assessment is and projected to remain
B train o!s, B train protected.
Event I Startthe lACtmtCoolerinfastspeed perSOP-12.1 ver4l.0 Event 2 Commence Ramp up to 12% power.
Verifiable actions: RO uses rods to increase RCS temperature, adjusts Steam Dumps to increase Rx power and adjusts MEW flow to the SGs (Bypass ERVs on service).
Event 3 EK-479, Bypass ERV, fails HIGH, Auto output failure.
Verifiable Actions: RO/BOP will manually control SG WL at low power levels. This will be a reactivity event as well. Stm dumps will have to be adjusted due to the cooldown.
Event 4 LT-461, controlling channel, fails HIGH.
Verifiable actions: charging flow in manual required to prevent Pzr level from decreasing to 15% and letdown securing, and select out the failed channel. Requires restoration of charging flow to AUTO.
TS 3.3.1 Condition M for >10% power. Admin <10%. AOP-100 Event 5 1 A Pzr Heater Breaker trips open TS 3.4.9 Condition B Unit 2 will experience a safety injection during the IA Pzr Heater failure. This ensures 1-2A DG will align to Unit 2 when the LOSP occurs and Unit 1 will experience a loss of all AC condition. (no action required)
Event 6 PT-464 fails high, Steam dumps open until shut by P-12, SGEP speed increases.
Verifiable actions: BOP will manually control SGEP speed and steam dumps to control RCS temperature. This is also a reactivity event. Manual control of steam dumps will be required after this event. Probable letdown isolation due to the cooldown. AOP-I00.
Next event can be put in before letdown is re-established but after the plant is stabilized.
Event 7 PK-444A, Pzr pressure controller, fails LOW.
Verifiable actions: close PORV-444B, close spray valves for BOTH RCPs, trip the reactor prior to 2100 psig, then trip 1A and lB RCPs.
Event 8 Dual unit LOSP, 1 B DG does not auto start and 1C DG is tagged out, 1 -2A DG is supplying unit 2. 1 D and 1 E SW pumps do not start on the sequencer.
Verifiable actions: start the 2C DG, (CT) start at least one SW pump. (CT)
Farley June 2012 exam Page 12 of 14
Scenario 3 detailed summary Appendix D Form ES-D-1 sheet Event 9 lB SG will have a fault inside containment after ESP-O.1 is entered from ECP-O.O.
1 B CS Pump does not auto start. (CT)
Both IA MSIVs will NOT auto close. Start the 1 B CS Pump (CT) and close one MSIV on 1A MS line and isolate AFW flow to the faulted SG. (CT)
SOP-12.1 /AOP-100, sections 1.3, 1.2, 1.5, 1.7 and 1.1 I EEP-OI ESP-O.1 / ECP-O.O I possible FRP-Z.1 entry! EEP-2.O! ESP-1 .1 Farley June 2012 exam Page 13 of 14
Scenario 3 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
1. Restore power to any emergency bus prior to completing step 5 of ECP-0.0 and within 30 minutes of start of the event. (WOG CT E-0 - C) (PRA 10.44
-
DGOPSTART2CH)
Perform 2C DG SBO start.
2. Manually Start the SW pump such that the EDG does not fail because of damage caused by engine overheating. (WOG CT ECA-0.0 - - F)
StartlDorlESWpump
3. Isolate the faulted SG before transition out of E-2. (WOG CT E-2 - - A) (PRA -
10.41 AFW-ISO-Bl)
Manually Close ALL MSIVs to isolate the faulted SG
Close AFW FCVs to the faulted SG
4. Manually actuate at least the minimum required complement of containment cooling equipment before an extreme (red-path) challenge develops to the containment CSF. (WOG CT E-0 - - E)
Start the 1 B CS pump after Containment pressure is/has been > 27 psig, and prior to a Red Path on FRP-Z.1 (54 psig) or start 2 ctmt cooler fans.
Requirement is 1 ctmt cooler fan and 1 CS pump OR 2 ctmt cooler fans.
SCENARIO Low power instrument and component failures with LOSP and Steam Fault inside OBJECTIVE! containment.
OVERVIEW: The team should be able to:
Place the 1A Ctmt cooler in service, ramp the plant from 4% to 12 % power,
respond to several instrument failures that affect the Stm dumps, Pzr level control and Pzr heater trip,
respond to a FRV bypass controller failure that has the potential for affecting core reactivity by applying the guidance of AOP-1 00,
respond to a Pzr pressure controller failure and then diagnose a stuck open spray valve per AOP-100,
respond to a LOSP per ECP-0.0 during which component failures occur, and respond to a Steam fault inside containment with component failures.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
1. Total malfunctions (58) 9
2. Malfunctions after EOP entry (12) 3
3. Abnormal events (24) 5
4. Major transients (12) 2
5. EOPs entered/requiring substantive actions (12) 1
6. EOP contingencies requiring substantive actions (02) 2*
7. Critical tasks (23) 4
Possible FRP-Z.1 entry Farley June 2012 exam Page 14 of 14
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 1 Page 1 of 44 Event
Description:
Start the IA Ctmt cooler per SOP-12.1, step 4.1 Start the 1A Ctmt Cooler in fast speed per SOP-12.1 Indications Available:
Annunciators:
- NONE Time Pos. Expected ActionslBehavior Comments
, ver 41 .0 Step 41 Containment Cooling System Startup BOP (Step 4.1.1) OPEN SW TO 1A CTMT CLR Qi P1 6M0V301 9A BOP (Step 4.1.2) OPEN SW FROM 1A CTMT CLR Q1P16MOV3441A BOP (Step 4.1.3) OPEN 1ACTMT CLR SW DISCH QIPI6MOV3O23A BOP (Step 4.1.4) Check SW combined flow through A Train (1A & lB containment coolers) 2000 GPM.
BOP (Step 4.1.5) Check SW combined flow through B Train (1C & 1D containment coolers) 2675 GPM.
BOP (Step 4.1.6) Start the IA containment cooler in FAST (SLOW) speed:
BOP (Step 4.1.7) Check CTMT CLR DISCH OPEN lights illuminated for:
CTMT CLR 1A DISCH 3186A OPEN 1
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 1 Page 2 of 44 Event
Description:
Start the IA Ctmt cooler per SOP-I 2.1, step 4.1 Time Pos. Expected ActionslBehavior Comments Dome Recirc fans are running and Rx cavity cooling fans will be running Event #2 will begin when the Ctmt cooler is RTS.
2
Appendix D Operator Action Form ESD-2 Op Test No.: FA2012301 Scenario # 3 Event # 2 Page 3 of 44 Event
Description:
Ramp up to 12% power Increase Reactor power to 12% and get ready to roll the Main Turbine. When simulator is taken to run the crew is expected to increase Reactor power to 12% lAW UOP-1 .2. At 8% the NRC will evaluate going to the next event. This evolution will take approx. 15 -20 minutes Indications Available:
Annunciators: NA I
. Time,, Pos... Expected ActionslBehavior ,,,, ,, Comments
-.
version 102,step 5.58 RO Begin to increase reactor power to greater than 12% with following controls.
D Manual adjustment of control rods Steam dumps in Steam Pressure Control Mode SRO Monitor reactor power and Steam Dump adjustments as reactor power rises BOP Will be reviewing UOP-1 .2 and getting ready to roll the main turbine.
3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 2 Page 4 of 44 Event
Description:
Ramp up to 12% power Time Pos Expected Actions/Behavior Comments RO WHEN Nuclear at Power Permissive P-b permissive status light is illuminated (2/4 power ranges greater than 10%), THEN perform the following: {CMT-0003695}
Block the intermediate range reactor trip and overpower rod stop.
LI Place INTEMEDIATE RANGE BLOCK TRN A to BLOCK.
LI Place INTEMEDIATE RANGE BLOCK TRN B to BLOCK.
On the Bypass and Permissive Panel verify the following:
LI The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.
LI The INTERM RANGE TRAIN B TRIP BLOCKED light illuminated.
Block the power range low setting reactor trip.
LI Place POWER RANGE BLOCK TRN A to BLOCK.
LI Place POWER RANGE BLOCK TRN B to BLOCK.
On the Bypass and Permissive Panel verify the following:
LI The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.
LI The POWER RANGE LOW SETTING TRAIN B TRIP BLOCKED light illuminated.
RO Verify that Low Power Trip Block P-7 status light is not illuminated to ensure the unblocking of the following reactor trips.
LI Pressurizer Low Pressure LI Pressurizer High Water Level LI Loss of Flow-Two Loops 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 2 Page 5 of 44 Event
Description:
Ramp up to 12% power Time Pos. Expected Actions!Behavior Comments RO Verify NR-45B is in the desired speed, i.e.,
2 speed (2 min/div) OR normal speed. (10 min!div)
SRO Direct qualified EM or OPS personnel to close disconnect switch 915 When 10-12% power is reached and at the discretion of the Lead Examiner move to event #3.
5
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 3 Page 6 of 44 Event
Description:
FK-479 failure high Auto output failure Description here Indications Available:
Annunciators: Recognize indications of FK-499 failing high:
- IC SG LVL DEV (JF3) - 10 SG feed flow rising
- IC SG FEED FLOW> STM FLOW (JG3) - 10 SG NR level rising
- 10 SG HI-HI LVL ALERT (JD3) - FRV bypass valve qoinq full open Time Pos. Expected Actions/Behavior Comments version 11 (possible AOP-13 entry SRO Instructs BOP/RO to perform Immediate Operator Actions of AOP-1 00 BOP (step 1) Maintain SG levels at 65%. NOTE: Step 1 is an Immediate IF required, THEN, take manual control of Operator Action and a SGFP speed control as necessary to continuing action step restore SG level to 65%
- SGFP master controller SK-509A OR
- SGFP individual controllers as needed.
{] SK-509B
[ I SK-509C IF required, THEN take manual control of the affected feedwater bypass valves
{j IA SO FW FLOW FK-479
[] I B SG FW FLOW FK-489 F 1 IC SG FW FLOW FK-499 SRO If a loss of main feedwater occurs, then This will not result in a loss of perform the actions of AOP-13, Loss of MFW Main 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 No ramp will be in progress place Turbine on HOLD 6
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 3 Page 7 of 44 Event
Description:
FK-479 failure high Auto output failure Time Pos. Expected Actions!Behavior Comments SRO/ (step 4) Determine if an instrument failure BOP has occurred.
Check for a failed or erroneous indications NO instrument failure occurred from the following Steam flow or feed flow indicators.
STM FLOW FEED FLOW SIG CHIlI CHIV CHIlI CHIV A SIG Fl-474 Fl-475 Fl-477 Fl-476 B SIG FI-484 Fl-485 Fl-487 Fl-486 C SIG Fl-494 Fl-495 Fl-497 Fl-496 Check for failed or erroneous readings on the following SG pressure indicators SIG CHII CHill CHIV A SIG P1-474 P 1-475 P1-476 B S/G P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496 SRO/B IF the alarm(s) was due to a SGWLC OP System controlling channel failure, THEN No action required due to select the unaffected channel and verify controller failure.
proper system response Places switches FS/498Z and FS/498Y for IC SG in the Ill position: FT-494 (STM Flow) & FT-497 (FEED Flow)
SRO (step 5) Refer to Tech Specs 3.3.2 for any No LCO requirements LCO requirements.
SRO (step 6) Notify the Shift Manager (step 7) WHEN plant conditions permit, THEN return systems to automatic control.
SRO (step 8) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
At the discretion of the Lead Examiner move to Event #4 7
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 4 Page 8 of 44 Event
Description:
LT-461 fails high, selected and controlling LT.
LT-461 fails high. The crew will enter AOP-100 for the failing level transmitter and get control of pzr level before it trips letdown. If letdown trips then it will have to be placed on service prior to continuing.
Indications Available:
Annunciators: Recognize indications of LT-461 failing high slowly:
PRZR LVL HI B/U HTRS ON (HA2)
LT-459, 460, Actual Przr level decreasing
-
-
PRZR LVL HI RX TRIP ALERT (HAl)
FI-122 slowly lowering
-
-
CHG HDR FLOW HI-LO (EA2)
VCT level rising
-
section_1.2 SRO Direct entry into AOP-iOO Perform the IOAs of AOP-i 00 for RCS pressure.
RO (step 1) Check pressurizer level is on or PZR level will be slowly trending to program value. decreasing RO (step 2) Check RCP Seal Injection flows. No adjustment will be
[1 HIK-i86 adjusted to 6-13 aom necessary RO (step 3) Determine if a pressurizer level LT-461 has failed high transmitter/indicator loop has failed.
SRO/ (Step 3) IF selected PRZR level control RO channel failed THEN select and unaffected channel.
Controlling channel Ill / II is affected
- RO directed to select channel III / II on LS-459Z, PRZR LEVEL CONTROL CHANNEL SWITCH Channel 461 is selected, change to I / II position IF required THEN select an unaffected channel on the PRZR level recorder control 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 Fl-i 50, LTDN HX Letdown will remain in service OUTLET FLOW.
8
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 4 Page 9 of 44 Event
Description:
LT-461 fails high, selected and controlling LT.
Time Pos. Expected ActionslBehavior Comments SRO (step 6) Refer to Tech Specs 3.3.1 & 3.3.3 determine any LCO requirements.
Tech Siec 3.3.1. Condition M 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 I >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 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.
M.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M. 2 Reduce THERMAL 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months POWER to < P-7.
SRO (step 7) Notify Shift Manager RO (step 8) WHEN plant conditions permit THEN restore components to automatic control as follows:
Restore charging flow control to automatic per SOP-2.1, Chemical and Volume Control System Plant Startup and Operation version 126, section 4.6.2 9
Appendix D Operator Action Form ES-D-2 Op Test No: FA2012301 Scenario # 3 Event # 4 Page 10 of 44 Event
Description:
LT-461 fails high, selected and controlling LT.
(step 4.6..i . ,:i tolowing)
- Place LK-459F, PZR LVL Controller, in manual
- Verify Pzr level is wll 3% of setpoint as indicated on LR-459
- Manually adjust the output meter on LK 459F to equal the position of the meter pointer on CHG FLOW Fl-i 22A
- Place LK-459F in AUTO
- Place FK-122 in AUTO Continue AOP-100 actions here RO (step 8.2) Restore control of pressurizer heaters:
- 1A PRZR HTR GROUP BACKUP
- lB PRZR HTR GROUP BACKUP
- 1D PRZR HTR GROUP BACKUP
- IE PRZR HTR GROUP BACKUP (ARP HD4 Actions)
- Places IC 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 the plant is under control and at the discretion of the Lead Examiner move to Event #5.
10
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 5 Page 11 of 44 Event
Description:
EAI I, IA Pzr Heater breaker, will trip open.
When Pzr level is under control, EAII, IA Pzr Heater breaker, will trip open.
Indications Available:
Annunciators: I Recognize indications of A Pzr Htr breaker tripping:
- PRZR HTR BKR TRIPPED (HD5)
- IA PZRZ HTR GROUP BACKUP green light LIT and Amber light LIT Ver. 35.1 RO (step 1) Determine which pressurizer heater group has tripped.
BOP (step 2) refer to HCI ARP SRO (step 4) Notify appropriate personnel to CR written, SM notified determine and correct the problem SRO (Step 5) Refer to Tech Spec 3.4.9 TECHNICAL SPECIFICATION 3.4.9, Pressurizer The pressurizer shall be OPERABLE with:
a. Pressurizer water level 63.5% indicated; and
b. Two groups of pressurizer heaters OPERABLE with the capacity of each group> 125 kW and caoable of beina oowered from an emergency power supply.
IA Pzr Heater is a Tech Spec heater due to power supply.
CONDITION REQUIRED ACTION COMPL ETION TIME B. One required B. I Restore required group 72 group of of pressurizer heaters to hours pressurizer OPERABLE status.
heaters inoperable.
SRO (step 7) Notify the Shift Manager SRO (Step 9) Submit a condition report for the failed instrument, and notify the Notify the Work Week Coordinator When Tech Specs have been evaluated and the plant is under control and at the discretion of the Lead Examiner move to Event #6.
11
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 6 Page 12 of 44 Event
Description:
PT-464, Steam Header Pressure, fails HIGH.
PT-464 fails HIGH. This will result in SGFP speed increasing, STM Dumps will go full open, and close at 543°F, shift to manual and will not re-open until P-12 is reset or temperature rises above 545°F AND the controller placed in AUTO. RCS Tavg will slowly rise until the atmospherics lift.
Reactor power will fluctuate throughout based on steam flow and temperature effects.
Indications Available:
Annunciators: Indications of PT-464 failure:
- RX COOLANT LOOPS IA, IB, OR IC - Steam dump demand indicator Tl-408 TAVG LO-LO (FF4) increasing
- 1A SG LVL DEV (JF1) - Additional steam dump valves opening (as
- 1 B SG LVL DEV (JF2) seen on Secondary Valve Position Indication
- 1C SG LVL DEV (JF3) Panel)
- Steam flow increasing on all 3 SGs (as seen on SF/FE recorders)
- Pl-464A increasing to 1200 psig
- RCS Tavg lowering
- Rx power increasing Time Pos. Expected Actions/Behavior Comments I
section 1.4 SRO Directs RO or BOP to address ARP5 as time permits
. HF4, RX COOLANT LOOPS 1A, 16, OR IC TAVG LO-LO
. JF1, 2, & 3: 1A, 1B, & 1C SG LVL DEV SRO Directs entry into AOP-100, section 1.4, and performance of immediate actions, then directs subsequent actions per RO & BOP rows below:
BOP (step 1 )Take manual control of SGFP speed immediate operator actions control
- SK-509A taken to manual and decreases speed 12
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 3 Event # 6 Page 13 of 44 Event
Description:
PT-464, Steam Header Pressure, fails HIGH.
Time Pos. Expected Actions/Behavior Comments SRO (step 2)Set manual trip criteria on SG level step 3 places ramp on hold (high and low trip setpoints are 82% & 28% Main Turbine not tied to grid.
respectively)
(step 4) Adjust speed back to within the normal operating range for the feed flow/steam flow LP required for the existing power level.
unit 1 NI) 1,OAD AP i O nirl fnr 1O%
Approximate AP can be determined from the following MCB indications.
o SGFP DISCH PRESS P1-4003 o SO Pressure indications:
S/G CH II CH Ill CH IV A S/G P1-474 P1-475 P1-476 B SIG P1-484 P1-485 P1-486 C SIG P1-494 P1-49 P1-496 SRO (step 5 RNO) Directs BOP operator to NOTE: Failure of PT-464 will manually operate steam dumps to prevent affect automatic operation of opening of SG atmospheric relief valves as the steam dumps in steam RCS temperature recovers pressure mode.
BOP (step 5) Take manual control of the steam dumps and adjust to maintain Tavg at approx 550°F.
- STM HDR PRESS PK-464 taken to raise to open STM Dumps to control RCS pressure 13
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario if 3 Event if 6 Page 14 of 44 Event
Description:
PT-464, Steam Header Pressure, fails HIGH.
SRO (step 6) Notifies Shift Manager (step 7) When plant conditions permit, Then Cannot do this step with PT-restore components to AUTO control 464 failed SRO (step 8) Submits a CR & Notifies the Work Week Coordinator SRO Enters LCO 3.4.2, RCS Minimum If required Temperature for Criticality: Be in Mode 3 in 30 minutes: IF Tavg < 541°F TECHNICAL SPECIFICATION 3.4.2, RCS Minimum Temperature for Criticality CRS 3.4 RCS 3.4.2, RCS Minimum Temperature NOTE: Tech Spec applicability for Criticality will vary depending of how quickly the event is diagnosed.
Each RCS loop average temperature (Tavg) shall be 541°F.
CONDITION REQUIRED COMPLETION ACTION TIME A. Tavg in one A.1 Be in MODE 30 minutes or more RCS 3.
loops not within limit.
Restoration of letdown is not required to continue but may be allowed at the discretion of the Lead Examiner At the discretion of the Lead Examiner move to Event #7.
14
Op Test No.: FA2O1 2301 Scenario # 3 Event # 7 Page 15 of 44 Event
Description:
PK-444A, Pzr Pressure control controller, fails LOW PK-444A fails LOW which opens the spray valves and PORV-444B. RCS pressure falls.
Indications Available:
Annunciators: Recognize indications of PK-444A failing LOW
- PRZR PRESS HI-LO (HC1) - PK-444A controller reading 0% output
- PRZR HI-LO PRESS ALERT (HC2) - BOTH Spray valves open
- PORV-444B open
- PRZR PRESS REL VLV 445A OR B/U
- RCS pressure falling HTRS ON (HD1) section 1.1 SS Directs AOP-100 section 1.1 immediate actions to be performed NOTE: WHEN transitioning to EEP-0, REACTOR TRIP OR SAFETY INJECTION AND at the Shift Supervisors direction, It is ACCEPTABLE for one team member to complete the Immediate Operator Actions of EEP-0, while the other team member verifies a Reactor Trip, THEN trips the appropriate RCPs before finishing the Immediate Operator Actions of EEP-0.
RO (Step 1) Take manual control to raise RCS Immediate Action steps I pressure: and 2
. PORVs PCV444B
. Sprays PK-444C & D
. Heaters 1A, 1B, 1C, 1D, 1E
. PK-444A PRZR PRESS REFERENCE controller 15
Op Test No.: FA2012301 Scenario # 3 Event # 7 Page 16 of 44 Event
Description:
PK-444A, Pzr Pressure control controller, fails LOW pressurizer pressure is decreasing due to a mechanically stuck open spray valve PCV444C or PCV444D, THEN perform the following:
- IF the reactor trip breakers are closed, THEN trip the reactor prior to pressure reaching 2100 PSIG.
- WHEN the reactor is tripped, THEN go to EEP-0, REACTOR TRIP OR SAFETY INJECTION.
- WHEN the reactor is tripped, THEN verify_1A and_1 B_RCPs_secured.
SRO Reactor trip Direct the reactor trip and enter EEP-0
-. I, version 43 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.
16
Op Test No.: FA2012301 Scenario # 3 Event # 7 Page 17 of 44 Event
Description:
PK-444A, Pzr Pressure control controller, fails LOW Time Pos. Expected Actions/Behavior Comments (step 4) Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[j ACTUATED status light lit
[] MLB-1 1-1 lit
[] MLB1 111 lit When ESP-O I entered then put in LOSP at discretion of Lead Examiner Steps 1 6 of ESP-O.1 below I [version 32 SRO Directs actions in ESP-O.1 per RO/BOP Actions listed below RO (step 1) Check RCS temperature NOTE: this is a continuing
- Stable at or approaching 547°F action step
- TAVG1A(1B,1C)RCSLOOP
[j TI 412D
[j TI 422D STM DUMP
[]_TI_432D BOP (step I RNO) Verify steam dumps closed. RCS temperature will be STM DUMP INTERLOCK decreasing due to the RCP
[] A TRN in OFF RESET trips and AFW flow OR
[] B TRN in OFF RESET BOP Verify atmospheric reliefs closed 1 A(1 B, I C) MS ATMOS REL VLV
[1 PC 3371A
[] PC 3371B
[1 PC 3371C BOP (step 1 .1.3) IF MSIVs are open, THEN Directs TB SO to wrap up the isolate turbine building steam loads while TB completing steps 1.1.3.1 continuino with RNO steo 1.1.4. 1.1.3.3 17
Op Test No: FA2012301 Scenario # 3 Event # 7 Page 18 of 44 Event
Description:
PK-444A, Pzr Pressure control controller, fails LOW (step 1.1.4) ii- cooldown continues, I I.N pots ..
minimize total AFW flow, maintain > 395 gpm if SG NR AFW FLOW TO IA(1 B,IC) SG levels are <31%
[] Fl 3229A
[1 Fl 3229B
[1 Fl 3229C AFW TOTAL FLOW
[] Fl 3229 fl Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[1 A TRN reset
[] B TRN reset MDAFWP TO INI B/IC SG B TRN
[1 FCV 3227 in MOD Control TDAFWP flow.
BOP (step 1.1.5) IF cooldown continues, THEN Cooldown should be under close main steam isolation and bypass control by this time valves.
BOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step status.
- Verify FRV5 closed Will have to close the Bypass FRVs since P-4 is not present (step 2.2) - MDAFWP AUTO/DEFEAT
[1 IA in DEFEAT
[1 lB in DEFEAT (step 2.3) -Verify BOTH SGFPs tripped (step 2.4) -Verify total AFW flow to the SGs
>395 qpm RO (step 3) Verify ALL RX TRIP breakers OPEN When ESP-O.1 entered OR EEP-O.O step 5 is started, then, at the discretion of the Lead Examiner, move to Event 8.
18
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 19 of 44 Event
Description:
Loss of ALL AC power.
A LOSP event occurs. 1C DG is tagged out, 1-2A DG is supplying power to Unit 2, lB DG does not start. lB DG could be started if required and 2C DG will start per ECP-O.O.
Indications Available:
Annunciators: Recognize indications of Loss of ALL AC power Many and various
- RCPs tripped EPB power indication lights not LIT
- Components not running Time Pos. Expected ActionslBehavior Comments version 25 SRO Recognize Loss of all AC and direct lOAs of ECP-O.
RO/ (step 1) Check reactor tripped. Immediate Operator actions of BOP ECP-O are steps 1 and 2
[] Check reactor trip and reactor trip bypass No power breakers OPEN.
-
[1 Nuclear power FALLING
(step 1.1 RNO) Manually trip reactor.
(step 1.2) IF reactor can NOT be tripped, THEN trip both MG set supply breakers.
[] N1C11EOO5A
[] N1C11EOO5B YES (step 2) Check turbine tripped.
[] TSLB2 14-1 lit
[] TSLB2 14-2 lit
[] TSLB2 14-3 lit
[1 TSLB2 14-4 lit 19
Op Test No.; FA2012301 Scenario # 3 Event # 8 Page 20 of 44 Event
Description:
Loss of ALL AC power.
RO (step 3) Verify RCS isolated.
(step 3.1) Verify normal letdown isolated.
3.1 .1 Verify all letdown line orifice isolation valves CLOSED.
-
LTDN ORIF ISO 45 GPM
[} QIE2IHV8I49A LTDN ORIF ISO 60 GPM
[1 QIE2IHV8I49B
[1 QIE2IHV8I49C OR 3.1.2 Verify letdown line isolation valves -
CLOSED.
LTD LINE ISO
[]QIE21LCV459
[]QIE21LCV46O (step 3.2) WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
(step 3.3) Verify excess letdown line -
ISOLATED.
EXC LTDN ISO VLV
[1 Q1E21HV8153 closed
[]Q1E21HV8154 closed (step 3.4) Verify all reactor vessel head vent valves. CLOSED.
RX VESSEL HEAD VENT OUTER ISO
[]Q1B13SV2213A
[]QIBI3SV22I3B RX VESSEL HEAD VENT INNER ISO
[]QIBI3SV22I4A
[1 Q1B13SV2214B 20
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 21 of 44 Event
Description:
Loss of ALL AC power.
RO (step 4) Verify total AFW flow GREATER Once verified, AFW flow may THAN 395 gpm.
be throttled back if SGWLs are AFW TOTAL FLOW
>31%
[] Fl 3229 (step 4 RNO) Verify TDAFWP running.
TDAFWP STM SUPP FROM 1B(1C) SG
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED j SI 3411A>3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Place TDAFWP STM SUPP FROM lB SG HV3235N26 AND TDAFWP STM SUPP FROM 1C SG to the START position BOP (step 5) [CA] Restore power to any emergency bus.
(step 5.1) Verify supply breakers for major loads on emergency 4160 V busses OPEN. - On EPB
[] BKR DFO1 (IA S/U XFMR TO iF 4160 V BUS)
[]BKRDF15(1BS/UXFMRTO 1F4160V BUS)
[]BKRDF-13-1 (IF4I6OVBUSTIETO1H 4160 V BUS)
[] BKR DGO1 (IA S/U XFMR TO 1G 4160 V BUS)
[] BKR DG15 (lB S/U XFMR TO 1G 4160 V BUS 21
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 22 of 44 Event
Description:
Loss of ALL AC power.
BOP/ [1 1C CCW PUMP BKR DF-04-1 Load shed list continued from RO [1 lB CCW PUMP BKR DF-05-1 above
[] 1 B CCW PUMP BKR DG-05-1 Components on MCB and may
[1 1A CCW PUMP BKR DG-04-1 be verified by RO
[1 1A SW PUMP BKR DK-03-1
[1 lB SW PUMP BKRDK-04-1
[1 1C SW PUMP BKR DK-05-1
[1 1C SW PUMP BKR DL-05-1 U 1D SW PUMP BKR DL-03-1
[1 1 E SW PUMP BKR DL-04-1 U #4 RW PUMP BKR DJ-03-1 U #5 RW PUMP BKR DJ-04-1
[1 #8 RW PUMP BKR DH-03-1
[1 #9 RW PUMP BKR DH-04-1
[] #10 RW PUMP BKR DH-05-1
[] lB CRDM CLG FAN BKR ED-Il-i
[] 1A CRDM CLG FAN BKR EE-13-1 U 1A CS PUMP BKR DF-1 1-1 U lB CS PUMP BKR DG-11-1
[] 1A RHR PUMP BKR DF-09-1
[] lB RHR PUMP BKR DG-09-1
[1 1A CHG PUMP BKR DF-06-1
[] lB CHG PUMP A TRN BKR DF-07-1
[] lB CHG PUMP B TRN BKR DG-07-1
[] 1C CHG PUMP BKR DG-06-1
[] 1A MDAFWP BKR DF-10-1 U lB MDAFWP BKR DG-10-1 BOP Check 1-2A, IC or lB diesel generator NO running for Unit 1.
Perform 2C DG SBO start: Critical task o MSSinMODE1 o USS in UNIT 1 o When load shed has been competed then depress START PB 2C DG will start o Check Unit 1 2C DG output breaker DJO6 closes. YES o Verify breaker DG13 closed. (lG 4160 V bus tie to 1J 4160 V BUS) o Verify breaker DGO2 closed. (1G YES 4160 V bus tie toiL 4160 V bus) o IF IG 4160V bus energized, THEN proceed to step 5.7 YES 22
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 23 of 44 Event
Description:
Loss of ALL AC power.
BOP Verify adequate SW flow.
o Verify two SW PUMPS in energized train RUNNING
- Critical task
[]ATrain(1A iBoriC)
Start ID andlor IE SW
[] B Train (ID IE or IC) pump(s) o IF A train energized, THEN verify SW TO/FROM DG YES BLDG A HDR Q1P16V519/537
-
open.
o IF B train energized, THEN verify YES SW TO/FROM DG BLDG B HDR -
Q1P16V518/536_open.
BOP . Will call DB SO to check 2C Check no running diesel generator lube oil DG temperature annunciator in alarm. (155 ft, DG BLDG local control panel)
SRO IF iF OR 1G 4160 V bus energized THEN go to procedure and step in effect and implement function restoration procedures as necessary.
I, version 43 23
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 24 of 44 Event
Description:
Loss of ALL AC power.
ROl 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.
(step 4) Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[1 ACTUATED status light lit
[1 MLB1 11 lit
[1 MLB1 111 lit version 32 SRO Directs actions in ESP-0.1 per RO/BOP Actions listed below RO (step 1) Check RCS temperature NOTE: this is a continuing
- Stable at or approaching 547° F action step
- TAVG IA(1B,1C) RCS LOOP
[1 TI 412D
[j TI 422D STM DUMP
[1 TI_432D When ESP-0.1 entered OR EEP-0.0 step 5 is started then, at the discretion of the Lead Examiner, move to Event 8.
24
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 25 of 44 Event
Description:
Steam break inside ctmt from lB SG.
When ESP-O.1 entered or step 5 of EEP-0, lB SG will have a Stm Fault inside containment. The IA MSIVs do not auto close so two SGs will be affected until MSIVs are closed. When the Steam Break occurs an Automatic SI will actuate if not already in.
lB CS pump will not auto start due to 20 DG running and past step 2.
Indications Available:
Annunciators: Recognize indications of LARGE Steam BREAK Various and many INSIDE CTMT Fire alarm (MH1) - Ctmt pressure rising Hi ctmt pressure (EEl) (EE2) (EE3) - Przr level decreasing
- SG pressures decreasing
- Dewpoints in ctmt rising
- Ctmt cooler drains increasing Time Pos. Expected Actions/Behavior Comments I, version 43 RO! Immediate Operator actions of EEP-O 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 I it Verify operating diesel generators are being supplied from at least one SW pump.
25
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 26 of 44 Event
Description:
Steam break inside ctmt from I B SG.
(step Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[J ACTUATED status light lit
[] MLB-1 1-1 lit
[] MLB1 111 lit SRO (step 5) Directs continuing into EEP-O at step See page 38, which is at the
5. Tab at end of scenario for Directs the BOP to perform Attachment 2 and 4 actions.
Attachment 2 of EEP-O.
(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig (checked on IPC or P1950, 951, 952, 953,CNMT PRESSURE) 6.1 Verify PHASE B CTMT ISO -
ACTUATED.
[] MLB-3 1-1 lit
[] MLB-3 6-1 lit 6.2 Stop all RCPs.
[1 IA
[1 I B Critical task
[1 IC To start the 1 B CS pump when 6.3 Verify PHASE B CTMT ISO alignment. ctmt press >27 psig or ensure Check containment spray. 2 ctmt coolers are running.
6.4.1 Check CS flow in both trains > 0 gpm. For a stm fault inside ctmt this CS FLOW is the required equipment that
[] Fl 958A needs to be running
[1 Fl 958B FR -Z.l may be entered if >27 psig in Ctmt and the CA step not used RO (step 7) Announce Unit 1 reactor trip and safety iniection 26
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 27 of 44 Event
Description:
Steam break inside ctmt from I B SG.
(L.r ) .U5.
Check secondary heat sink Available o Check total AFW flow> 395 gpm
[1 Fl 3229A
[] Fl 3229B
[] Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level> 31% {48%}
WHEN all SG narrow range levels less than 31 %{48%}, THEN maintain total AFW flow greater than 395 gpm.
WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.
RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.
. Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[] A TRN reset
[1 B TRN reset MDAFWP TO lA/lB/iC SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[1 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 IA(IB,1C) RCS LOOP
[1 TI 412D
[1 TI 422D
[] TI 432D 27
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 28 of 44 Event
Description:
Steam break inside ctmt from I B SG.
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
[1 A TRN in OFF RESET
[1 B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB
[] Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO IA(1B,1C)SG
[j Fl 3229A fl Fl 3229B
[J Fl 3229C AFW TOTAL FLOW
[] Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.6. accomplish this task 28
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 29 of 44 Event
Description:
Steam break inside ctmt from I B SG.
(step 10) Check pressurizer i- - and spray valves.
WHEN pressurizer pressure less than 2335 NOTE: [CAl step psig, THEN verify both PRZR PORVs closed.
Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[1 PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT PRESS P1 472
[1 PRT LVL Ll-470
[1 PRT TEMP TI-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.
I A(1 B) LOOP SPRAY VLV NOTE: [CA] step
[JPK444C
[1PK444D 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.
IC(1A) LOOP RCS WR PRESS
[1 P1 402A
[] P1 403A Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
29
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 30 of 44 Event
Description:
Steam break inside ctmt from I B SG.
[] Check no SG pressure FALLING IN AN
UNCONTROLLED MANNER OR LESS THAN 50 psig.
RNO Go to EEP-2.0, Faulted SG Isolation
, ver 15 SRO Direct transition to EEP-2 or FRP-Z.1 See EEP-2 on page 32 if FRP-Z.1 not entered RO (step 1) Verify PHASE A CTMT ISO -
ACTUATED.
[] MLB-2 1-1 lit
[1 MLB2 1 11 lit (step 2) Check all MLB-2 lights LIT.
-
- Verify containment ventilation isolation.
- Verify all containment purge dampers-CLOSED.
- Verify containment mini purge dampers -
CLOSED.
- Stop MINI PURGE SUPP/EXH FAN.
RO (step 3) Check if containment spray is NOTE: [CA] step required.
- Containment pressure HAS RISEN TO
-
GREATER THAN 27 psig.
- VerifyPHASEBCTMT ISO ACTUATED Critical task
. . 1 B CS Pump will need to be
- Verify containment spray pumps started RUNNING
- Check containment spray flow in both trains > 0 gpm.
-
CS FLOW on Fl 958A and Fl 958B BOP Check all MLB-3 lights - LIT.
30
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 31 of 44 Event
Description:
Steam break inside ctmt from I B SG.
Time Pos. Expected Actions!Behavior Comments RO Stop all RCPs.
BOP (step 4) Verify containment fan cooler alignment.
Verify all available containment fan coolers -
STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED
[] IA NOTE: 1 D ctmt cooler is the
[1 lB-TRIPPED only cooler running
[] 1 C Critical task
[1 iDDID NOT START Start the 1 C and 1 D CTMT Verify associated emergency service water cooler or the 1 B CS pump and outlet valves OPEN.
- 1 ctmt cooler EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[1 QIP16MOV3O24A
[} QIP16MOV3O24B
[1 QIP16MOV3O24C
[1 QIP16MOV3O24D BOP (step 5) Verify MSIV and bypass valves Critical task CLOSE MSIVs.
BOP (step 6) Check if feed flow should be isolated to any SG.
Check any SG pressure FALLING IN AN
-
UNCONTROLLED MANNER OR LESS THAN 50 psig.
Verify all faulted SG main feed stop valves -
CLOSED.
SRO Evaluation IF all SGs faulted THEN
- Only the 1 B SG is faulted maintain 20 aom AFW flow to each SG.
BOP (step 6.4) Isolate AFW flow to all faulted Critical task SGs. Closes MOV3764D and B on Close MDAFWP isolation valves to all faulted the BOP I B MDAFWP to 1 B
SGs. (BOP) SG ISO valves BOP Close TDAFWP flow control valves to all Take HV-3228B pot to 0 faulted SGs.
TDAFWP FCV 3228
[] RESET reset 31
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 32 of 44 Event
Description:
Steam break inside ctmt from I B 5G.
SRO Call to 555-P orTSC to have QIN23VO17B closed in the MSVR
,versionl5 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 1 B 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 1 B SG BOP (step 4) Isolate all faulted SGs.
- Verify 1 B ARV closed - PC3371 B minimum demand
- Verify 1 B SG Feed stop valves closed M0V3232B
- Verify blowdown from all faulted SOs
- ISOLATED. HV 7614B Since the fault is on the 1 B SG, the crew will proceed to step 4.5 SRO (step 4.5) IF 1 B SG faulted, then isolate Will call BOOTH operator to TDAFWP steam supply from 1 B SO have this accomplished
- IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from 1 B_SO_at_hot_shutdown_panel.
BOP (step 4.6) Verify SG blowdown sample ISOLATED MLB lights lit.
IA(1B,1C) SGBD SAMPLE ISO
[j MLBI 19-2 lit Q1P15HV3328 closed
[1 MLBI 19-3 lit Q1P15HV3329 closed
[] MLBI 19-4 lit QI P1 5HV3330 closed 32
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 33 of 44 Event
Description:
Steam break inside ctmt from 18 SG.
Time Pos. Expected Actions/Behavior Comments BOP (step 5) Isolate AFW flow to all faulted SGs. Critical task Close MDAFWP isolation valves to all faulted Closes M0V3764D and B on SGs. (BOP the BOP BOP (step 5.2) Close TDAFWP flow control Critical task valves to all faulted SGs. Close HV3228B pot to 0 AND TDAFWP FCV 3228 call to close VOI7B below.
[1 RESET reset SRO (step 5.3) Call to SSS-P or TSC to have key Z-139 Q1N23V017B closed in the MSVR BOP (step 6) Check CST level greater than 5.3 feet U R-1 5
[] 19 (step 7) Check secondary radiation [1 23Aand B indication NORMAL.
-
II 15B and C,
[1 60 A, B, C, D SRO (step 8) Evaluate SI termination criteria
- Check SCMM indication GREATER THAN 16°F{45°F}
SUBCOOLED IN CETC MODE.
- Check secondary heat sink available.
>395 gpm AFW flow OR
> 31%{48%} SGNR level
- Check RCS pressure STABLE OR
-
RISING
- Check pressurizer level>
I 3%{43%}.
When the Faulted SG is isolated and announcement of SI termination transition identified (ESP-1.1 or EEP-1 return) , then terminate the exam.
SRO Enter EEP-1 or ESP-1 .1 depending on SI See below for both procedure termination criteria actions 33
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 34 of 44 Event
Description:
Steam break inside ctmt from I B SG.
Time Pos. Expected Actions/Behavior Comments version 25 RO (Step 1) Verify SI Reset
[] MLB-1 1-1 not lit (A TRN)
[1 MLB-1 11-1 not lit (B TRN)
RO (Step 2)Stop all but one CHG PUMP.
SRO (Stop 3) Verify RCS pressure STABLE
-
OR Rising 1C(IA) LOOP RCS WR PRESS
[] P1 402A
[1 P1 403A RO (Step 4) Isolate HHSI flow. Verify alignment and change chq pump suctions to the VCT RO (Step 5) Establish normal charging. Align FCV-122 to operation If E EP-1 is entered and the exam is allow d to continue then these actions will be performed.
rev 30 RO (step 1) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}
-
SUBCOOLED IN CETC MODE.
BOP (step 2) Check SGs not faulted. RNO IF affected SG not Check no SG pressure FALLING IN AN isolated then Go to EEP-2 UNCONTROLLED MANNER OR LESS THAN 50 psiq.
34
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 35 of 44 Event
Description:
Steam break inside ctmt from 18 SG.
Time Pos. Expected Actions/Behavior Comments BOP (step 3) Check intact SG levels.
Check any intact SG narrow range level GREATER THAN 31%{48%}.
NOTE: [CA] step WHEN SG narrow range level greater than 31 %{48%}, THEN maintain SG narrow range level 31 %-65%{48%-65%}.
Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[] A TRN reset
[] B TRN reset MDAFWP TO lA/lB/iC SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted BOP (step 4) Check secondary radiation [] R-15 indication NORMAL.
-
[] 19 Checks rad monitors [] 23AandB
[] 15B and C,
[1 60A,B,C,D RO (step 5) Check pressurizer PORVs Check any PRZR PORV ISO power available NOTE: [CA] step WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.
[1 Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT PRESS P1 472
[1 PRT LVL LI-470
[] PRT TEMP Tl-471
[] Check at least one PRZR PORV ISO -
OPEN 35
Op Test No.: FA2012301 Scenario # 3 Event if 9 Page 36 of 44 Event
Description:
Steam break inside ctmt from I B SG.
Time Pos. Expected Actions/Behavior Comments SRO (step 6) Perform the following within I NOTE: These steps are not hour of start of event. required since this is a steam fault event.
SRO (step 7) Evaluate SI termination criteria RNO if all SI termination
[] Check SUB COOLED MARGIN MONITOR criteria is met then go to ESP indication GREATER THAN 16°F{45°F}
1.1, see actions above on SUBCOOLED IN CETC MODE. page 33 Check secondary heat sink available.
[] >395 gpm AFW flow OR
[1 > 31%{48%} SGNR level
[1 Check RCS pressure STABLE OR
-
RISING
[1 Check pressurizer level GREATER THAN I 3%f43%}.
RO (step 8) [CA] Check containment spray system.
Check any CS PUMP STARTED.
-
Reset containment spray signals.
CS RESET
[]ATRN
[] B TRN RO (step 9) [CA] Check if LHSI Pumps should be stopped Check RCS pressure > {435 psig)
-
[] P1 402B
[] P1 403B
- Check RCS pressure stable or rising
- RHR pumps running from RWST
- Verify SI reset.
[] MLB-1 1-1 not lit (A TRN)
[] MLB-I 11-1 not lit (B TRN)
- Stop any RHR Pumps running with suction_aligned_to_the_RWST.
36
Op Test No.: FA2012301 Scenario # 3 Event # 9 Page 37 of 44 Event
Description:
Steam break inside ctmt from I B SG.
Time Pos. Expected Actions/Behavior Comments SRO (step 10) Check no SC pressure - (step 10 RNO) Return to step FALLING IN AN UNCONTROLLED MANNER When the Faulted SG is isolated and announcement of SI termination transition identified (ESP-1.1 or EEP-1 return), then terminate the exam.
37
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 38 of 44 Event
Description:
Attachment 2 of EEP-O Cue: BOP will accomolish when at step 5 of EEP-O AUTOMATIC ACTIONS VERIFICATION Time Pos Expected ActionslBehavior Comments (Step 1) Verify one CHG PUMP in each train STARTED.
-
BOP [j A train (1A or 1 B) amps > 0
[1 B train (1 C or 1 B) amps> 0 BOP (Step 2) Verify RHR PUMPs STARTED.
-
RHR PUMP
[]lAamps>O fl lB amps> 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow GREATER
-
THAN 0 gpm.
fl Fl 943 BOP (Step 3.2) Check RCS pressure LESS THAN 275 psiqf435 psici).
BOP (step 3.3) Check LHSI flow greater than
1.5 XlO gpm 3
[] 1A RHR HDR FLOW Fl-605A
[1 lB RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[]Atrain (1AlBorIC)
[1 B train (iDlE or IC) 38
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 39 of 44 Event
Description:
Attachment 2 of EEP-O Time Pos. ExpectedActións!Behavior omménts BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train- STARTED.
A train HX 1 C or 1 B CCW FLOW
[] F! 3043CA> 0 gpm OR
[] F! 3043BA> 0 gpm Btrain HX1AorIB CCW FLOW
[] F! 3043AA> 0 gpm OR
[] F! 3043BA> 0 gpm Verify SW flow to associated CCW HXs SW FROM IA(IB, IC) COW HX U QI P1 6F!3009AA> 0 gpm
[] QI P1 6F13009BA> 0 gpm U QIPI6FI3009CA> 0 gpm BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[] 3197
[] 3198D
[] 31980 U 3196
[1 3198A
[] 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MIN!-2866C & 28670 FULL-3198A & 3198D
[] 28660 U 2867C CTMT PURGE DMPRS M!N!-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 31980
[1 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 39
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 40 of 44 Event
Description:
Attachment 2 of EEP-O Time Pos Expected Actions!Behayior 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 A tm is not runnincj due to loss
[1 1A of power
[] I B B
Critical task Start 1 C ctmt
ri ID cooler if I B CS not running since only I D ctmt cooler will Verify associated emergency service water be running due to the LOSP outlet valves OPEN. sequencer
-
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] QIPI6MOV3O24A
[] QIPI6MOV3O24B
[] QIPI6MOV3O24C fl QIPI6MOV3O24D BOP (step 8) Verify AFW Pumps STARTED.
-
Verify both MDAFW Pumps STARTED-
[1 IA MDAFW Pump amps> 0
[1 lB MDAFW Pump amps> 0 AND U Fl-3229A indicates > 0 gpm
[] Fl-3229B indicates > 0 gpm 11 Fl-3229C indicates> 0 ciom (Step 8.2) Check TDAFW Pump start required.
[Condition LJTSLB Li Setpoint Li Coincidence[i 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 40
Op Test No: FA2012301 Scenario # 3 Event # 8 Page 41 of 44 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments.
BOP (step 8.3) Verify TDAFWP started.
[1 MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[]Sl 3411A> 3900 rpm TDAFWP SPEED CONT
[1 SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SG.
TDAFWP TO IA(1 BIG) SG
[1 Qi N23HV3228A in MOD fl Qi N23HV3228B in MOD fl Q1 N23HV3228C in MOD TDAFWP TO IA(IB,1C) SG FLOW CONT
[1 HIC 3228AA open
[1 HIC 3228BA open fl HIC 3228CA open BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves CLOSED.
-
IA(1 BIG) SG FW FLOW
[]FCV478
[]FCV488
[1 FCV 498 Verify both SGFPs TRIPPED.
-
Verify SG blowdown ISOLATED.
-
1A(1B,1C) SGBD ISO
[] Qi G24HV761 4A closed
[1 Q1G24HV7614B closed
[] Q1G24HV7614C closed 9.4 Verify SG blowdown sample -
ISOLATED MLB lights lit.
IA(1 BIG) SGBD SAMPLE STEAM GEN ISO
[] MLBI 19-2 lit Q1P15HV3328 closed
[] MLBI 19-3 lit Q1P15HV3329 closed fl MLBI 19-4 lit Q1P15HV3330 closed 41
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 42 of 44 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActinsiBéhavior* 1. Comments BOP (Step 10) Check no MSL isolation actuation signal present.
Sianal Setnoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% 4 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psiq 2/3 TSLB1 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO.
(Step 11.1) Verify PHASE A CTMT ISO -
ACTUATED.
BOP fl MLB-2 1-1 lit fl MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.
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 U NIC1IEOO5A F] N1C11EOO5B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO ACTIONS FOLLOWING A accomplish this.
REACTOR TRIP OR SAFETY INJECTION.
42
Op Test No: FA2012301 Scenario # 3 Event # 8 Page 43 of 44 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected, AtionslBeháviór .,. GommeAts.
BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRAGS Mode Selector Switch
[JATRAIN
[1 B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR
[] 810- OPEN
[1 914- OPEN BOP (step 17) Verify two trains of ECCS SEE page 44 equipment aligned.
Perform ATTACHMENT 4, TWO TRAIN EGGS ALIGNMENT VERIFICATION.
End of Attachment 2 43
Op Test No.: FA2012301 Scenario # 3 Event # 8 Page 44 of 44 Event
Description:
Attachment 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.
[] Check DFO1 closed
[1 Verify DFO2 closed
[1 Check DG15 closed U Verfiy DGO2 closed
[] Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.
-
CHG PUMP DISCH HDR ISO
[] Q1E21MOV8132A
[] Q1E21MOV8132B
[] QIE2IMOV8133A
[] QIE2IMOV8133B CHG PUMP SUCTION HDR ISO
[] Q1E21MOV813OA
[] Q1E21MOV813OB
[] Q1E21MOV8131A
[] QIE21MOV8131B (Step 1 .7) Verify all post accident containment air mixing system fans STARTED. (BOP)
-
POST ACCIDENT MIXING FANs RX CAV H2 DILUTION FANs (Step 1.8) WHEN power restored to any de energized emergency bus, THEN verify alignment of associated equipment.
BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
End of Attachment 4 44
Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2012-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.
In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
AssiQn orerating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-2 IXiUniti [lUnit2 Shift: Date j Off-going SS - I Oncoming SS j [ ] N [ X] D Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, 5, D, SW, X on key ring. SS Unit 4% power, UOP-I.2, v102, completed thru step 5.57, Ready to perform step 5.58. EOL, 449 ppm Cb, Status 18,000 MWD; IA SGFP on service. Aux steam from U-2.
STPslEvolutions. B Train On-Service B Train STP-27 I completed 2 Protected hours_ago 1.0; 109.1 No adi.; 63.7; FSP-20,0 Status of Special Testing I A CTMT cooler was isolated for leak detection per and will be returned to service per SOP-I 2.1.
General Information
1. Return IA Ctmt Cooler to service per SOP-12.1 ver. 41.0, step 4.1.
2. Plant startup is on hold for turnover and will recommence after the turnover is complete.
3. PLANT Management has approved Mode 1 entry.
4. Ramp up to 12% reactor power.
5. 1C DG is Tagged Out for slow start investigation.
6. Current Risk Assessment is and projected is 7.
8.
9.
Equipment Status 1 C DG T/O for slow start Maintain VCT gas pressure 25-30 psi 9 investigation.
Reactivity Plan Waste Manager ent Status I #3 RHT On Service
WGS secured
LCO Status 3.8.1 condition B, STP-27.I completed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago 3.6.6 ADMIN LCO for 1A Ctmt cooler isolated Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-I .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[X]Yes [XjYes [X}Yes [X]Yes {X]Yes [X]Yes
Scenario #4 FA2O1 2301 Southern Nuclear JIM. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #4 Still need to stabilize snap or dilute 100 gallons prior to start Validation time: 110 minutes Validated by David Shiprnan, Todd Smith and Doug Jimmerson The week of February 13. 2012 TRN Supervisor Approval: Gary Ohmstede Date: 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTHERN COMPANY
Appendix D Scenario #4 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 4 Op-Test No.: 2012-301 Examiners: Operators: SRO RO BOP Initial Conditions: 29% power, 1 172 ppm, BOL 4000 MWD!MTU Turnover:
. A seismic event has occurred. Ramp down at 2 MW/MIN was in progress and is now on HOLD for turnover.
. 1-2A DG is T/O due to the crankcase being cracked and oil draining out of DG.
. 1A MDAFW pump has a cracked pump casing, was leaking and is tagged out.
Current Risk Assessment is YELLOW and projected is YELLOW due to the 1A MDAFW pump and 1-2A DG issues.
. A Train On-Service A Train Protected.
. Earthquake recovery is in progress.
SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.
imf (I) (RO) FT-122, charging flow transmitter, fails HIGH 1
ri ba- C (BOP) CST rupture base plate crack from bottom to top will place 2 cfwOOl SW on AFW suctions TS (SRO) TS 3.7.6 condition A imf (I) (RO) TK-144 fails HIGH. TCV-143 fails to divert on high temperature.
3 TK144 Controller can NOT be controlled in manual. Letdown will have to be secured.
4 N (BOP) Place Excess letdown on service lAW AOP-16.
ml TS (SRO) 10 SG tube leak 5 gpm over 3 mm and stabilizes
mal- TS 3.4.13 Condition B rcs4c N (BOP)
R (RO) Commence ramp off line lmf C (BOP) Main Turbine Lube Oil Temperature Controller Auto Output 6 CP405 Failure LOW 5H-A Bat C (BOP) This causes High Vibration on Main Turbine of >15 mils.
2012nr 7 cexam AOP-3.0 entered to trip the Main Turbine and decrease Rx power to 8%.
Farley June 2012 exam Page 2 of 14
Appendix D Scenario #4 Outline Form ES-D-1 imf M (ALL) Main Steam header break in Turbine Building after Rx power is mal- stable near 8%.
mss9 8 AOP-14 Rx trip required. (CT)
C (BOP) 1C SG MSIVs will not auto close, manual closure required.
(CT) imf M (ALL) 10 SGTR 400 gpm when Reactor is tripped.
9 mal rcs4c Safety injection required. (CT)
Terminate when cooldown and depressurization complete (CT)
(N)ormal, (R)eactivity, (I)nstrument, (c)omponent, (M)ajor Farley June 2012 exam Page 3 of 14
Appendix D Scenario 4 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 Load in IC-214 Base IC is IC-39 RUN RUN simulator 0 0 Generic setup:
bat generic_setup_H LT.txt 0 0 Quick setup (all items with
are included) bat 20l2nrcexam 04 txt PRESETS 8 0 Rx trip breakers fails to open in auto but will open manually:
CMFmalf I cBKRXTRP_cc5 open CMFmalf I cBKRXTRP cc6 open 8 0 RTB handswitch #1 will not work
lmf cbkrxtrp oposi open 0 0 Fail auto SI signals, Manual SI works
CMFmalf I csftyinj_ccl / open CMFmaIf/ csftyinj_ccl 1 / open 0 0 Main Turb fails to auto trip
lmf MAL-TUR2 7 8 1 C MSIVs will not close on auto closure
CMFmalf / crshOOl c_cc5 !open CMFmalf I cmshOO2c_d_cc5 Iopen 4 4 TCV-143 fails to divert on High temperature
lmf ccvtl43_d_ccl closed 0 0 Tag 1-2A DG output breakers for Unit I & 2
rack out 1-2A DG DFO8-1 rack out 1-2A DG DFO8-2 CMFremote I cbkldfo8_d_cdl I open CMFremote I cbk2dfo8_d_cdl I open 0 0 Tag 1AMDAFWpump
irfcafpola d_cdl open Triggers and_Commands 3 Trigger 1: When CST level < 14.1 decrease CST to 0 feet over
3 300 seconds.
Event: bcfwl32b < 14.1 Command: irf loa-cfwOOl 0 300 8 Trigger 3:IC 400 gpm SGTR ramped in over 60 seconds when
9 when Rx trip breakers open trg set 3 j52rtao && j52rtbo Command: imf mal-rcs4c 400 60 Farley June 2012 exam Page4ofl4
1-2A DC Mode selector switch 3 Place HOLD Taci 1-2A MSS 1 HOLD TAG Place HOLD Taq on 1-2A DC output breakers 2 HOLD TAGS Place HOLD tag on IA MDAFW pump handswitch 1 HOLD TAG Place Unit 1 Bypass and Inoperable Panel light to the up Unit I A-Train oosition (AFW SYSTEM)
Place Unit 1 and Unit 2 Bypass and Inoperable Panel Unit 1 A-Train lights to the up position (EMERGENCY POWER Unit 2 A Train SYSTEM)
DEH Clear DEH alarms 11V11I II it I L IL Ii I In 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 snreadsheet nrovided Recorders Verify memory disks cleared Provide a marked up copy of UOP-3.1 version 111.1 UOP-3.1 and UOP-2.1 through step 8.16 complete and UOP-2.1 version copy 71.0 step 5.1 is N/A: at steD 5.3
-I FREEZE simulator Perform Booth Oierators SetuD Checklist Open Simview file to be used for plant parameter data collection:
Simview I sv DataCollection.uvl sv flfnIInf inn iiiI If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv simclock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 5 ofl4
Appendix D Scenario 4 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Prior to 0 RUN Start data collection for Simview file On DataCollection.uvl file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam J
J simulator ON: hornflag Turn Horns ON/OFF
ORNS ON = TRUE ann horn 1 FT-122, charging flow transmitter, fails HIGH lmfftl22 150 50 NRC CST rupture base plate crack from bottom to top will 2 CUE place SW on AFW suctions 4minto istalarm Remote/N21 /irfloa-cfwOOl /14/300 second ramp CST level will drop to 0 over a slower time frame when the CST level reaches 14.1 F / N21 / irf loa-cfwOOl I 0 / 300 second ramp.
Note (CST level rate of change is automatically Caption C f level adjusted on TRG 1. Button is Variable = bcfwl32b backup) 3 TK-144 fails HIGH. TCV-143 fails to divert on high temperature. lmfTKl44-D! 10 /60 5 mm to 1st alarm 4 Place Excess letdown on service lAW AOP-1 6.
5 10 SG tube leak 5 gpm over 3 mm and stabilizes Malf I M / imf mal-rcs4cl 5 /180 Commence ramp off line NRC Main Turbine Lube Oil Temperature Controller Auto 6 CUE Output Failure LOW CP-4055 CNH I lmf CP4055H-A 0 45 Takes 2 minutes till first alarm -----
Farley June 2012 exam Page 6 of 14
Appendix D Scenario 4 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC Main Turbine High vibrations CUE Bat 201 2nrcexam_highvibs.txt 8 NRC Main Steam header break in Turbine Building.
CUE - imf mal-mss9 1.5 300 8% Rx power AOP-14 Rx trip and safety injection required. (CT) 1C SG MSIVs will not auto close, manual closure required. (CT) 9 preset 1C SGTR 400 gpm when Reactor is tripped.
imf mal-rcs4c 400 60 IC SG overfill variable 11 when > 0.995): TRG 3 t]
CONDITIONAL: AFW MONITOR AFW suction, if 0 psig for> 3 miiis then, with pumpswillbeTRlPPED . ,
(seize) if running without a Examiner s direction, TRIP the Running AFW pumps; suction source for>3 NO suction source aligned.
mins. IF conditions met then:
Simulator will not model a failure of AFW pumps if run without suction . .
. CMFmaIf/ cAFPO1 B_dccl 3 2 source. IF 0 psig for> 3 mins then trip the MDAFW pump MaIf/mal-FWM1C T IF 0 psig for> 3 mins then trip the TDAFW pump Terminate when cooldown and depressurization complete (CT)
End of Exam HORNS OFF
i FREEZE simulator Stop data collection for Simview file Parley June 2012 exam Page7ofl4
Appendix D Scenario 4 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND sv_DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.
grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
Farley June 2012 exam Page 8 of 14
Appendix D Scenario 4 Local Operator Action sheet Form ES-D-l Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 WHEN REQUESTED Secure SGBD bat 2ol2nrcexam_sgbdiso txt AFTER a short delay, RADSIDE SO: Direct the MCR to Close HV76I4AIB/C per step 4.3.3 of SOP-16.l 3 NONE REQUIRED 4 Acknowledge MK4 Liquid waste panel alarm 5 NONE REQUIRED 6 NONE REQUIRED 7 WHEN REQUESTED TBSO:
I have locally tripped the main turbine.
MALF / T/ MAL-TUR2/ DELETE MALF / T / MAL-TURI 7 IF REQUESTED TBSO:
I have opened the condenser vacuum breaker isolation valves NIN51V5I8A and 518B.
REMOTE / N21 TLOA-CFWO12 / 100 /20 sec ramp 8 NONE REQUIRED 9 WHEN REQUESTED ROVER:
Place in local and close at HSP F: TDAFWP STM SUPP FROM IC SG, Q1N12HV3235B.
Farley June 2012 exam Page 9 of 14
Appendix D Scenario 4 Local Operator Action sheet Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS Farley June 2012 exam Page 10 of 14
Appendix D Scenario 4 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
IF REQUESTED Radside SO:
The charging pump looks fine and FCV-122 is about 15% open.
DISPATCHER:
- Acknowledges when informed that the CR is in the queue.
2 When the CST low level DBSO:
alarm comes in report: The CST base plate has a large crack in it and water is gushing out of the hole. There is no way to stop the leak.
When requested for SGBD- see LOA page Radside SO:
to secure SGBD SGBD is secured.
SM:
I will make notifications as required.
3 WHEN REQUESTED Chemistry: will be asked to respond to high temperature in Demineralizer beds.
We will sample the demin bed that was on service and let you know the sample results. Leave TCV-144 bypassing the demins until we get a sample back.
We will secure ZAS.
HP:
- We will monitor radiation readings in the Aux building and repost the areas as radiation levels rise.
4 WHEN REQUESTED RADSIDE SO:
TCV-144 is fully closed and the letdown piping is slightly brown and very warm.
If requested to BYPASS COW for the letdown Hx, then say,the handwheel for the bypass valve is missing.
The RCDT system is in operation lAW SOP-50.
To the OATC, Go to OPEN and back to AUTO on LCV-1 003 When 10 minutes have passed TCV-143 no problem locally When 10 minutes have passed, call OATC to report that 300 gallons has been flushed to the RCDT.
When asked about MK4, alarm is due to high RCDT level.
Farley June 2012 exam Page 11 of 14
Appendix D Scenario 4 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME Communication:
5 WHEN REQUESTED AOP-2.O communications- HP and shift radiochemist, counting room, and SM will all be notified.
DISPATCHER:
I will place SJAE on service.
Radside SO:
I will secure SGBD.
6 WHEN REQUESTED TBSO:
I have walked down the turbine and am finding all lube oil temperatures higher than normal.
Monitor temperatures on SIPC. Under U2 UO or Extra Operator: (This assumes KK4 NOT in alarm)
SYSTEMS click on the All the journal bearing temperatures and thrust bearing Main Turbine button. temperatures are elevated, but none are in alarm.
Subtract 5°F from a journal bearing to get a If KK4 in alarm bearing closest to 21 0°F report as being
temperature for a thrust some value> °F but less than 220°F.
bearing.
7 IF REQUESTED DISPATCHER:
Acknowledge ramping down and off line.
Booth prompt (if TBSO:
necessary) The vibration seems to be getting worse.
IF REQUESTED TBSO:
I have locally tripped the main turbine.
8 IF REQUESTED TBSO:
There is a lot of steam in the Turbine Building 155 by the EH skid.
WHEN REQUESTED SM:
I will make the classifications and notifications.
EXTRA CONTROL ROOM OPERATOR:
Both CRACS mode selector switches are in ON.
ANY CALL TO SHIFT CHEMIST:
Acknowledge to requirement for sampling.
TBSO:
Back up cooling to the Cond pumps is aligned.
Other routine calls - provide appropriate information Farley June 2012 exam Page 12 of 14
Scenario 4 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 29% power, 1172 ppm, BOL Turnover:
A seismic event has occurred. Ramp down at 2 MW/MIN was in progress and is now on HOLD for turnover.
1-2A DG is T/O due to the crankcase being cracked and oil draining out of DG.
1A MDAFW pump has a cracked pump casing, was leaking and is tagged out.
Current Risk Assessment is YELLOW and projected is YELLOW due to the 1A MDAFW pump and 1-2A DG issues.
A Train On-Service A Train Protected.
Earthquake recovery is in progress.
Event 1 FT-122 fails HIGH AOP-16 entry.
Verifiable actions: Take manual control of FCV-1 22 before Pzr level decreases to out low and control Przr level Event 2 CST rupture base plate crack from bottom to top TS 3.7.6 condition A Verifiable actions: place SW on AFW suctions per SOP-22.0 (PRA - 10.4 1AFOP-SW-ALG NH)
Event 3 TK-144 fails HIGH. TCV-143 fails to divert on high temperature. Controller cannot be controlled in manual. Letdown will be secured and AOP-16 will be entered to place excess letdown on service.
Verifiable actions: Close letdown orifice isolation valves, stop the ramp and enter AOP-16.
Event 4 Place Excess letdown on service lAW SOP-2.7.
Verifiable actions: Open isolation valves and control flow to control temperature <165F.
Event 5 1C SG tube leak 5 gpm over 3 mm and stabilizes TS 3.4.13 (d) 150 gallons per day primary to secondary LEAKAGE through any one SG. Condition B Verifiable actions: Commence ramp off line RO will adjust rods or boron to control Tavg/Tref on program, BOP will set up and start a ramp on the Main Turbine. Due to the FT-I 22 failure it is difficult to verify leak rate.
Event 6 Main Turbine Lube Oil Temperature Controller, CP-4055, Auto Output Failure LOW Verifiable actions: place CP-4055 in manual and open per skill of the craft.
Event 7 Main Turbine vibrations will increase to >15 mils AOP-3.0 entered to trip the Main Turbine and ramp to 8% power.
Verifiable actions: Main Turbine trip, rods shimmed in, Rx power reduced to 8%, in preparation to place steam dumps in the STM PRESS mode.
Event 8 Main Steam header break in the Turbine Building when Rx power at 8%.
AOP-14 Rx trip required. (CT) 1 C SG MSIVs will not auto close, manual closure required. (CT)
Event 9 1C SGTR 400 gpm when MSIVs Reactor is tripped and safety injection required. (CT)
AOP-16 I ARP-JD4&JE4 I SOP-22 I AOP-2.0 I AOP-14.0/ AOP-3.0 I LEP-0 / EEP-3.0 Farley June 2012 exam Page 13 of 14
Scenario 4 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
1. Actuate a manual Rx trip prior to SI (WOG CT E-0 - - A) (PRA - 10.29 1 RTOPMANRT
--H)
2. Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-0 - - D)
Transition to any E- 3 series procedure, as appropriate
3. Isolate 1C MSIV in EEP-3.0 before a transition to ECP-3.1 occurs. (WOG CT E-3 - -
A) (PRA 10.63 CAl_A_i
- H)
4. Depressurize the RCS to meet SI termination criteria before SG overfill parameters are exceeded. (WOG CT E-3 - - C)
SCENARIO Low power scenario at 29% and failures during a seismic event where a ramp OBJECTIVE! down is required.
OVERVIEW: While at 29% power, the team will have to:
respond to several instrument and component problems using the appropriate ARP5, AOP-100 and AOP-16.
shift suctions of AFW pumps to the SW system, respond to a SGT leak per AOP-2.0 and ramp down with Charging flow in manual
respond to a Steam Break in the MSVR per AOP-14 and trip the reactor, safety inject the plant and close MSIVs, then
respond to a SGTR from the 1C SG, then cooldown and depressurize the RCS using EEP-3.0.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
1. Total malfunctions (58) 9
2. Malfunctions after EOP entry (12) 2
3. Abnormal events (24) 6
4. Major transients (12) 2
5. EOPs entered/requiring substantive actions (12) 1
6. EOP contingencies requiring substantive actions (02) 0
7. critical tasks (23) 4 Farley June 2012 exam Page 14 of 14
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 4 Event # 1 Page 1 of 42 Event
Description:
FT-122, charging flow transmitter, fails HIGH FT-I 22 will fail high. This will cause FCV-122 to open fully but the indication to show 0 gpm. The crew will use AOP-I 6 to restore control of Charging flow and charging will remain in manual for the entire scenario.
Indications Available:
Annunciators: Recognize indications of FT-i 22 FAlLING CHG HDR FLOW HI-LO (EA2) LOW REGEN HX LTDN FLOW DISCH TEMP - FT-i 22 will indicate >0 gpm (pegged low)
HI (DEl) (possible if not discovered in a - VCT level will 4.
timely manner) - Przr level will 4. slowly
- FK-122 demand will go to approx. 0
- LK-459F will 4. slowly Time Pos. Expected Actions/Behavior Comments 17.0 SRO Determine a charging system malfunction is occurring and direct entry into AOP-l 6.
RO - Monitor VCT level
- Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation
- P1-121 and ammeter for chg pump
- Actual amps will be lower than normal RO (Step 1) Verify charging flow adequate to cool letdown.
RNO close all LTDN ORIF ISOs
Letdown flow may or may not
[1 Q1E21HV8149A be secured
[1 Q1E21HV8I49B
[1 QIE2IHV8149C RO (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained I
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 4 Event # I Page 2 of 42 Event
Description:
FT-I 22, charging flow transmitter, fails HIGH Time Pos. Expected ActionslBehavior Comments RO (Step 4) [CA] Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.
[1 P1-121
[1 AMMETER FOR RUNNING CHG PUMP RO (Step 5) Check charging pump RUNNING YES RO (Step 6) Check Charging flow FK-1 22 The answer to this question controlling in AUTO with flow indicated is NO.
RNO- FT- 122 taken to manual control An incorrect determination here will cause the crew to There will be flow indicated and 122 in AUTO place 122 on the bypass.
- Seal mi flow will increase due to FCV122 going closed.
RO (Step 7) Check DE3 clear RO (Step 8) Determine Status of Normal Letdown may have been Letdown: removed from service so it Check normal CVCS letdown AFFECTED
-
might have to be placed in BY MALFUNCTION service when FCV-122 control LTDN HX OUTLET FLOW, Fl150, NO is regained.
FLOW INDICATED (Step 8.2) Minimize RCS makeup:
Manually close charging flow control:
CHG FLOW
[1 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- manual control of FCV Check normal letdown malfunction(s) - 122 established CORRECTED 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # I Page 3 of 42 Event
Description:
FT-I 22, charging flow transmitter, fails HIGH Restore letdown with the following steps: IF ISOLATED RO (Step 9.2) Verify all letdown orifice isolation If not isolated go to step 18 valves CLOSED on page 5 LTDN ORIF ISO 45 GPM
[] Q1E21HV8149A LTDN ORIF ISO 60 GPM
[1 Q1E21HV8I49B
[] Q1E21HV8I49C (Step 9.3) Place LP LTDN PRESS PK 145 on service:
[1 Place controller in MANUAL
[J Adjust demand signal to 50% or less (Step 9,4) 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-1 1 5A alignment:
[] Position indicator VCT light LIT
-
[1 Handswitch in AUTO
-
RO (Step 9.6) Verify LTDN HI TEMP DIVERT VLV Q1E21TCVI43:
[] DEMIN light LIT
-
[1 Handswitch in AUTO
(Step 9.7) IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the PRIP.
[1 Q1E21HV8I75A
[1 Q1E21HV8I75B (Step 9.8 Verify LTDN LINE CTMT ISO Q1E21HV8152 OPEN -
(Step 9.9 Verify LTDN LINE ISO valves -
OPEN
[1 Q1E21LCV459
[j Q1E21LCV46O 3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 1 Page 4 of 42 Event
Description:
FT-I 22, charging flow transmitter, fails HIGH 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:
l1 1 Orifice 18 gpm
-
OR LJ 2 Orifices 40 gpm
-
(Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:
[]Q1E21HV8149B OR Ii Q1E21HV8149C RO (Step 9.12) [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 9.13) Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -
BETWEEN 260-450 PSIG RO (Step 9.13.1) Set controller between 4.3 and 7.5 (Step 9.13.2) Check letdown flow STABLE
(Step 9.13.3) Place PK 145 in AUTO (Step 9.13.4) Control Letdown pressure as desired (Step 9.14) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.
[1 TI-i 16 VCT TEMP
[] Tl-i43 DIVERT LTDN HX TEMP
[1 TI-i 44 CCW LTDN HX TEMP (Step 9.15) 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
-
4
Appendix D Operator Action Form ES-D-2 Op Test No: FA2012301 Scenario # 4 Event # 1 Page 5 of 42 Event
Description:
FT-122, charging flow transmitter, fails HIGH Time Pos. Expected Actions/Behavior Comments RO (step 10.2) Go to procedure and step in effect RO (step 18) Determine Charging Status: Continue here from step 9 Check charging AFFECTED BY
- RNO if letdown not removed MALFUNCTION from service.
. CHG FLOW, Fl-i 22A ABNORMAL
-
FLOW INDICATED Check Charging flow controlled
[1 FK-122 in AUTO OR
[1 FK-122 in MANUAL (step 19) Check VCT outlet isolation valves OPEN
[]LCV115C and 115E (step 20) Verify charging pump suction header aligned:
[1 Qi E21 MOV81 30A open
[] Q1E21MOV813OB open
[1 Q1E21MOV8131A open
[1 Q1E21MOV8131B open (step 21) Verify charging pump discharge flow path-ALIGNED CHG PUMP DISCH HDR ISO
[]Q1 E21 MOV81 32A open
[]Q1E21MOV8132B open
[1 Q1E21MOV8133A open
[]Q1E21MOV8133B open CHG PUMPS TO REGENERATIVE HX
[j Q1E21MOV81O7 open
[]Q1E21MOV81O8 open (step 22) [CA] Maintain pressurizer level between 20-60%:
Check pressurizer level STABLE 5
Appendix D Operator Action Form ES-D-2 Op Test No: FA2012301 Scenario # 4 Event # 1 Page 6 of 42 Event
Description:
FT-I 22, charging flow transmitter, fails HIGH Time Pos. Expected Actions/Behavior Comments (step 23) Check charging flow ESTABLISH ED (step 24) Determine normal letdown established Step 25 is NA (step 26) Go to procedure and step in effect.
SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)
Notify the Shift Manager At the discretion of the Lead Examiner move to Event #2.
6
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 2 Page 7 of 42 Event
Description:
CST rupture base plate crack from bottom to top CST level will decrease over a 5 mm time frame to 14 feet. The first alarm comes in at 16 feet so if the crew does not notice the decreasing level, the first alarm will be at about the 4 minute mark.
The DBSO will be sent out to look for the problem and then a report will be given about a crane accident. The CST level will continue to fall to 0 feet.
Indications Available:
Annunciators: Recognize indications of CST LEVEL
- CST LVL HI-LO (JE5) Decreasing:
- CST LVL LO-LO A TRN and B TRN (JD4 - Ll-4005 B decreasing and JE4) - Computer alarms Time Pos. Expected ActionslBehavior Comments 150,000 gallons = 12 feet VE -47.
SRO Direct ARP reference (JE5) and a call to the DBSO to look for problems.
BOP (JE5 step 2) manually close CP-4055F HOTWELL FILL CONTROLLER, to avoid collapsing tank diaphragm.
BOP (JE5 step 3) IF CST level is low, and SGBD is on service, THEN secure SGBD.
(JE5 step 4) Call Radside SO and have SGBD secured BOP (JE5 step 7) Direct DBSO to commence filling the tank (Unless report of ruoture has come in SRO (JE4.JD4 step 1) Monitor condensate storage tank level on Ll-4005B, Ll-41 32A and LI-41 32B to verify validity of alarm Direct BOP to monitor this issue SRO (JE4.JD4 step 2) Make a decision to do the See page 15 for SOP-22, followinci: version 64, section 4.7 actions IF Auxiliary Feedwater is required and Tank Level if < 5.3 feet, THEN shift Auxiliary Feed Pump Suctions to the Service Water System per SOP-22.0, AUXILIARY FEEDWATER SYSTEM.
7
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 2 Page 8 of 42 Event
Description:
CST rupture base plate crack from bottom to top Time Pos. Expected ActionslBehavior Comments SRO (JE4 JD4 step 9) Evaluate Tech Specs 3.7.6 condition A Verify by administrative means OPERABLILITY of backup water supply w/l 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and restore the CST to OPERABLE status w/I 7 days c...... i.....I.....
- -S---.
... r.....j..
I TE CHNIC,AL SPECIFICATION 3.7.6, Condensate Storage Tank (CST)
The CST shall be OPERABLE. (> 150,000 GAL)
SRO
(.(JNU1 I I(JIV REQUIRED ACTION COMPLETION TIME A. CST A. 1 Verify by administrative 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable. means OPERABILITY of AND backup water supply. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND thereafter A.2 Restore CST to OPERABLE status. 7 days SRO Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
SRO Inform the SM of the failure and Tech Spec entry
&siui1 68 BOP (step 4.7.1) Notify Shift Chemist that SW will be added to the SGs.
BOP (step 4.7.2) Verify service water is in operation per SQP-24.0, SERVICE WATER SYSTEM maintaining proper SW pressure.
BOP (2504-N) or Back panel handswitches BOP (step 4.7.3) Open MDAFWP SW SUPP:
(BOP key operated switches)
[1 M0V3209A
[1 M0V3209B 8
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 2 Page 9 of 42 Event
Description:
CST rupture base plate crack from bottom to top Time Pos. Expected ActionslBehavior Comments BOP (step 4 7.4) Open: (BOP)
[1 MDAFWP SW SUPP MOV321OA
[1 MDAFWP SW SUPP MOV32IOB
[1 TDAFWP SW SUPP M0V3216.
BOP (step 4.7.5) Place AFW system in operation per section 4.1 or 4.3 of this SOP.
When SW is aligned to the AFW pumps and Tech Specs have been evaluated then move to Event #3.
9
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 3 Page 10 of 42 Event
Description:
TK-144 fails HIGH TK-144 fails HIGH, and TCV-143 does not divert to bypass the demins. This failure does NOT allow manual control of TCV 144 and therefore letdown will have to be secured.
Indications Available:
Annunciators: Recognize indications of TK-144 failing high
- LTDN TO DEMIN DIVERTED-TEMP HI - TI-143 indicating off scale high (>200°F)
(DF1) - Tl-144 indicating off scale high (>200°F)
- Possible boration and RCS temperature decrease if prolonged Time Pos. Expected ActionslBehavior Comments rev 52.1 SRO Direct entry into DFI ARP RO (step 1) Verify Q1E21TCV143 has diverted NO letdown flow to VCT to bypass demins
- TCV-143 white light LIT (VCT) on MCB (step 2) Monitor charging and letdown flows and temperatures.
Fl 122, Fl 150, TI 140, TI 144 and 143 (step 3) Try to take manual control of TCV will not be able to take 144 manual control of TCV-I 44 (step 4) Adjust charging or letdown flow as required to reduce the letdown flow temoerature.
SRO (step 6) Direct removing letdown from service by closing LTDN ORIF ISO 45 (60)
GPM Q1E21HV8149A, B, and C (step 7) Direct placing ramp on HOLD (steo 8 Direct enterina AOP-16 ver 1 .0 RO (Step 1) Verify charging flow adequate to cool letdown.
RNO close all LTDN ORIF ISOs
Letdown flow is secured
[] Q1E21HV8149A
[] QIE2IHV8I49B F] QIE2IHV8149C 10
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 3 Page 11 of 42 Event
Description:
TK-144 fails HIGH Time Pos. Expected ActionslBehavior Comments RO (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained RO (Step 4) [CA] Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.
[1 P1-121
[1 AMMETER FOR RUNNING CHG PUMP RO (Step 5) Check charging pump RUNNING YES RO (Step 6) Check Charging flow FK-122 YES controlling in AUTO with flow indicated RO (Step 7) Check DE3 clear YES RO (Step 8) Determine Status of Normal Letdown will have been Letdown: removed from service Check normal CVCS letdown AFFECTED
-
BY MALFUNCTION
- LTDN HX OUTLET FLOW, Fl-i 50, NO FLOW INDICATED (Step 8.2) Minimize RCS makeup:
Manually close charging flow control:
CHG FLOW
[1 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 jf desired due to plant conditions, THEN See page 12 SRO place excess letdown in service using SOP-2.7, CVCS EXCESS LETDOWN Event #4 (placing excess letdown in service) will be entered from AOP-16.
11
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 4 Event# 4 Page 12 of 42 Event
Description:
Place Excess letdown in service Excess Letdown will be olaced in service oer SOP-2.7 Indications Available:
Annunciators: Recognize indications of LT-461 failing high slowly:
PRZR LVL HI B/U HTRS ON (HA2)
LT-459, 460, Actual Przr level decreasing
-
-
PRZR LVL HI RX TRIP ALERT (HAl)
Fl-122 slowly lowering
-
-
CHG HDR FLOW Hl-LO (EA2)
VCT level rising
-
-
Time Pos. Expected Actions/Behavior Comments FiiT CAUTiON: Do not exceed 165° F excess letdown heat exchanger outlet temperature. I Excess letdown flow will be limited to approximately 10-15 gpm.
SOP (step 4.1.11.2) Verify the RCDT system in Will call Radside SO and operation per SOP-50.0, LIQUID WASTE check on status and notify the PROCESSING SYSTEM SO to expect an increase in RCDT level due to excess letdown being placed on service.
SOP (step 4.1.31.41.5) Verify the following valves open:
- HV3095
- HV3443
- HV3067 (step 4.1.6) Verify HV-1 37 is closed (step 4.1 .7/.8) Open HV 8153 and 8154 (step 4.1.9) Place excess letdown divert valve Q1E21HV8143 control switch in the RCDT position (step 4.1 .10) Slowly throttle open the excess LTDN HX discharge valve QIE2IHCVI37 to establish excess letdown flow not to exceed 165° F excess letdown heat exchanger outlet temperature 12
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 4 Page 13 of 42 Event
Description:
Place Excess letdown in service Time Pos. Expected Actions/Behavior Comments SRO Should read the Caution in the procedure CAUTION and speak to reactivity changes associated A small portion of excess with placing excess letdown on service. letdown piping can not be flushed to the RCDT (calculated to be approx. one gallon) and there are Should decide and brief the crew on aligning uncertainties associated with excess letdown to the VCT/Charging pump achieving a complete flush.
suction and the expectations on this. This is Therefore, the reactivity affects not required to be done since it will take a associated with directing significant amount of time to do this excess letdown to the evolution. VCT/Charging pump suction must be considered and contingencies established for mitigating the consequences.
SRO Direct crew back to AOP -16.
SRO AOP-1 6 (Step 9) Determine if normal letdown should be re-established:
Check normal letdown malfunction(s) -
NO CORRECTED RO (step 10) Determine status of letdown Excess letdown established flow: Check letdown flow established
-
SRO (step 10.2) Go to procedure and step in effect When Excess letdown is in service and at the discretion ot the Lead Examiner move to Event #5.
13
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 4 Event # 5 Page 14 of 42 Event
Description:
IC SG tube leak 5 gpm over 3 mm and stabilizes IC SG tube leak will start and ramp in over 3 minutes.
Indications Available:
Annunciators: Recognize indications of SG TUBE LEAK
- SG TUBE LEAK ABOVE SETPT (FG1) - R-15, 19 AND 23 IN ALARM
- RMS HI RAD (FH1) - R-70C READING> 1000 GPD Time Pos. Expected Actions/Behavior Comments version 68 BOP Reference ARP FH1 FG1 has much of the same (step 1) check R-70s to determine SG in actions alarm.
(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.
SRO R-15 alarms AND remains above the alarm setpoint (not a momentary spike),
THEN perform the following:
IF high effluent activity is possible, THEN implement EIP-9.0, ACTIONS.
Notify the Counting Room to immediately Call Counting Room sample the SGs per CCP-31 to determine the leak rate.
Notify the Operations Shift Manager. Call SM BOP IF R-19 alarms refer to SOP-45.0 for Call shift chemist guidance in sampling SGs with R-19 in alarm.
IF R-23A OR R-23B alarms, contact the Call Radside SO RAD man to verify SGBD secured.
SRO rev 33.1 14
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 4 Event # 5 Page 15 of 42 Event
Description:
IC SG tube leak 5 gpm over 3 mm and stabilizes Time Pos. Expectód ActionslBehavir Comments RO (step 1) Maintain pressurizer level stable at NOTE: This is a continuing normal programmed value by: action step
- Control charging FK-122 adjusted as required
- Reduce letdown close HV-8149 A, B, C close one or more orifice isol.
valves
- Determine leak rate, if possible RO (step 2) Maintain VCT level greater than NOTE: This is a continuing 20%. by: action step Verify RMW system in AUTO RNO is to trip the Rx and OR actuate an SI Manually control makeup as required by using SOP-2.3, CVCS Rx makeup system BOP (step 3) Check that the Continuous Radiation Monitoring System is operable Either R-15-- OPERABLE OR R-70s- OPERABLE SRO (step 4) Check reactor power conditions:
Check NO power ascension in progress
- Check NO power reduction in progress
- Check reactor power greater than 20%
BOP (step 5) Monitor primary to secondary NOTE: This is a continuing leakage action step Check R-70s or R-15 for increasing count rate Begin trending R-70A, 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.
15
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 5 Page 16 of 42 Event
Description:
IC SG tube leak 5 gpm over 3 mm and stabilizes Time Pos Expected ActionslBehavior Comments SRO (step 7) Direct chemistry to perform grab samples and leak rate determinations.
CCP-201 Table 55 NOTE: This is a continuing (step 8) Notify SM of leak rate action step (step 9) Continue to monitor R-70s, R-15 or NOTE: This is a continuing CHM/HP leak rate input for primary to action step secondary leak rate and rate of change using Data sheet 1.
(step 10) Evaluate Table to determine appropriate response:
- ACTION LEVEL 4 Proceed to step 1 1 30 gpd/hr rate of increase AND 75 gpd leak in any SG BOP (Step 11) Check any two of the following rad monitors trending in the same direction:
- R-70s/R-15 OR R-70s/R-23A(B) OR R-1 51R-23A(B) trending in the same direction with the same order of magnitude SRO Direct placing the Unit in Mode 3 within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .
- Identify the correct leaking SG 1C SG has a 5 gpm tube leak Using R-70s, R-60s and level rise in any SG AOP-2.0 actions continue on pg 17 version 58, 16
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 4 Event # 5 Page 17 of 42 Event
Description:
IC SG tube leak 5 gpm over 3 mm and stabilizes Time Pos. Expected ActionslBehavior Comments.
RO (Step 1.0) Borating per SOP-2.3 appendix B Version 56
. Set the boric acid integrator to the desired uantit NOTE: A continuous boration isaflowedbyappendixC
. Adjust LTDN TO VCT FLOW LK 112 setpoint as desired system lined up and the RO
. M/U mode selector to STOP will take the MSS to START
. MKUP MODE SEL SWITCH to BOR each time a boration is
. MKUP MODE CONT SWITCH to START. required.
(Step 1.6) Verify proper boration operation by observing the following: NOTE. M/A station FK-113
On service boric acid pump started. may have to be adjusted in
MKUP TO CHG PUMP SUCTION HDR MAN to obtain desired FCV113B opens. flowrate
BORIC ACID TO BLENDER FCV113A opens.
Boric acid flow is displayed on Fl-il 3 MAKEUP FLOW TO CHGNCT.
SRO (step i 1.7) Call SM to evaluate emergency classifications per EIP-8.0 or EIP-9.0 SRO (step 16) Direct Chemistry to monitor the turbine buildinq sump for activity SRO (step 17) Refer to FNP-0-AOP-2.l; Contingency Plan For Minimizing And Controlling Contaminated Secondary Condensate.
BOP (step 18) Verify affected SG(s) identified.
Check any SG level RISING IN AN
-
UNEXPLAINED MANNER.
OR Check any SG radiation indication HIGH
R-70 A, B, C and R-60 A B, C BOP (STEP 19) Verify affected SG(s) atmospheric relief valve-ALIGNED
- 8.25 and in AUTO BOP (STEP 20) Check affected SG atmospheric relief valve CLOSED
17
Appendix D Operator Action Form ES-D-2 Op Test No: FA2O1 2301 Scenario # 4 Event # 5 Page 18 of 42 Event
Description:
IC SG tube leak 5 gpm over 3 mm and stabilizes Time Pos. Expected Actions/Behavior Comments (STEP 21) if TDAFWP is running or required then direct the counting room to perform CCP-645 (STEP 22) Isolate steam supply from affected SG(s) to TDAFWP from 1C SG by directing ROVER to do the following:
- Establish LOCAL control from HSD Panel AND Isolate TDAFWP steam supply from 1 C SG by taking HV3235B in LOCAL and then to STOP BOP (STEP 23) Verify SGBD isolated from the 1C SG- 7614C closed (STEP 24) Check AS supplied from Unit 2 Call SSS to align AS SRO (step 7 of ARP FGI) Evaluate Tech Specs Condition B- be in mode 3 in 6 3.4.13 mandatory LCO hours.
RCS operational LEAKAGE shall be limited to:
d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).
TECHNICAL SPECIFICATION 3.4.13, RCS Operational LEAKAGE RCS operational LEAKAGE shall be limited to:
d. 150 gallons per day primary to secondary LEAKAGE throuah any one SG.
CONDITION REQUIRED ACTION COMPL ETION TIME B. Required B. I Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and AND associated B.2 Be in MODE 5. 36 Completion hours Time of Condition A not met.
OR Pressure boundary LEA KAGE exists.
OR Primary to secondary LEAKAGE not within limit.
At the discretion of the Lead Examiner move to Event #6.
18
Op Test No.: FA2012301 Scenario # 4 Event # 6 Page 19 of 42 Event
Description:
Main Turbine Lube Oil Temperature Controller CP-4055 Auto Output Failure LOW Main Turbine Lube Oil Temperature Controller CP-4055 Auto Output Failure, Requiring Manual Control of Main Lube Oil Temperature using CP-4055.
Indications Available:
Annunciators: Indications of Main Turbine Lube Oil Temperature Controller Failure:
DEH Trouble Alarm (LBI)
Tl-4020 Turbine Bearing Oil Temperature increasing.
- CP-4055 Turbine Bearing Oil Temperature Controller demand fails low.
Time Pos. Expected ActionslBehavior Comments version 50 BOP Announces receipt of annunciator LB1 SRO Directs BOP to respond to LB1 BOP Checks DEH CRT alarm sub screen Informs SRO Lube Oil Cooler Out alarm displayed on the DEH alarm sub screen SRO Directs taking manual control of Main There is no procedural Turbine Lube Oil Temperature guidance to take manual control of this controller.
Establishes Control Band for Lube Oil Outlet temperature BOP Takes Manual control of Main Turbine Lube Oil Temperature When Main Lube Oil temperature is decreasing and at the discretion of the Lead Examiner, move to Event 7 19
Op Test No.: FA2012301 Scenario # 4 Event # 7 Page 20 of 42 Event
Description:
High Vibration on Main Turbine of >15 mils Vibrations will increase rapidly on the Main Turbine. ARP KD4 will have the crew trip the Main Turbine. NOTE: Vibrations will decrease after main turbine is tripped. The crew will ramp Reactor power down to 8% to transfer the Stm Dumps to the STM PRESS mode.
Indications Available:
Annunciators: Recognize indications of High Vibrations:
MAIN TURB GEN VIB ALARM (KD4) - Vibration Display Monitor will show in RED high out of spec readings
- DEH Turbine bearing page will show high readings
- IPC Main Turbine page will show high readings version 70 SRO Direct actions of KD4 BOP KD4 (step 1) Check indications on BN TURB VIB MCR DISPLAY to determine the cause of the alarm Or On DEH Or On IPC (step 2) IF shaft vibration exceeds 7 mils, THEN investigation is necessary if vibration is continuous.
BOP (step 3) IF shaft vibration for #9 bearing is>
7 mils, THEN go to Step 11.
(step 4) IF shaft vibration is> 7 mils but less than 14 mils, THEN reduce turbine speed or load to reduce vibration.
20
Op Test No.: FA2O1 2301 Scenario # 4 Event # 7 Page 21 of 42 Event
Description:
High Vibration on Main Turbine of>15 mils SRO (step 5) IF shaft vibration exceeds 14 mils, OR thrust bearing wear exceeds 40 mils THEN perform the following:
Direct tripping the Main IF Reactor Power is < 35%, THEN Trip the Turbine and enter AOP-3.0 Turbine and refer to AOP-3.0, TURBINE TRIP BELOW P-9 SETPOINT.
BOP Place MAIN TURB EM ERG TRIP switch to TRIP for at least 5 seconds.
version 17 BOP (step 1) Check turbine TRIPPED.
-
[JTSLB214-l lit
[1 TSLB2 14-2 lit
[1 TSLB2 14-3 lit 1 1 TSLB2 14-4 lit RO (step 2) Stabilize reactor power.
2.1 Verify Rod Control in MANUAL 2.2 Adjust control rods in MANUAL to control RCS TAVG.
2.3 Verify steam dumps modulate to maintain reactor power less than 35%.
RO RNO (step 2.3) 2.3.1 Reduce reactor power to less than 8%.
2.3.2 Direct counting room to perform CCP 645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.
2.3.3 Control atmospheric relief valves to maintain RCS TAVG at program value for existing power level.
1A(1 B,IC) MS ATMOSREL VLV
[] PC 337 IA adjusted
[j PC 3371B adjusted I PC 3371 C adiusted BOP (step 3) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
21
Op Test No.: FA2012301 Scenario # 4 Event # 7 Page 22 of 42 Event
Description:
High Vibration on Main Turbine of >15 mils RO (step 4) Check all RCPs STARTED.
-
RCP
[] 1A
[] lB
[1 IC BOP (step 5) Check SG levels STABLE OR
-
TRENDING TO 65%.
BOP (step 6) Verify MSRs RESET.
-
REHEATER CONTROL SYSTEM
[]CP4054 BOP (step 7) Stop both heater drain pumps.
HDP
[] IA
[1 lB BOP (step 8) Check main turbine status.
8.1 WHEN main turbine is < 600 rpm, THEN verify main turbine shaft lift pump
- RUNNING.
MN TURB SHAFT LIFT
[1 N1N33P504 BOP (step 9) IF steam dump system in TAVG mode, THEN transfer to STM PRESS mode.
9.1 Reduce reactor power to less than 8%.
9.2 Place standby CNDS PUMP in STOP.
9.3 WHEN SGFP suction pressure greater than 500 psig, THEN stop all but one CNDS PUMP.
22
Op Test No.: FA2012301 Scenario # 4 Event # 7 Page 23 of 42 Event
Description:
High Vibration on Main Turbine of >15 mils RO 9.4 WHEN BYP & PERMISSIVE NUCLEAR AT POWER PERMISSIVE P-lU status light NOT lit, THEN perform the following:
9.4.1 Verify intermediate range reactor trip and rod stop UNBLOCKED.
-
BYP & PERMISSIVE INTERMEDIATE RANGE TRAIN A(B) TRIP BLOCKED
[]TrainAnotlit
[]Train B not lit 9.4.2 Verify power range low setpoint reactor trip UNBLOCKED.
-
BYP & PERMISSIVE POWER RANGE TRAIN A(B) TRIP BLOCKED
[]TrainAnotlit
[]Train B not lit 9.4.3 Verify BYP & PERMISSIVE LOW POWER TRIP BLOCK P-7 status light LIT.
-
RO (step 9.5) Check reactor power LESS
- Since Steam Dumps are failed THAN 8% in this scenario, 9.6 can be skiDDed.
When Reactor power decreases to 8% and is stable or under control, then go to the next event.
When Rx power is under control and approx 8% move to Event 8 23
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 24 of 42 Event
Description:
Steam break in Turbine Building.
When Rx power is under control and approx 8%, a steam break in the Turbine Building will occur. The IC MSIVs do not auto close and MSIVs are required to be closed to isolate the fault.
Indications Available:
Annunciators: Recognize indications of LARGE Steam BREAK Various and many in MSVR:
- Unexplained rise in steam flow
- Unexplained rise in feedwater flow
- Unexplained reduction in steam generator level and/or pressure
- Unexplained reduction in RCS/PRZR pressure and/or level
- Unexplained reduction in Tavg with Tavg below Tref
- Atmospherics or steam dumps closing with Reactor_power_rising Time Pos. Expected ActionslBehavior Comments SRO
. Direct entry into AOP-14.0 I version 10 RO! (step 1 .0) [CA] Evaluate plant status for safe BOP operation.
Pressurizer level GREATER THAN 15%
AND
Pressurizer pressure GREATER THAN 2000 psig AND
Steam generator pressure GREATER THAN 650 psig AND
Containment pressure LESS THAN 2 psig AND with main generator off line, THEN check reactor power less than 15%
24
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 25 of 42 Event
Description:
Steam break in Turbine Building.
SRO Directs RNO (step 1.0) If parameters not met here
. then step 2 would be 1 .1 Tnp the reactor referenced 1 .2 IF reactor tripped, THEN CLOSE SG Critical task MSIVs and bypass valves.
CLOSE MSIVs.
1.4 Go to EEP-0, REACTOR TRIP OR SAFETY INJECTION.
BOP (step 2) Identify SECONDARY leakage source.
2.1 Check SG atmospheric relief valves CLOSED.
2.2 Check Main Steam Safety valves -
CLOSED.
BOP (step 2.3) Check no abnormal steam Phone call to Rover or SSS or leakage in Main Steam Valve Room. Security guard RNO (step 2.3) Perform the following.
a) Isolate affected components consistent with plant operating requirements Call to Turbine Bldg b) IF steam leakage cannot be isolated AND the plant is in Mode 3, THEN verify the N/A- not in mode 3 reactor is triooed.
When the Reactor is tripped, Event 9 will start; a 400 gpm SGTR on 1C SG will ramp in over 60 seconds.
25
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 26 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds When the Reactor Trip breakers are opened, a 400 GPM SGTR will ramp in over 60 seconds Indications Available:
Annunciators: Recognize indications of 10 SG 400 gpm
- Various and many SGTR:
, version 43 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 Critical task trip bypass breakers OPEN.
- Trip the reactor 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. If no SI signal is in at this time BOP Check any SI actuated indication. ESP-0.1 will be entered.
BYP & PERMISSIVE SAFETY INJECTION
[1 ACTUATED status light lit If SI actuated then go to page
[1 MLB1 11 lit 27 and skip ESP-0.1.
[1 MLB-1 11-1 lit
, version 32 26
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 27 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds RO (step 1) Check RCS temperature NOTE: this is a continuing
- Stable at or approaching 547° F action step
- TAVG 1A(IB,IC) RCS LOOP
[] TI 412D
[] TI 422D STM DUMP
[j TI 432D BOP (step I RNO) Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET OR
[1 B TRN in OFF RESET Verify atmospheric reliefs closed IA(IB,1C) MS ATMOS REL VLV
[] PC 3371A fl PC 3371B
[1 PC 3371C Safety Injection F oldout page criteria will be met due to PRZR level <4%. A safety Injection will be actuated and EEP-O re-entered. Critical task- actuate the S TEAM Re-perform lOAs of EEP-O above Page 26 above continued here:
SRO (step 5) Directs continuing into EEP-O at step See page 37, which is at the
5. Tab at end of scenario for Directs the BOP to perform Attachment 2 and 4 actions.
Attachment 2 of EEP-O.
(step 6) Check containment pressure- HAS NOTE: [CA] step RO REMAINED LESS THAN 27 psig (checked on IPC or P1950, 951 952, 953,CNMT PRESSURE)
RO (step 7) Announce Unit 1 reactor trip and safety iniection 27
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 28 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds RO (step 8) Check AFW status.
Check secondary heat sink Available o Check total AFW flow> 395 gpm
[j Fl 3229A
[] Fl 3229B
[j Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level> 31% {48%}
WHEN all SG narrow range levels less than 31 %{48%}, THEN maintain total AFW flow greater than 395 gpm.
WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.
RO (step 8.4) WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31 %-65%{48%-65%},
. Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[] A TRN reset
[] B TRN reset MDAFWP TO lA/lB/iC SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT U 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 IA(1B,1C) RCS LOOP
[1 TI 412D
[] TI 422D
[] TI 432D 28
Op Test No.: FA2O1 2301 Scenario # 4 Event # 8 Page 29 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds 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
[jATRN in OFF RESET
[] B TRN in OFF RESET (step 9.1.2) Verify atmospheric reliefs closed on MCB
[1 Demand at 0 and minimum red light LIT (step 9.1.3) Control total AFW flow to minimize RCS cooldown, AFW FLOW TO 1A(1B,IC)SG
[] Fl 3229A U Fl 3229B
[] Fl 3229C AFW TOTAL FLOW
[1 Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 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.
[1 PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.
[] PRT PRESS P1 472
[] PRT LVL Ll-470
[1 PRT TEMP Tl-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.
NOTE* CA ste p 1A(1B)LOOPSPRAYVLV
[1 PK 444C
[] PK 444D Check any PRZR PORV ISO OPEN -
29
Op Test No.: FA2O1 2301 Scenario # 4 Event # 8 Page 30 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds RO (step 11) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45F}
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.
IC(IA) LOOP RCS WR PRESS
[] P1 402A
[1 P1 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.
[1 Check no SG pressure FALLING IN AN
UNCONTROLLED MANNER OR LESS THAN 50 psig.
SRO (step 14) Check SGs not RUPTURED RNO to go to EEP-3.0 Check secondary radiation indication -
NORMAL.
[1 R-1 5 SJAE EXH
{] R-19 SGBD SAMPLE
[1 R-23A SGBD HX OUTLET
[]R-23B SGBD TO DILUTION
[]R-15B TURB BLDG VNTL (BOP)
[1 R-15C TURB BLDG VNTL (BOP)
[]R-60A MS ATMOS REL (BOP)
[1 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.
ver26 RO (step 1) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication -> 16°F{45F} SUBCOOLED IN CETC MODE.
30
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 31 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds BOP (step 2) Identify ruptured SG(s). NOTE: this is a continuing action step Check any SG level RISING IN AN
-
UNCONTROLLED MANNER SRO/ (step 3) WHEN ruptured SG(s) identified, NOTE: this is a continuing RO THEN isolate flow from ruptured SG(s). action step Verify ruptured SG(s) atmospheric relief 1 C SG is ruptured valve ALIGNED.
-
- PC3371C, 10 MS ATMOS REL VLV, set 8.25 and in auto
- Verify 3371 C, 1 C MS ATMOS REL VLV, is closed Isolate steam supply from I C SG to TDAFWP:
Check at least one MDAFWP running and no TDAFWP auto start signals present (step 3.3.4) Stop the TDAFWP from the MOB (step 3.3.6) initiate actions to isolate the TDAFW steam supply from the ruptured SG while continuing with step 3.6.
(step 3.6) Verify blowdown from ruptured SG(s) ISOLATED.
-
CRITICAL TASK -
(step 3.7) Verify at least one SG MSIV on 10 Verifies MSIV 33690 or SG closed 3370C closed and bypass valves closed BOP (step 4) WHEN ruptured SG(s) NR level NOTE: this is a continuing greater than 31% THEN perform the action step following:
Isolate AFW flow to ruptured SG(s) using FCVs.
- FCV 32270 in MOD, and closed
- HV 3328C in MOD and 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.
31
Op Test No: FA2012301 Scenario # 4 Event # 8 Page 32 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds RUPTURED REQUIRED SG CORE PRESSURE EXIT (pig) TEMPERATURE 1151 - 1200 536°F (522°F) 1101 - 1150 531°F (516°F) 1051 - 1100 525°F (510°F) 1001 - 1050 519°F {504°F) 951 - 1000 513°F (498°F) 901 - 950 507°F (491°F) 851 - 900 500°F (484°F) 801 850 494°F (477°F) 751 - 800 487°F (469°F) 701 - 750 479°F {461°F) 651 - 700 471°F (453°F) 601 - 650 463°F (443°F) 551 - 600 454°F (434°F) 501 - 550 445°F (423°F) 451 - 500 434°F (412°F) 401 - 450 423°F (400°F) 351 - 400 411°F (386°F) 301 - 350 398°F (370°F) 251 - 300 383°F (353°F)
- 250 365°F (332°F)
SRO Direct the STA to Display the hottest CETC page ITCI on plant computer.
This is normally selected by the STA and put on the control board display.
Critical task Cooldown and depressurize SRO Will direct these steps: Steam Dumps are not (step 6.4 RNO) available due to the Steam Begin RCS cooldown to cold shutdown. Fault and MSIVs closed (step 6.4.1) Direct countingroom to perform CCP-645 (step 6.4.2) Dump steam from the INTACT SGs at maximum attainable rate MS ATMOS REL VLV Atmospherics will be opened
- PC3371A fully by adjusting the pots to
- PC3371B full open 32
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 33 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds 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 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
[J A TRN reset fl B TRN reset MDAFWP TO lA/lB/iC SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[1 SIC 3405 adjusted RO (step 8) Check pressurizer PORVs Check any PRZR PORV ISO power available
[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.
Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.
[] PRT PRESS P1 472
[1 PRT LVL Ll-470
[1 PRT TEMP TI-471 Check at least one PRZR PORV ISO -
OPEN 33
Op Test No.; FA2012301 Scenario # 4 Event # 8 Page 34 of 42 Event Description; IC SG 400 gpm SGTR ramped in over 60 seconds BOP (step 9) Verify SI RESET.
-
MLB-1 1-1 not lit (A TRN) and MLB-1 11-1 not lit (B TRN)
(step 10) Verify PHASE A CTMT ISO -
RESET.
MLB-2 1-1 not lit and MLB-2 1 1-1 not lit BOP (step 11) Check PHASE B CTMT ISO -
RESET.
RO (step 12) IF instrument air available, THEN establish instrument air to containment.
Verify at least one air compressor started.
AIR COMPRESSOR U 1A
[] lB
[] 1C Check INST AIR PRESS P1 4004B greater than 85 psig.
Check instrument air to containment.
IATO CTMT
[1 MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO
[1 Annunciator KD1 clear RO (step 13) [CA] Check if LHSI Pumps should be stopped.
Check RCS pressure GREATER THAN
275 psig{435 psig} on PT-402 AND 403, IA/IC LOOP RCS WR PRESS.
Check RCS pressure STABLE OR RISING
-
Take HS to stop.
Secure any running RHR pumps 34
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 35 of 42 Event
Description:
IC SG 400 gpm SGTR ramped in over 60 seconds SRO (step 14) Check if Cooldown should be stopped.
Check hottest core exit T/Cs - LESS THAN REQUIRED Temperature.
RNO Stop RCS cooldown Do NOT proceed until hottest Maintain core exit T/Cs LESS THAN core exit T/Cs LESS THAN
-
REQUIRED TEMPERATURE. REQUIRED TEMPERATURE.
SRO (step 15) Check ruptured SG(s) pressure -
STABLE OR RISING.
(step 16) Check SUB COOLED MARGIN MONITOR indication GREATER THAN
-
36°F{65°F) SUBCOOLED IN CETC MODE.
RO (step 17) Reduce RCS pressure to Critical task minimize break flow and refill pressurizer.
Open all available normal pressurizer spray valves.
1A(1B) LOOP SPRAY VLV
[]PK444C
[1PK444D SRO (step 17.2) Reduce RCS pressure until one of the following three conditions occurs, then stop RCS pressure reduction.
RCS pressure less than ruptured SG pressure AND pressurizer level greater than 1 3%{43%}
OR RCS pressure within 300 psi of ruptured SG(s) pressure AND Pzr level >43%{50%}
OR Pressurizer level greater than 73%{66%} Then verify the snravs are OR closed.
SCMM indication less than 16°F{45°F}
subcooled in CETC mode.
SRO (step 19) Check RCS pressure rising on
PT-402 AND 403, lA/iC LOOP RCS WR PRESS.
When spray valves closed and at the discretion of the Lead Examiner, terminate the scenario.
35
Op Test No: FA2012301 Scenario # 4 Event # 8 Page 36 of 42 Event
Description:
Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-O AUTOMATIC ACTIONS VERIFICATION Time Pos. Expected ActionslBehavior Comments (Step 1) Verify one CHG PUMP in each train STARTED.
-
BOP [] A train (IA or I B) amps > 0 Ii B train (1 C or I B) amps> 0 BOP (Step 2) Verify RHR PUMPs STARTED.
-
RHR PUMP
[JlAamps>0
[1 lB amos> 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow GREATER
-
THAN 0 gpm.
[1 Fl 943 BOP (Step 3.2) Check RCS pressure LESS -
THAN 275 osia435 nsici.
BOP (step 3.3) Check LHSI flow greater than
1.5 XlO gpm 3
[j 1A RHR HDR FLOW Fl-605A
[j lB RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[]Atrain (1A1B or 1C)
U B train (1D,1E or 1C) 36
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 37 of 42 Event
Description:
Attachment 2 of EEP-O Time Pos.. Expected ActionslBehavior :comments BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train- STARTED.
A train HX IC or 1 B CCW FLOW fl Fl 3043CA> 0 gpm OR fl Fl 3043BA> 0 gpm B train HX lAor lB COW FLOW
[] Fl 3043AA> 0 gpm OR
[]Fl 3043BA>Ogpm Verify SW flow to associated COW HXs SW FROM IA(IB, IC) COW HX
[1 QIPI6FI3009AA> 0 gpm
[] QIPI6FI3009BA> 0 gpm
[] Q1PI6FI3009OA> 0 gpm BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[1 3197
[1 3198D
[j 31980
[j 3196
[] 3198A
[] 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 28670 FULL-3198A & 3198D
[1 28660
[] 28670 CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 31980 fl 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP 37
Op Test No.: FA2012301 Scenario # 4 Event# 8 Page 38 of 42 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 7) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.
-
CTMT CLR FAN SLOW SPEED Atrain
[] 1A
[] lB trips B train
[1 IC fl ID does not auto start Verify associated emergency service water outlet valves OPEN.
-
EMERG SW FROM IA(1B,1C,1D) CTMT CLR
[] Q1P16MOV3O24A
[] Q1P16MOV3O24B
[1 Q1P16MOV3O24C
[J Q1P16MOV3O24D BOP (step 8) Verify AFW Pumps STARTED.
-
Verify both MDAFW Pumps STARTED-
[1 1A MDAFW Pump amps > 0
[] lB MDAFW Pump amps> 0 AND
[1 FI-3229A indicates > 0 gpm
[1 Fl-3229B indicates > 0 gpm fl Fl-3229C indicates > 0 gpm (Step 8.2) check TDAFW Pump start required.
DCondition LITSLB L Setpoint D CoincidenceLl RCP Bus TSLB2 I-I L12680 V 1/2 Detectors Undervoltaqe 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 38
Op Test No.: FA2O1 2301 Scenario # 4 Event # 8 Page 39 of 42 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 8.3) Verify TDAFWP started.
fl MLB-4 1-3 lit
[1 MLB-4 2-3 lit
[j MLB-4 3-3 lit TDAFWP SPEED
[JSI 3411A> 3900 rpm TDAFWP SPEED CONT
[1 SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SO.
TDAFWP TO IA(1B,IC) SO
[1 Qi N23HV3228A in MOD
[j QI N23HV3228B in MOD
[] Qi N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SO FLOW CONT
[J HIC 3228AA open
[} HIC 3228BA open fl HIC 3228CA open BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves CLOSED.
-
1A(1B,1C) SG FW FLOW
[] FCV 478
[] FCV488
[1 FCV 498 Verify both SGFPs TRIPPED.
-
Verify SG blowdown ISOLATED.
-
1A(1B,1C) SGBD ISO
[1 Q1G24HV7614A closed
[1 Q1G24HV7614B closed
[] Q1G24HV7614C closed 9.4 Verify SO 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 U MLB1 19-4 lit Q1P15HV3330 closed 39
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 40 of 42 Event
Description:
Attachment 2 of EEP-O Time - - Pos. - -
- Expected- ActionslBehavior - - -
- .1 - - - -
- omments - - - --
BOP (Step 10) Check no MSL isolation actuation signal present.
SianFil
.... IJSJI I II. ---
I..#.JII III.V..,I II..?., TSI R
-
LO SG PRESS < 585 psig 2/3 TSLB4 19-23,4 Hi stm flow >40% 4 on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt oress >16.2 osio 2/3 TSLBI 2-234 (Step 11) Verify PHASE A CTMT ISO.
(Step 11.1) Verify PHASE A CTMT ISO -
ACTUATED.
BOP fl MLB-2 1-1 lit
[] MLB-2 11-1 lit 1 1 .2 Check all MLB-2 liqhts - LIT.
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 fl N1C11EOO5A
[1 N1C11EOO5B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO ACTIONS FOLLOWING A accomplish this.
REACTOR TRIP OR SAFETY INJECTION.
40
Op Test No.: FP2012301 Scenario # 4 Event # 8 Page 41 of 42 Event
Description:
Attachment 2 of EEP-0 Time Pos. Exoected Actions/Behavior Comments BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[] A TRAIN
[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR
[1 810- OPEN 1] 914- OPEN BOP (step 17) Verify two trains of ECCS SEE page 42 equipment aligned.
Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.
End of Attachment 2 41
Op Test No.: FA2012301 Scenario # 4 Event # 8 Page 42 of 42 Event
Description:
Attachment 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.
[1 Check DFO1 closed
[] Verify DFO2 closed
[] Check DG15 closed fl Verfiy DGO2 closed
[1 Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
fl Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.
-
CHG PUMP DISCH HDR ISO
[1 Q1E21MOV8132A
[1 Q1E21MOV8132B
[j QIE21MOV8133A
[J QIE2IMOV8133B CHG PUMP SUCTION HDR ISO
[1 Q1E21MOV813OA
[] Q1E21MOV813OB
[] Q1E21MOV8131A
[] QIE21MOV8131B (Step 1 .7) Verify all post accident containment air mixing system fans STARTED. (BOP)
-
POST ACCIDENT MIXING FANs RX CAV H2 DILUTION FANs (Step 1.8) WHEN power restored to any de energized emergency bus, THEN verify aliqnment of associated equipment.
BOP (Step 1.9) Verify Spent Fuel Pool Cooling in Call Radside SO service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
End of Attachment 4 42
Appendix B Crew Briefln sheet Form ES-D-2 Op-Test No.: FA2012-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.
In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign operating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-2
[XJUnitl [ ]Unit2 Shift: Date Off-going SS I Oncoming SS I [ ]N [X] D Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, 5, D, SW, X on key ring. SS Unit 29% power, 1172 ppm, BOL 4000 MWD/MTU Status MK-5 actions and ramp down in progress STPslEvolutions: A Train (
STP-27.1 completed 1 ProtectE hour_ago 10; 109.1 Noadi.; 63.7; FSP-20,0 Status of Special Testing General Information
1. 1-2A DG is TIO due to the crankcase being cracked and oil draining out of DG.
2. 1A MDAFW pump has a cracked pump casing, was leaking and is tagged out.
3. Current Risk Assessment is YELLOW and projected is YELLOW due to the 1A MDAFW pump and 1-2A DG issues.
4. Earthquake recovery is in progress. MK5 has been entered, and UOP-3.1 is complete through step 8.16 and UOP 2.1 is at step 5.3.
5. Plans are to continue the ramp down at 2 MW/mm and be off line in the next hour.
6.
7.
8.
9.
PnhlinmQnt !.tti
-..
1-2A DG TIO due to crankcase IA MDAFW pump TIC due to Maintain VCT gas pressure 25-30 psig crack cracked casino retaiviiv 11ar1 Waste Manager ent Status 50 qal every 10 minutes, as required. I #3 RHT On Service
I WGSsecured LCO tatus 3.8.1 condition B, STP-27.1 completed 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago 3.7.5 Condition Night Orders No New Night Orders Part II Review Shift Complement LCOs Reviewed SS (initials) reviewed as early in shift as possible Part Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[X]Yes [X]Yes [XJYes [X]Yes [X]Yes [XjYes
Scenario #5 FA2O1 2301 Southern Nuclear JM. Farley Nuclear Plant Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #5 Validation time: 120 minutes Validated by David Shipman, Todd Smith and Doug Jimmerson The week of February 13, 2012 TRN Supervisor Approval: Gary Ohmstede Date: 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTHERN £ COMPANY
Appendix D Scenario #5 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 5 Op-Test No.: 2012-301 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power, 58 ppm, EOL, steady state.
Turnover:
. 1 C DG TIC for governor work. (OOS 2 days, ETR 4 hrs)
. IA MDAFW Pump is T/C for impeller replacement. (QOS for 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months , ETR 2 days)
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 MaIf. Event Type* Event Description No. No.
1 imf I (RO) PT447, Turbine first stage impulse pressure, fails LOW.
pt447 TS (SRO) T.S. 3.3.1 Condition U and 3.3.2 Condition D 2 imf C (BOP) 1A HDT pump trips due to the HDT dump valve failing open.
FWM9 3 lmf C (RO) 1A charging pump sheared shaft.
Ncvpo TS (SRO) T.S. 3.5.2 Condition A TRM 13.1.5 admin (mandatory while a-swapping charging pump trains) 4 lmf I (BOP) PT-464 fails LOW. SGFP speed decreases.
pt464 5 R (RO) Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17.1 entry.
N (BOP) 6 imf M (ALL) lB FRV fails shut slowly while ramping down. Start when 90%
fk488 power reached. Manual Rx trip due to LO LO SGWL (CT) 7 imf M (ALL) LOSP 1C DG is tagged out, 1-2A DG will not auto start or
mal- start from EPB, and 1 B DG starts and trips. 20 DG will not espi start. Enter ECP-0 here.
preset C (RO) TDAFWP will not auto start but will start from MCB. (CT) 8 C (BOP) When at ECP-0 step 10.2, after the MSIVs have been closed, then restore off site power to the SU Transformer(s). Use step 5 to restore power. (CT)
(N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor Farley June 2012 exam Page2ofl4
Appendix D Scenario 5 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS 0 0 Load in IC-215 and sim IC snap directory Base IC as IC-76 RUN RUN simulator 0 0 Generic setup bat genenc_setup_HLT txt
0 0 Quick setup (all items with are included):
bat 20l2nrcexam_05 txt IB-2ADG fails to auto start: If the box = TRUE than Set jdgblklb = tme the l-2A DG will NOT auto start 1*i
0 0 Block Auto Reactor Trips imf cbkrxtrp_cc5 open imf cbkrxtrp cc6 open
7 6 1 -2A DG fails to auto start set jdgblkla = true or Imf mal-dsgOl6 7 6 1 B DG trips on AUTO start Trg 2 imf mal-eps4b (2 30) 7 7 TDAFW pump will not auto start
imf cms3235b ccl open imf cms3235b_cc2 open imf cms3235a_ccl open imf cms3235a cc2 open
2 2 Block 1A Cond pump from auto start imf ccfcnla_cc8 open imf ccfcnla_cc9 open imf ccfcnl a_cclO open 0 0 Fail Normal Air Pressure light OFF on 10 DG MaIf I D I mal-dsgOO4
7 6 1-2ADGfailstostartfrom EPB irf loa-epbOOl false
0 0 Tag Out 1A MDAFW Pump irf cafpol a_d_cdl open
0 0 20 DG will not start from EPB.
irf loa-epbOO5 false
0 0 TagoutlCDG in cbkldh07_d_cdl open Farley June 2012 exam Page 3 ofl4
Appendix D Scenario 5 Presets Form ES-D-l EVENT# TIME EVENT DESCRIPTION I ACTION LIST ACTIONS in cbk2dh07_d_cdl open Thggers and Commands 2 2 Event trigger 1 degrade IC CND pmp when HDT
- pump trips
trgset 1 li4OlOa < 10 trg 1 imfncfcnla-d_th 10 120 7 6 Trigger 2: 1 B DG will trip when it starts.
trgset 2 xg I baO2 Farley June 2012 exam Page 4 of 14
Place HOLD Tag on 1 C DG MSS 1 HOL[ TAG Place HOLD Tag on 1C DG DG output breakers DHO7- 2 HOLD TAGS 1 and DHO7-2 1A MDAFW pump handswitch 1 HOLD TAG Place Unit 1 and unit 2 Bypass and inoperable panel Unit 1 A-Train lights to the up position (EMERGENCY POWER Unit 2 A Train SYSTEM)
Place Unit 1 Bypass and inoperable panel light to the up Unit 1 A-Train position (AUXILIARY FEEDWATER SYSTEM)
DEH Cf ear 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 uodate rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared
-..
FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview I sv DataCollection.uvl sv DatacoIIecton.uvI If needed, adjust sim time back to 00:00:00 SIM VIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: cIock(1 = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 5 ofl4
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 DataCollectionuvl file press DATA for drop down and then COLLECT to start collecting data 0 Begin Exam
-
RUN simulator Vei ON: hornflag Turn Horns ON/OFF HORNS ON = TRUE ann horn 1 PT447, Turbine first stage impulse pressure, fails LOW.
IMF PT447 0 /20 2 1A HDT pump trips due to the HDT dump valve failing open.
imf MAL-FWM9! 100! 50 When 1A HDT pumr is restarted then delete degraded head on 1C cond pump pmps! dmf ncfcnlc-dth 3 1A charging pump sheared shaft.
Imf Ncvpola-b 4 PT-464 fails LOW. SGFP speed decreases.
lmfpt464 0/ 100 5 Bus duct cooling alarm, NC5, ramp unit to approx. 63%
power in 45 minutes.
lmf NC5 failon 6 1 B FRV fails shut slowly while ramping down. Start 90% when 90% power reached.
power mffk488-bO 120 Farley June 2012 exam Page6ofl4
Appendix D Scenario 5 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 7 NRC LOSP imf mal-epsl I CUE When SGFPs tripped TDAFWP will not auto start but will start from MCB 8 Phone When at ECP-0 step 10.2, after the MSIVs have been call at closed, then restore off site power to either lAor lB SU S ep Transformer. Use step 5 to restore power. (CT)
End of Exam HORNS OFF
-I FREEZE simulator Stop data collection for Simview file sv DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.
grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
Farley June 2012 exam Page7ofl4
Appendix D Scenario 5 Local Operator Action sheet Form ES-D.1 Local operator actions:
EVENT NO. TIME ACTIONS I NONE REQUIRED 2 WHEN Close 1A HDT dump valve V915A per step 6.2.3 RNO REQUESTED to perform step 6.2 RNO MALF I MAL-FWM9 /1/ 30 3 NONE REQUIRED 4 NONE REQUIRED 5 NONE REQUIRED 6 NONE REQUIRED 7 Place each Start the 2C DG in Mode 4 DG in mode 4 and report the DG cannot be started from Remote / r43/ loa-dsgOO7 true the DG LCP Start the 1 -2A DG in Mode 4 Remote / r431 loa-dsgOO3 true 8 WHEN Defeat Auto Starts REQUESTED Attachment Two ecp_Oatt25m in.txt (INSTRUCTOR MUST PERFORM THE LOCAL ACTIONS OF THE ATTACHMENT AT HSPs)
Place LOCAL/REMOTE switches for A train ESF equipment in LOCAL.
CHG PUMP lAand lB (ATRN)
CCWPUMPICand1B(ATRN)
MDAFWP1A Place LOCAL/REMOTE switches for B train ESF equipment in LOCAL.
CHG PUMP IB(B TRN)and 1C
CCWPUMP1B(BTRN)and IA
MDAFWP1B Farley June 2012 exam Page 8 of 14
Appendix D Scenario 5 Local Operator Action sheet Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 8 WHEN RCP Seal Isolation REQUESTED Attachment Three ecp 0 att 3 lmin.txt 8 Instructor Note: No action to be taken for isolating Hotwell Fill per step 9 of ECP-O.O (no simulator capability)
No action Reduce DC Loads Attachment Four (Delay any action on this) 8 IF crew may direct N2 aligned to PORVs REQUESTED cae n2_porvs_align.cae 8 This is a Restore Offsite Powe required action for event 8 NRC direction MaIf I El MAL-EPSI 1100 8 Note Crew takes actions of ECP-O.O to power emergency busses Energizes dead bus per ECP-OO, step 592 or SOP-362 When emergency busses energized, go to step 24 of ECP-O.O Farley June 2012 exam Page 9 of 14
Appendix D Scenario 5 Communications sheet Form ES-D-1 Communications sheet EVENT TIME Communication:
NO.
WHEN SSS-plant, SM and Dispatcher: (PT-447)
REQUESTED Dispatcher for CR and for placing bistables in trip, Shift manager informed and acknowledge.
2 WHEN TB SO:
REQUESTED called to check out the IA HDT level.
TB SO reports: The HDT is low.
TB SO later reports Dump valve V91 5A is failed open.
TB SO will be asked to iack the valve closed.
TB SO reports: The HDT dump valve is jacked closed.
If asked DDO7 has normal indications and 1A HDT pump looks good 3 WHEN Radside SO:
REQUESTED called to check 1A charging pump
Radside SO reports: the 1A 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.
SM and Dispatcher:
Dispatcher for CR Shift manager informed and acknowledge.
4 WHEN SM and Dispatcher: (PT-464)
REQUESTED Dispatcher for CR Shift manager informed and acknowledge.
5 WHEN SM and Dispatcher: (Bus duct cooling)
REQUESTED Dispatcher for CR Shift manager informed and acknowledge.
TB SO:
If asked to check bus duct cooling report the following:
The fan belt is broke and the fan is not running ACC:
Ramping to 50% POWER 6 None required lB FRV fails closed SEE LOCAL OPERATOR ACTION PAGE for actions taken and provide the below feedback when requested Farley June 2012 exam Page 10 of 14
Appendix D Scenario 5 Communications sheet Form ES-D-1 Communications sheet EVENT TIME Communication:
NO.
WHEN DBSO:
REQUESTED - lB DG has several alarms in:
35 ESSENTIAL GENERATOR PROTECTION GEN DIFF
-
43 EMERGENCY ENGINE SHUTDOWN
-
2CDG
- 2C DG looks good, alarm is due to SW pressure low.
- After the 2C DG is tried to be started, then tell the CR that there is no obvious problem with the 2C DG.
- I have placed the 2C DG Mode select switch to the MODE 4 position (see LOA pace to do this action) 7 1-2A DG - 1-2A DG looks good, alarm is due to SW pressure low.
- After the l-2A DG is tried to be started, then tell the CR that there is no obvious problem with the 1-2A DG.
- I have placed the l-2A DG Mode select switch to the MODE 4 position (see LOA paae to do this action)
WHEN If called about off-site power:
REQUESTED ACC: it may be an hour before we get off-site power restored.
7 WHEN ROVER:
REQUESTED TDAFW pump looks good and is running. As appropriate.
after the If the handswitches have not been taken to start and held long enough, report the TDAFW TDAFW pump pump is not running and there is no obvious problem with the pump.
handswitches have been taken to Start and the pump is running 7 IF Sampling as requested by chemistry and secure ZAS REQUESTED Radside SO:
I will align N2 to the PORVs (this is not necessary to be done.)
HP:
Perform RCP-25 on MS lines 8 NRC direction SM:
(when off-site power restored)
ACC just called and reported that the grid is stable and offsite power is available to Farley Nuclear Plant.
Farley June 2012 exam Page 11 of 14
Scenario 5 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: 100% power, 58 ppm, EOL, steady state.
Turnover:
1 C DG T/C for governor work. (OOS 2 days, ETR 4 hrs)
1A MDAFW Pump is TIC for impeller replacement. (OOS for 20 hours2.314815e-4 days 0.00556 hours 3.306878e-5 weeks 7.61e-6 months , ETR 2 days)
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 PT-447 impulse pressure channel fails LOW.
Verifiable actions: Stop rod movement by placing rods in manual; select PT-446 as the controlling channel. Recover rods and power/Tavg to normal. TS 3.3.1 Condition U and 3.3.2 Condition D Event 2 1A HDT pump trips due to the HDT dump valve failing open. Stby Cond. Pump wont start in AUTO.
Verifiable actions: Start the stby cond pump and find the problem with the HDT valve.
Possible restart of HDT pump and securing of Stby Cond pump.
Event 3 IA 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.
Verifiable actions: Secure the running Chg pump and start either 1 B or 1 Chg pump. Place letdown back on service per AOP-16.0. TS 3.5.2 condition A and TRM 13.1.5 admin (mandatory while swapping the I B Chg pump to A Train)
Event 4 PT-464 fails LOW. SGFP speed decreases and SGWLs fall.
Verifiable actions: Take manual control of BOTH SGFP speeds and control speed to control SGWLs. This will be difficult once the fast ramp starts in the next event.
Event 5 Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17 entry.
Verifiable actions: RO will have to borate and drive rods to maintain TavglTref and flux on target at 7 MW/mm ramp rate. SOP will have to set up the ramp on DEH and control SGFP speed in manual during the ramp.
Event 6 1 B FRV fails shut slowly while ramping down. Start when 90% power reached. Rx trip due to LO LO SGWL or possible Hi Hi SGWL Rx trip, loss of BOTH SGFPs and Main Turbine.
Verifiable actions: Trip the reactor when SGWLs approach 30% to prevent an Auto Rx trip. (CT) Then when in ESP-0.1 secure the SGFPs.
Event 7 LOSP 1C DG is tagged out, l-2A DG will not start automatically or manually, and IS DG
starts and trips. 2C DG will not start. TDAFW pump will not auto start.
Verifiable actions: Start the TDAFW pump from the MCB, (CT) In ECP-0, direct isolating RCP seal injection before a charging pump starts or is started. (CT)
Parley June 2012 exam Page 12 of 14
Scenario 5 detailed summary Appendix D Form ES-D-1 sheet Event 8 At step 10.2, ACC will call the control room and give power back to the unit from offsite.
The crew will immediately transition back to step 5.9.3 and realign the startup transformers back to Unit 1. Then the crew would transition to step 25 and continue with ECP-0.0.
Verifiable actions: align breakers to restore off-site power to one emergency bus. (CT)
Terminate the scenario when offsite power is restored to Unit 1.
AOP-1 00 I ARPs and AOP-1 3 I AOP-16/ AOP-1 7 I possible AOP-16 I EEP-0 I ESP-0.1 /
ECP-0.0 Farley June 2012 exam Page 13 of 14
Scenario 5 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
1. Actuate a manual Rx trip prior to SI (WOG CT E-0 - - A) (PRA - 10.29 1 RTOPMANRT
--H)
2. Call to implement isolation of RCP seal injection before a charging pump starts or is started per ECP-0.0 (step 8). (WOG CT ECA-0.0 -H) -
3. Start the TDAFW pump before SG dryout occurs. (WOG CT ECA-0.0 - - B)
Start the TDAFW pump from the MOB
4. Restore power to the emergency busses when Off-site power becomes available after entering steps to isolate equipment and minimize loads. (WOG CT E-0 - - C)
This applies to this case when off-site power is restored and incorrect alignment or failure to align the off-site power source to the emergency busses could result in continued degraded core cooling conditions should a small LOCA through the seals were to occur.
SCENARIO With a tornado heading for the plant the crew will have to ramp down due to bus OBJECTIVE! duct cooling problems.
OVERVIEW: The team should be able to:
respond to a failed equipment and instruments and complete the appropriate ARP5, AOP-100, AOP-13, AOP-16 (possible) & Tech Specs,
respond to a loss of bus duct cooling with SGFP speed control in manual and ramp the unit to 63% power in 45 minutes,
respond to a FRV that fails closed and manually trip the reactor,
respond to a loss of off-site power for which no DG will start. When ECP-0 is in progress off-site power will be restored and the crew will restore power to one emergency bus and then exit ECP-0.0.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
1. Total malfunctions (58) 7
2. Malfunctions after EOP entry (12) 1
3. Abnormal events (24) 5
4. Major transients (12) 2
5. EOPs entered/requiring substantive actions (12) 1
6. EOP contingencies requiring substantive actions (02) 1
7. Critical tasks (23) 4 Farley June 2012 exam Page 14 of 14
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 1 Page 1 of 31 Event
Description:
PT447, Turbine first stage impulse pressure, fails LOW Indications Available:
Annunciators: Indications of PT-447 failing low:
- TAVG/TREFDEV(HF3) - P 1-447 decreases to 0 psig
- HI STM FLOW ALERT (JB4) - Tl-408A TAVG TREF increases to +5°F
- TR-408 HIGH TAVG / TREF
- TREF Decreases to 547 °F
- Loss of Load Interlock C-7A light on BYP and Permissive Panel lights up
- TSLB4 channel 4 bi-stable lights 16-3; 17-3; 1 8-3, for loops 1; 2; & 3 Hi Steam Flow Illuminate
- Control Rods step in at 72 steps per minute IF ROD CONTROL IN AUTO
- Steam Dump Loss of Load Controller is armed.
Time Pos. Expected Actions/Behavior Comments ver 11.0 RD Announces annunciators or abnormal indications SRO Directs Immediate Operator Actions of AOP Note: Steps I and 2 are 100 for Turbine Impulse Pressure immediate operator action Instrumentation.
RD (Step 1) Check no load rejection in Note: If rods are in auto rods progress will be stepping in at 72 steps per minute. After no load rejection is verified rods should be placed in manual.
RD (Step 2) Check no ROD motion.
- Place rod control in Manual 1
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # I Page 2 of 31 Event
Description:
PT447, Turbine first stage impulse pressure, fails LOW Time Pos. Expected Actions/Behavior Comments BOP (Step 3) IF the selected channel of Pimp has failed, THEN select the unaffected channel.
FIRST STG IMPULSE PRESS SEL SWITCH P51446Z
[] PT-446 (CH-IlI) selected Check C5 permissive light on.
LOW TURB IMPULSE PRESS AUTO ROD WDRL
[1 BLOCKED 0 lit RO! (Step 4) IF required, THEN restore Tavg to BOP programmed value.
NOTE: T-446 and PT-447 are the two inputs to P13. Tech Spec 3.3.1 Table 3.3.1-1 Function 1 7f requires two channels operable in mode 1. The one hour required action for condition U states, Verify interlock is in required state for existing unit conditions. With either PT-446 or PT-447 disabled P13 would still be in the required state (above 10% power) as indicated by the P13-LOW TURBINE IMPULSE PRESSURE PERMISSIVE Bypass and Permissive window not illuminated.
SRO (Step 5) Refer to Tech Spec 3.3.1 & 3.3.2 for I 7f will be verified that the LCO requirements. interlock is in the required T.S. 3.3.1 Condition U and state and at 100% power it will 3.3.2 Condition D be.
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 I 7f Turbine Impulse Pressure, P-i 3
- Applicable in Mode I 2 required channIs condition_U SRO CONDITION REQUIRED ACTION COMPLETION TIME U. One channel U. 1 Verify interlock is in inoperable, required state for existing unit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months conditions.
OR M. 2 Be in Mode 2. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 1 Page 3 of 31 Event
Description:
PT447, Turbine first stage impulse pressure, fails LOW Time Pos. Expected ActionslBehavior Comments TECHNICAL SPECIFICATION 3.3.2, Engineered Safety Feature Actuation System (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 Applicable in Mode I required channels- 2 per steam line condition D SRO CONDITION REQUIRED ACTION COMPLETION TIME D. One channel NOTE inoperable. The inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.
D. 1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 0.2.1 Be in mode 3 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND D.2.2 Beth mode 4 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SRO (Step 6) Notify the Shift Manager RO (Step 7) [CA] WHEN Tavg is within +/-1°F of Tref AND plant conditions permit, THEN return rod control to auto.
SRO (Step 8) Submit a condition report documenting the failure and notify the Work Week Coordinator of the condition reøort.
SRO IF PT-447 failed, AND it is desired to reset Note: C-7A should not be reset C-7A, THEN go to SOP-I 8.0, STEAM DUMP in the event of a failure of PT SYSTEM. 447 which actuates C-7A without consultation with the Operations manager C-7A will not be reset At the discretion of the Lead Examiner move to Event #2.
3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 2 Page 4 of 31 Event
Description:
IA HDT pump trips due to the HDT dump valve failing open V915A, HDT dump valve, will fail open. This will cause the level in the 1A HDT to fall and the IA HDT to trip on low level.
Indications Available:
Annunciators: Indications:
- IAOR lB HDT PUMP TRIPPED (LAI) - SGFP suction pressure
- SGFP SUCT PRESS LO (KB4) probable - 1A HDT level ..
- 1A HDT pump amber light LIT Time Pos. Expected ActionslBehavior Comments version 50.0 LAI BOP (step 1) Monitor SGFP suction pressure. IF low suction pressure annunciator KB4 alarms, THEN refer to ARP-1.10.
version 70.0 KB4 BOP (step 1) WHEN low pressure alarm comes in, THEN observe suction pressure on MCB recorder PR-4039 or plant computer Step 2 is not applicable (step 3) IF a feedwater heater malfunction is AOP-1 3 steps are on page indicated, THEN go to AOP-13.0, Condensate 6 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:
- Check the MCB level indication for the appropriate heater drain tank.
- Dispatch personnel to turbine building to check the heater drain tank dump valve and jack it closed if necessary.
- Restart the heater drain pump if there is sufficient level in the heater drain tank.
Steps 6 & 8 are not applicable 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenano # 5 Event # 2 Page 5 of 31 Event
Description:
IA HDT pump trips due to the HDT dump valve failing open Time Pos. Expected ActionslBehavior Comments (step 7) IF suction pressure continues to decrease, THEN start the standby condensate oumo orior to reach mo 275 PS 1G.
BOP (step 9) IF operation with three condensate pumps is required, THEN carefully monitor Tave, reactor power, pressurizer level and pressure, and 5/0 level due to effects of colder feedwater.
version 500 LAI BOP (step 2) Determine which pump has tripped by observing red! green/amber status lights above pump handswitches on MCB.
Steps 3-4 are not applicable BOP (step 5) Observe Heater Drain Tank level indicators on MCB
- IF level is low, THEN dispatch personnel to check affected HDT dump valve and Heater Drain Tank to attempt to determine cause of pump trip.
- A Heater Drain Tank dump valve NI N26V915A
- B Heater Drain Tank dump valve Nl N26V915B SRO (step 6) Have personnel in Turbine Bldg. to perform the following:
- Verify cause of trip.
- Observe Pump and Heater Drain Tank during_any_restart_attempt_pumo.
SOP (step 7) IF a Heater Drain Pump restart is to be attempted, THEN restart lAW SOP-21 .0, Condensate And Feedwater System.
Step 8 is not applicable SOP IF suction pressure continues to decrease, THEN start the standby condensate pump prior to reaching 275 PSIG.
Restore condensate/heater drain system to normal operating conditions as soon as possible per 21.0, Condensate And Feedwater System.
5
Appendix D Operator Action Form ES..D-2 Op Test No.: FA2012301 Scenario # 5 Event # 2 Page 6 of 31 Event
Description:
IA HDT pump trips due to the HDT dump valve failing open (step 6.1) Check SGFP suction pressure stabilizes above 275 psig.
(step 6.1 RNO) Verify standby condensate When the cond pump is pump started started the suction pressure will rise.
(step 6.2) Check required number of HDT Go to RNO pumps running.
(step 6.2.1) Reduce turbine load at 5 MW/mm to restore reactor power within limits as reqd (step 6.2.2) Dispatch operator to investigate affected HDT 6.2.3 IF HDT dump valve failed open, THEN restore tank level.
N1N26V915A(B) affected heater
-
drain pump dump valve jacked closed
Verify heater drain tank level restored Start affected heater drain pump
Verify level control normal
-
(step 6.3) Check required number of condensate pumps running.
(step 6.4) Verify proper position of condensate and feedwater system valves.
(step 6.5) Check LESS THAN three condensate oumos running.
(step 6.5.1)lF required to allow operation with two condensate pumps, THEN reduce turbine load to 840 MW.
(step 6.5.2) WHEN operation with two condensate pumps acceptable, THEN stop one condensate pump and place in AUTO.
When HDT pump restarted and at the discretion of the Lead Examiner move to event #3.
6
Appendix D Operator Action Form S-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 3 Page 7 of 31 Event
Description:
IA charging pump sheared shaft 1A 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) - Fl-I 22A decreasing to 0 gpm
- RCP SEAL INJ FLOW LO (DD1) - IC Chg pump amps decrease to 52 amps
- LTDN ORIF ISO VLV REL LINE TEMP HI - SI flow decreases to 0 gpm on all 3 RCPs (DE3) - VCT level will .
- Przr level will slowly
- FK-122 demand will go to approx. 0
- LK-459F will t slowly Time Pos. Expected Actions/Behavior Comments ver 17.0 EA2 will direct the crew to AOP-1 6.0 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
- P1-121 and ammeter for chg pump
- Actual amps will be lower than normal RO (Step 1) Verify charging flow adequate to cool letdown.
RNO close all LTDN ORIF ISOs
Letdown flow is secured
[1 QIE21HV8I49A
[1 QIE2IHV8I49B
[1 QIE2IHV8I49C RO (Step 2) Stop any load change in prociress RO (Step 3) Monitor VCT level to ensure proper level is maintained 7
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 5 Event # 3 Page 8 of 31 Event
Description:
IA charging pump sheared shaft Time Pos Expected ActionslBehavior Comments RO (Step 4) [CA] Observe CHG HDR PRESS Amps will be lower than and MOTOR AMPS to ensure proper normal charging pump operation.
[] P1-121
[1 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 1A charging pump may be pump as follows: stopped at any time but will not (step 5.1) Check VCT level and pressure be procedurally directed to be secured.
adequate.
5.2 Verify charging suction flowpath aligned:
VCT OUTLET ISO valves
[1 Q1E21LCV115C OPEN -
[]Q1E21LCV115E-OPEN OR EJ RWST TO CHG PUMP valves
[j Q1E21LCV115B OPEN -
[] Q1E21LCVI15D 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:
ID 1A CHG PUMP MINIFLOW ISO, Q1 E21 MOV81O9A ID 18 CHG PUMP MINIFLOW ISO, Q1E21MOV81O9B ID 1C CHG PUMP MINIFLOW ISO, Q1 E21 MOV81O9C (step 5.5) Verify CHG PUMP MINIFLOW ISO. Q1E2IMOV8IO6, is ooen.
8
Appendix D Operator Action Form ES-D-2 Op Test NO.: FA2012301 Scenario # 5 Event # 3 Page 9 of 31 Event
Description:
IA charging pump sheared shaft (step 5.6) \ -
j the following are closed:
[1 CHG FLOW FK 122
[] SEAL WTR INJECTION HIK 186 (step 5.7) Verify a COW 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 P1 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 controlling in AUTO with flow indicated RO (Step 7) Check DE3 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
- LTDN HX OUTLET FLOW, Fl-150, NO FLOW INDICATED (Step 8.2) Minimize RCS makeup:
Manually close charging flow control:
CHG FLOW
[1 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
9
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 3 Page 10 of 31 Event
Description:
IA charging pump sheared shaft Time Pos. Expected ActionslBehavior Comments RO (Step 9) Determine if normal letdown should be re-established:
Check normal letdown malfunction(s) -
CORRECTED Rstnr IAtdnwn with the followinq steps:
RO (Step 9.2) Verify all letdown orifice isolation valves CLOSED
-
LTDN ORIF ISO 45 GPM
[] QIE21HV8I49A LTDN ORIF ISO 60 GPM
[1 Q1E21HV8149B
[] Q1E21HV8149C (Step 9.3) Place LP LTDN PRESS PK 145 on service:
[] Place controller in MANUAL
[j Adjust demand signal to 50% or less (Step 9.4) Place LTDN HX OUTLET TEMP TK 144 on service:
[] Place controller in AUTO
[j Set to maintain temperature 90 to 115°F RO (Step 9.5) Verify VCT HI LVL DIVERT VLV LCV-1 1 5A alignment:
[] Position indicator VCT light LIT
-
[1 Handswitch in AUTO
-
10
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 3 Page 11 of 31 Event
Description:
IA charging pump sheared shaft Time Pos Expected ActionslBehavior Comments (Step 9.6) Verify LTDN HI TEMP DIVERT RO VLV Q1E21TCV143:
[] DEMIN light LIT-
[1 Handswitch in AUTO (Step 9.7) IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the PRIP.
[] Q1E21HV8175A
[] Q1E21HV8175B (Step 9.8 Verify LTDN LINE CTMT ISO Q1E21HV8152 OPEN -
(Step 9.9 Verify LTDN LINE ISO valves -
OPEN
[1 Q1E21LCV459 Fl Q1E21LCV46O 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 E1 2 Orifices 40 gpm
-
(Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:
[1 QIE2IHV8149B OR
[1 QIE21HV8149C RO (Step 9.12) [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 9.13) Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -
BETWEEN 260-450 PSIG 11
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 5 Event # 3 Page 12 of 31 Event
Description:
IA charging pump sheared shaft Time Pos. Expected Actions!Behavior Comments RO (Step 9.13.1) Set controller between 4.3 and 7.5 (Step 9.13.2) Check letdown flow STABLE (Step 9.13.3) Place PK 145 in AUTO (Step 9.13.4) Control Letdown pressure as desired (Step 9.14) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.
[] TI-i 16 VCT TEMP
[] Tl-143 DIVERT LTDN HXTEMP
[1 TI-i 44 CCW LTDN HX TEMP (Step 9.15) 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 Evaluate Tech Specs Refer to Technical Specifications LCOs 3.5.2, and Technical Requirements TR 13.1.5 3.5.2 Mandatory LCO Condition A; since the 1 B chg pump is aligned to B Train. 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO until the I B chg pump is placed on A Train and the 1A CHG pump is either racked out or has a jumper installed to allow I B chg pump to auto start 13.1.5 Admin LCO Condition A. Two charging pumps shall be operable. 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months LCO 12
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 3 Page 13 of 31 Event
Description:
IA charging pump sheared shaft TECHNICAL SPECIFICATION 3.5.2, ECCSOperati ng 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 OPERABLE status 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.
AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.
TECHI ICAL REQUIREMENT 13.4.5, Charging Pumps Operating -
Two charging pumps shall be FUNCTIONAL.
APPLICABILITY: MODES 1, 2, 3, and 4 This s an AD 4IN LCO except durinq the pump swap placing lB chargin pumi 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 0.02 hours 1.190476e-4 weeks 2.7396e-5 months nonfunctional. FUNCTIONAL status.
SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts)
Notify the Shift Manager At the discretion of the Lead Examiner move to Event #4.
13
Appendix D Operator Action Form ES.D-2 Op Test No.: FA2012301 Scenario # 5 Event # 4 Page 14 of 31 Event
Description:
PT-464 fails LOW PT-464 will fail LOW. SGFP speed will decrease causing FRVs to open due to lower Feed flow than steam flow. SG NR levels will decrease to a trip setpoint if SGFP speed is not controlled in a timely manner.
Indications Available:
Annunciators: Indications of PT-464 failure:
- IA SG LVL DEV (JF1) - Pl-464A decreasing to 0 psig
- 1 B SG LVL DEV (JF2) - Rx power
- IC SG LVL DEV (JF3) - SGFP speed
- SGWLs version 11 SRO Directs RO or BOP to address ARPs as time permits
. 1A,1B,&ICSGLVLDEV(JFI,2
&_3)
SRO Directs entry into AOP-100, section 1.4, and performance of immediate actions, then directs subsequent actions BOP (step 1) Maintain SG level at the referenced Step I is an Immediate level of 65%. Operator action Take manual control of SGFP speed control NOTE: Step I is a continuing SK-509A taken to manual and increases action step soeed SRO (step 1.3) a loss of main feedwater has occurred, THEN perform the actions required by AOP-13.O, LOSS OF MAIN FEEDWATER.
SRO (step 2) Set manual trip criteria on SG level (high and low trip setpoints are 82% & 28% resoectivelv)
BOP (step 3) IF a ramp is in progress, THEN place turbine on HOLD.
14
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 4 Page 15 of 31 Event
Description:
PT-464 fails LOW Time Pos. Expected ActionslBehavior Comments BOP (step 4) Adjust speed of SGFPs to maintain See table below approximate DP for the existing power level Approximate tiP can be determined from the following MCB indications.
o SGFP DISCH PRESS P1-4003 o SG Pressure indications:
/G CH II CH III CH IV A S/G P1-474 P1-475 P1-476 B S/G P1-484 P1-485 P1-486 C SIG P1-494 P1-495 P1-496 Unit 1 NO LOAD tiP is 50 psid from 0-28.1%. PROGRAM tiP is linear from 50-190 psid from 28.1% to 100%. TABLE 1 provides approximate tiP values for varying power levels.
%POWER DP 70 132 psid 80 151 psid 90 171 psid 100 190 psid SOP (step 5) Check Stm Dumps in the Tavg mode SRO (step 6) Notifies Shift Manager SRO (step 8) Submits a CR & Notifies the Work Week Coordinator At the discretion of the Lead Examiner move to Event #5.
15
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 5 Event # 5 Page 16 of 31 Event
Description:
Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17 entry.
NC5, GEN BUS CLG ALARM, will come into alarm. The report from the TB SO will be that the belt for the bus duct cooling system has broken. The ARP response is to ramp the unit to 13,200 amps w/i 45 minutes, which is less than 63% power. Normal 100% amperage is approx. 22,500 amps.
Indications Available:
Annunciators: - Indications: NONE
- GEN BUS CLG ALARM (NC5) Verbal report of Bus Duct cooling is not operating correctly Time Pos. Expected ActionslBehavior Comments IVERSION 18.1 SRO (step 1) Notify the Load Dispatcher (GENCOMM) of the problem Request the SM to call PCC via SYSTAT.
BQP (step 2) call TBSO to determine the cause of NOTE:
the alarm. When information received that the Bus Duct Cooling fan belt is broke and the fan is NOT running then continue to step 3 SRO (step 3) Directs ramp to approx. 63% power If forced cooling is lost from using AOP-17.1 and UOP-3.1. the bus duct cooling fan then ramp down to 13,200 amps (AM 4077, 4078, 4079) w/i 45
- Call SM and SRC to inform of ramp minutes version_1 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 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to perform STP-746 (SR 3.4.16.2) 16
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 5 Event # 5 Page 17 of 31 Event
Description:
Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17 entry.
Time Pos. Expected Actions/Behavior Comments BOP (step 2) Reduce turbine load at desired rate in OPERATOR AUTO (DEH)
- Desired rate will be between 7 and 10 MW/mm On the DEH panel:
- Press SETPOINT
- Set desired TARGET
- Select desired RATE
- Verify the HOLD light is LIT.
- Press the GO pushbutton and ensure the GO light is LIT
- Ensure the Main Turbine starts to ramp UP,_GVs start to_open.
RO (step 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 mixina (step 3.3) RO will adjust rod position to maintain Delta I w/l limits 17
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 5 Page 18 of 31 Event
Description:
Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17 entry.
Time Pos. Expected Actions/Behavior Comments (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 io RO (Step 1.0) Borating per SOP-2.3 appendix B
Set the boric acid integrator to the desired uantit NOTE: A continuous boration aHowedbyappendixC
Adjust LTDN TO VCT FLOW LK 112 setpoint as desired system lined up and the RO
M/U mode selector to STOP will take the MSS to START
MKUP MODE SEL SWITCH to BOR 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 FCVI 13B opens.
BORIC ACID TO BLENDER FCV1 1 3A opens.
Boric acid flow is displayed on Fl-i 13 MAKEUP FLOW TO CHGNCT.
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 18
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 5 Event # 5 Page 19 of 31 Event
Description:
Bus duct cooling alarm, NC5, ramp unit to approx. 63% power in 45 minutes. Fast ramp required AOP-17 entry.
Time Pos. Expected ActionslBehavior 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/l limits RO (step 6) when power reduction completed Continuing action step then restore Tavg to programmed value When power reduction to approximately 85% power and per Lead Examiner move to Event #6.
19
Op Test No.: FA2012301 Scenario # 5 Event # 6 Page 20 of 31 Event
Description:
At 90% power, I B FRV fails shut slowly while ramping down 1 B FRV fails closed causing the crew to evaluate tripping the reactor.
Indications Available:
Annunciators: Recognize indications of 1 B FRV closing:
- I B SG STM FLOW> FEED FLOW (JB2) - I B FRV controller going to 100% demand
- 1 B SO LVL DEV (JF2) - Steam flow> Feed Flow
- 1BSGWLNR Time Pos. Expected Actions/Behavior Comments Ver32, step 4 SS Directs AOP-1 3 entry RO (Step 4) Check main feed regulating valve(s) automatic control inadequate.
(step 4.1) Take manual control of the affected main feedwater regulating valves as necessary to control SO level.
[1 1A SO FW FLOW FK-478
[] I B SG FW FLOW FK-488
[] 1 C SO FW FLOW FK-498 RO (Step 4.2) Maintain SG narrow range level aooroximatelv 65%.
SRO RNO (step 4.2) IF SO narrow range levels Direct the reactor trip and enter NOT maintained greater than 28%, THEN EEP-0 trip the reactor and go to EEP-0, REACTOR Critical task TRIP OR SAFETY INJECTION.
I, version 43 20
Op Test No.: FA2012301 Scenario # 5 Event # 6 Page 21 of 31 Event
Description:
At 90% power, 18 FRV fails shut slowly while ramping down Time Pos. Expected Actions/Behavior Comments ROI 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.
(step 4) Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[1 ACTUATED status light lit
[1 MLB1 11 lit
[j MLB-1 11-1 lit When ESP-O I entered then put in LOSP at step 3 of ESP-O I Steps I 6 of ESP-0.1 below Iversion 32 SRO Directs actions in ESP-0.1 per RO/BOP Actions listed below
Ñ 21
Op Test No.: FA2O1 2301 Scenario if 5 Event if 6 Page 22 of 31 Event
Description:
At 90% power, I B FRV fails shut slowly while ramping down Time Pos. Expected ActionslBehavior Comments RO (step 1) Check RCS temperature NOTE: this is a continuing
- Stable at or approaching 547°F action step
- TAVG IA(1B,IC) RCS LOOP
[] TI 412D
[] TI 422D STM DUMP Ii TI_432D BOP (step 1 RNO) Verify steam dumps closed. RCS temperature will be STM DUMP INTERLOCK decreasing due to the RCP
[1 A TRN in OFF RESET trips and AFW flow OR
[1 B TRN in OFF RESET BOP Verify atmospheric reliefs closed 1A(1B,1C)MSATMOS RELVLV
[] PC 3371A
[1 PC 3371B
[1 PC 3371C BOP (step 1.1.3) IF MSIVs are open, THEN Directs TB SO to wrap up the isolate turbine building steam loads while TB completing steps 1.1.3.1 continuing with RNO step 1.1.4. 1.1.3.3 BOP (step 1.1.4) IF cooldown continues, THEN Adjusts pots for AFW flow to minimize total AFW flow, maintain > 395 gpm if SG NR AFW FLOW TO 1A(1B,1C) SG levels are <31%
[] Fl 3229A
[] Fl 3229B
[] Fl 3229C AFW TOTAL FLOW
[1 Fl 3229 El Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[1 A TRN reset
[1 B TRN reset MDAFWPTO INIB/1CSG BTRN
[] FCV 3227 in MOD Control TDAFWP flow.
BOP (step 1.1.5) IF cooldown continues, THEN Cooldown should be under close main steam isolation and bypass control by this time valves.
22
Op Test No.: FA2012301 Scenario # 5 Event # 6 Page 23 of 31 Event
Description:
At 90% power, I B FRV fails shut slowly while ramping down Time Pos. Expected ActionslBehavior Comments SOP (step 2) WHEN RCS average temperature NOTE: this is a continuing less than 554°F, THEN verify feedwater action step status.
- Verify FRVs closed (step 2.2) MDAFWP AUTO/DEFEAT
[] 1A in DEFEAT
[JIB in DEFEAT (step 2.3) -Verify BOTH SGFPs tripped (step 2.4) -Verify total AFW flow to the SGs
>395 gpm RO (step 3) Verify ALL RX TRIP breakers OPEN RO (step 4) Check emergency Boration not required
- All rods FULLY INSERTED
- RCS Tavg >525° F SOP (step 5) Announce Unit 1 Reactor Trip BOP/ (step 6) Check AFW status RO - Check secondary heat sink available Check total AFW flow> 395 gpm OR Check any SG narrow range level GREATER than 31%
RNO ACTONS Verify all available AFW pumps started Verify AFW flow> 395 gpm OR any SG level>_31%
When ESP-O.1 step 3 started OR if EEP-0.0 entered; then at step 5, and at the discretion of the Lead Examiner, move to Event 7.
23
Op Test No.: FA2012301 Scenario # 5 Event # 7 Page 24 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.1 I TDAFWP does not auto start.
A LOSP event occurs. 1C DG is tagged out, 1-2A DG will not start and lB DG starts but trips.
2C DG will not start.
Indications Available:
Annunciators: Recognize indications of Loss of ALL AC power Many and various
- RCPs tripped EPB power indication lights not LIT
- Components not running Time Pos. Expected Actions/Behavior Comments version 25 SRO Recognize Loss of all AC and direct lOAs of ECP-O.
RO/ (step 1) Check reactor tripped. Immediate Operator actions of BOP ECP-O are steps I and 2
[1 Check reactor trip and reactor trip bypass No power breakers OPEN.
-
[] Nuclear power FALLING
(step 1.1 RNO) Manually trip reactor.
(step 1.2) IF reactor can NOT be tripped, THEN trip both MG set supply breakers.
[] N1C11EOO5A
[] N1C11EOO5B YES (step 2) Check turbine tripped.
[] TSLB2 14-1 lit
[] TSLB2 14-2 lit
[1 TSLB2 14-3 lit
[1 TSLB2 14-4 lit 24
Op Test No: FA2012301 Scenario # 5 Event # 7 Page 25 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.1 I TDAFWP does not auto start.
RO (step 3) Verify RCS isolated.
(step 3.1) Verify normal letdown isolated.
3.1.1 Verify all letdown line orifice isolation valves CLOSED.
-
LTDN ORIF ISO 45 GPM
[J Q1E21HV8149A LTDN CRlF ISO 60 GPM
[1 Q1E21HV81498
[1 Q1E21HV8149C OR 3.1.2 Verify letdown line isolation valves -
CLOSED.
LTD LINE ISO
[1 Q1E21LCV459
[1 Q1E21LCV46O (step 3.2) WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
(step 3.3) Verify excess letdown line -
ISOLATED.
EXC LTDN ISO VLV
[1 Q1E21HV8153 closed
[1 Q1E21HV8154 closed (step 3.4) Verify all reactor vessel head vent valves CLOSED.
-
RX VESSEL HEAD VENT OUTER ISO
[1 QIBI3SV2213A
[1 QIBI3SV2213B RX VESSEL HEAD VENT INNER ISO
[]Q1813SV2214A
[1Q1B135V2214B 25
Op Test No.: FA2012301 Scenario # 5 Event # 7 Page 26 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.1 I TDAFWP does not auto start.
RO (step 4) Verify total AFW flow GREATER Critical task start the
THAN 395 gpm. TDAFW pump AFW TOTAL FLOW
[1 Fl 3229 RNO (step 4) Verify TDAFWP running.
TDAFWP STM SUPP FROM 1B(1C) SG
[]MLB-4 1-3 lit
[]MLB-4 2-3 lit
[]MLB-4 3-3 lit TDAFWP SPEED
[]Sl 3411A>3900 rpm TDAFWP SPEED CONT
[1 SIC 3405 adjusted to 100%
Place TDAFWP STM SUPP FROM lB SG HV3235A126 AND TDAFWP STM SUPP FROM 1C SG to the START position BOP (step 5) [CA] Restore power to any emergency bus.
(step 5.1) Verify supply breakers for major loads on emergency 4160 V busses OPEN. - On EPB
[]BKR DFO1 (lAS/U XFMR TO iF 4160 V BUS)
[1 BKR DF15 (lB S/U XFMR TO IF 4160 V BUS)
[]BKR DF-13-1 (iF 4160 V BUS TIE TO 1H 4160 V BUS)
[]BKRDGO1 (lAS/U XFMRTO 1G4160V BUS)
[]BKR DG15 (lB S/U XFMR TO 104160 V BUS 26
Op Test No.: FA2012301 Scenario # 5 Event # 7 Page 27 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.1 I TDAFWP does not auto start.
BOP/ [1 Ic CCW PUMP BKR DF-04-1 Load shed list continued from RO [1 1 B ccw PUMP BKR DF-05-1 above
[] I B ccw PUMP BKR DG-05-1 components on MCB and may
[1 1A CCW PUMP BKR DG-04-1 be verified by RO
[j 1A SW PUMP BKR DK-03-1
[jiB SW PUMP BKR DK-04-1
[1 1 c SW PUMP BKR DK-05-1
[1 1 c SW PUMP BKR DL-05-1
[] 1 D SW PUMP BKR DL-03-1
[] 1ESW PUMP BKR DL-04-1
[] #4 RW PUMP BKR DJ-03-1
[1 #5 RW PUMP BKR DJ-04-1
[1 #8 RW PUMP BKR DH-03-1
[] #9 RW PUMP BKR DH-04-1
[1 #10 RW PUMP BKR DH-05-1
[1 lB CRDM CLG FAN BKR ED-Il-I
[1 1A CRDM CLG FAN BKR EE-13-I
[1 lAGS PUMP BKR DF-11-I
[1 lB CS PUMP BKR DG-11-1
[] 1A RHR PUMP BKR DF-09-1
[] lB RHR PUMP BKR DG-09-1
[] 1A CHG PUMP BKR DF-06-1
[] 1 B CHG PUMP A TRN BKR DF-07-1
[] 1 B CHG PUMP B TRN BKR DG-07-1
[1 1C CHG PUMP BKR DG-06-1
[j 1A MDAFWP BKR DF-10-1
[] 1 B MDAFWP BKR DG-lO-1 BOP Check 1-2A, IC or lB diesel generator running for Unit I. NO Perform 2C DG SBO start:
o MSS in MODE I o USSinUNIT1 o When load shed has been competed_then_depress_START_PB 2C DG will NOT start SRO (step 5.8) IF iF OR 1G 4160 V bus energized THEN go to procedure and step in effect and implement function restoration procedures as necessary.
SRO RNO (step 5.8) Continue efforts to start at energized, least one diesel aenerator 27
Op Test No.: FA2012301 Scenario # 5 Event # 7 Page 28 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.i I TDAFWP does not auto start.
SRO (step 5.9) Restore offsite power to any emergency bus.
SRO RNO (step 5.9) 5.9 Continue efforts to energize any 4160 V emergency bus and proceed to Step 6. OBSERVE NOTE PRIOR TO STEP 6.
SRO (step 5.9.1) Request Shift Manager coordinate efforts to restore offsite power to at least one startup transformer.
NOTE: Step 6 ensures that proper recovery actions are taken in a timely manner.
SRO (step 6) Perform the following.
6.1 [CA] WHEN power is restored to any emergency bus, THEN proceed to step 25.
6.2 [CA] WHEN an SI signal is present, THEN reset SI signal.
SRO (step 7) Defeat auto start of safeguards equipment using ATTACHMENT 2.
SRO (step 8) Isolate RCP seals using Critical task call to ensure
ATTACHMENT 3. Attach 3 is performed BOP (step 9) Locally close HOTWELL FILL Call TB SO INLET ISO N1P11V5O1 and HOTWELL FILL MAN BYP N1P11V5O6. (137ff, TURB BLDG) 28
Op Test No.: FA2012301 Scenario # 5 Event # 7 Page 29 of 31 Event
Description:
Loss of ALL AC power while in ESP-O.1 I TDAFWP does not auto start.
BOP (step 10) Check SG status
- Verify MSIVs and Bypass valves closed 1A(1B,1C)SG MSIVTRIP
[1 Q1NI1HV3369A
[J QINIIHV3369B
[] QINI1HV3369C
[1 QINIIHV337OA
[1 Q1N1IHV337OB
[J Q1NI1HV337OC 1A(IB,IC)SG MSIV- BYPASS
[1 QINIIHV3368A
[1 QIN11HV3368B
[] Q1NIIHV3368C
[] QINIIHV3976A
[] Q1NIIHV3976B
[1 QIN11HV3976C BOP (step 10.2) Verify main feedwater flow control and bypass valves CLOSED.
-
1A(1B,IC) SG FW FLOW
[JFCV478
[j FCV 488
[] FCV 498 1A(1B,IC)SG FW BYP FLOW
[] FCV 479
[] FCV 489
[] FCV 499 BOP RNO (step 10.2) Locally isolate main Call Rover/SSS to close these feedwater flow path(s). valves
- Locally close main feedwater stop valves with handwheels. (127 ft, AUX BLDG main steam valve room)
BOP (step 10.3) Verify blowdown - ISOLATED.
IA(IB,IC) SGBD ISO
[] HV7614A closed
[]HV7614B closed
[1HV7614C closed This is where off site power is restored and ACC calls to control room to inform them the grid is stable.
29
Op Test No.: FA2012301 Scenario # 5 Event # 8 Page 30 of 31 Event
Description:
Restoration of power to the plant from the GRID.
BOP (Step 11) Check SGs not faulted Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR < 50 psig.
SRO (step 5.9.2) Consult the PCC to ensure that the grid is stable and reliable prior to realioninci emeroencv buses to offsite oower.
Phone call to SM precedes this steo.
SRO Direct the BOP to restore power to one emergency bus per step 5.9.3 below:
BOP (step 5.9.3) WHEN any startup transformer energized, THEN close associated S/U transformer output breaker.
- DFO1lF4l6OVbus
- DG15lG4l6OVbus BOP (step 5.9.5) WHEN I F or 1 G 4160 V bus NOTE: The SYNCH BYPASS energized from any startup transformer, switch must be held in the THEN verify the associated river water bus BYPASS position when breaker closed. performing the following step.
Per step 6.1, the crew will go to step 25 as shown below:
SRO (step 25) Check at least one train of 4160 V ESF busses ENERGIZED.
-
[1 A Train (F & K) power available lights lit
[1 B Train (G & L) power available lights lit (step 26) Verify SW system operating.
- Verify at least one SW train HAS TWO
-
SW PUMPs RUNNING.
[jA Train (1A,1B or IC)
U B Train (iDlE or IC)
- Verify SW flow through at least one train of containment coolers -> 0 gpm.
SW THROUGH CTMT CLRS INLET
[]Fl 3013A
[]Fl 3013B
- Verify SW to DG BLDG valves - OPEN.
SW TO/FROM DG BLDG - A HDR
[jQ1P16V519/537 SW TO/FROM DG BLDG - B HDR
[1 Q1P16V518/536 30
Op Test No.: FA2O1 2301 Scenario # 5 Event # 8 Page 31 of 31 Event
Description:
Restoration of power to the plant from the GRID.
(step 27) Verify electrical alignment Verify battery charger in at least one train -
ENERGIZED.
[] A Train (1 A or I C) amps > 0
[j B Train (1 B or IC) amps > 0 (step 27.2) IF A train 4160 V buses NOT energized, THEN proceed to step 28.
(step 27.3) Verify IC air compressor in service.
(step 28) [CA] Maintain intact SG pressures No action required since the stable at current value. ARVs were not manipulated (step 29) Check all Condensate Pump These will be at this time oower suoolies ENERGIZED
-
(step 30) Restore intact SG AFW flow No action required control valve jacking devices to normal position.
(step 31) Evaluate plant conditions RNO (step 31.1) Go to ECP
- Check SCMM indication -> 16°F 0.2, LOSS OF ALL AC SUBCOOLED IN CETC MODE. POWER RECOVERY WITH SI
- Check pressurizer level-> 13% REQUIRED.
- Check SI equipment - HAS NOT ACTUATED UPON AC POWER RESTORATION such that SI flow occurred.
(step 31.2) Go to ECP-0.1, LOSS OF ALL AC POWER RECOVERY WITHOUT SI REQUIRED.
Terminate the scenario when offsite power is restored to Unit I OR at the discretion of the Lead Examiner 31
Appendix D Crew Briefing sheet Form ES-D-2 OpTest No.: FA2012-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.
In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
AssiQn operatinQ positions.
Ask for and answer Questions.
C) CO CJ)CO COC Cl) 0 oO CD 0 CD b-1 C m G) i 3
H 0 o <
(I) 0 0 CD 0 D3 ..< Cl)
- V Cl) CD Cl)
CD 0 .
o C CD -
CD 0CD- tIJSD O
< 0<0. C (I) C 3QO - I CD
>< H
-a -
I 0 0 Cl DU).CD U) U) 0
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Scenario #6 FA2O1 2301 Southern Nuclear M. Farley Nuclear Plant 1
J Operations Training Simulator Exam Scenario BOOTH INSTRUCTOR GUIDE ILT-35 NRC EXAM SCENARIO #6 Need to prebrief the STA NOT to prompt the Foldout page entry to ECP1 .1 Validation time: 100 minutes Validated by David Shipman, Todd Smith and Doug Jimmerson The week of February 13, 2012 TRN Supervisor Approval: Gary Ohmstede 3/2/12 NRC Chief Examiner SEE NUREG 1021 FORM ES-301-3 SOUTHERN COMPANY
Appendix D Scenario #6 Outline Form ES-D-1 Facility: Farley Nuclear Plant Scenario No.: 6 Op-Test No.: FA2012-301 Examiners: Operators: SRO RO BOP Initial Conditions: Mode 3, MOL, Shutdown banks are pulled, Xe decreasing from its peak following the reactor trip. The reactor tripped 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months ago as a result of the loss of both SGFPs, ATrain On-Service A Train Protected Turnover:
0% RTP, MOL, 893 ppm Cb, 10,000 MWD, Xe concentration is slowly decreasing,
Reactor tripped 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months ago as a result of loss of both SGFPs & repairs are in progress,
Reactor Startup planned in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , ECC being calculated by Reactor Engineering,
Current Risk Assessment is and projected is
A Train On-Service A Train Protected
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
SPLIT TRAIN ALIGNMENT Event MaIf. Event Type* Event Description No. No.
1 N (BOP) Perform STP-11.11, 1A RHR Pump Operability Check.
2 preset C (RO) Initiate an entry into AOP-27 for emergency boration (SSS phone call due to SDM OOS). Boric acid pump 1A will not start and MOV 8104 will not open.
TS will be handled by SSS per the phone call.
3 Imf C (BOP) AFW FCV-3227C fails open, alternate means of isolation 2
j TS (SRO) required to prevent SG overfill. TS 3.7.5 Condition C Imf I (RO) PK- 444A fails HIGH.
4 pk444a-d C (BOP) 1C CCW pump trips on Overcurrent. lB CCW pump does not TS (SRO) auto start. TS 3.7.7 Condition A 6 C (BOP) CCW leak when I B CCW pump starts- Leak can be isolated locally at the 1 C CCW pump due to relief valve lifting. Makeup to CCW surge tank.
7 imf C (RO) PK-145 fails HIGH.
pk145-a Farley June 2012 exam Page 2 of 15
Appendix D Scenario #6 Outline Form ES-D-1 8 Imfmal- M(ALL) A LBLOCA occurs rcs2a C (RO) Automatic SI fails to actuate, manual actuation required. (CT)
C (BOP) 1A & 1 B CTMT coolers fail to auto start, manual start of at least one required C (RO) lB RHR pump falls to auto start, manual start required. (CT) 9 preset C (RO) During the LB LOCA, power to M0V881 1 B (CTMT SUMP to 1 B RHR Pump) will be lost.
preset 1A RHR pump automatically starts, but will trip when RWST C (BOP) level reaches 30 feet.
The combination of problems will prevent the crew from transferring to CL recirc. The crew should transition to ECP-1 .1 per step 14.1 RNO OR FO page of EEP-1 -Makeup to the RWST and minimize RWST outflow (CT)
When ECP-1 .1 is entered and evaluation of equipment running complete, then restore power to 8811 B and transition to EEP 1.0 or ESP-1 .3.
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley June 2012 exam Page 3 of 15
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 Hotwell flush at 0.20 UOP-I.3, v. 62, at step 5.17 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months after trip, MOL, 893 ppm boron Xe -2969 1 Letdown orifice on service Base IC- 019 RUN LJ RUN simulator 0 0 Generic setup:
bat generic setup HLT.txt
0 0 Quick setup (all items with are included):
bat 201 2nrcexam06.txt A1f 2 0 Boric Acid Pump A fails to start in Manual.
Cmfmalf / ccvpoo5a cr2
8 0 auto SI A Train and B Train fails CMFmalf / csftyinj_ccl / open CMFmalf I csftyinj_ccl I I open 1 B CCW pump will not auto start.
5 0 imf cccpo2a_d_cc7 open imf cccpo2a_d cc8 open 6 0 COW leak when dfO4 opens TRG 3 imf Mal-ccw2B (3 1) 150 60 8 0 1 B RHR pump fails to auto start on SI. Manual start allowed.
CMFmalf/ crhpolb d_cc9 / open 8 0 1A & I B ctmt crls do not auto start on LOSP or ESF sequencer
CMFmalf I cchflal_d_cc3 / open CMFmalf I cchfl bl_d_cc3 / open CMFmalf I cchfl al_d_cc4 I open CMFmalf / cchflbl_d_cc4 / open
2 0 MOV-8104 will not open lmf ccvhl04_d_crl 9 0 IA RHR pump trips on overload after auto start TRG 5 imfcrhpola d col (5 0) 9 0 M0V881 1 B breaker trips during LB LOCA 10 minutes TRG 4 CMFremote/irfcrh88llb_d_cdl open 0 Th érsidtó nd
3 0 Trigger I flash JKI A MDAFWP SUCT PRESS LO, event 3
-
when FCV3227C> 0.6 trgset I raf3227c> 0.6 trg 1 imfjkl failon
3 0 Trigger 2 part of flash from trig I, event 3
-
trgset 2 raf3227c> 0.9 Farley June 2012 exam Page4ofl5
Appendix D Scenario 6 Presets Form ES-D-1 EVENT# TIME EVENT DESCRIPTION / ACTION LIST ACTIONS trg 2 dmf jkl
6 0 Trigger 3: start a CCW leak when I B CCW pump is started Event trigger 3 monitors breaker dfo4 open trgset 3 cccp01 c_d_col
8 0 Trigger 4 trigger on LB LOCA
-
Event: trgset 4 jmrcs2a 9 0 Trigger 5 RWST LI 4075a < 30, event 9
-
trgset 5 bsis4O75 < 30 Farley June 2012 exam Page 5 of 15
D6Simulatorsetup 1
izr letdown has 1 on service and charging flow is stable at a low minimum value Turn ON scaler-timer ON DEH Clear DEH alarms Select CRITICAL STARTUP PARAMETERS on MCB IPC monitor Acknowledge computer alarms IPC: IF FF5 is in alarm, update rods Ensure FF5 clear or update rods on IPC Setup spreadsheet on OATC computer to resemble Set up computer reactivity spreadsheet provided Recorders Verify memory disks cleared Provide a marked up copy of UOP-1 .3 version 62 UOP-t3 copy through step 5.16 complete. The following steps should be signed off: P&L: 2.1, 2.2, 2.3, 2.4, 2.5, 2.6, 2.8, 2.9, 2.10 Steps: 5.3, 5,6, 5.7, 5.8, 5.9, 5.11, 5.12, 5.14, 5.15, 5.16 Provide STP-1 1.11, 1A RHR Pump Operability Check STP-1 1.11
-I FREEZE simulator Perform Booth Operators Setup Checklist Open Simview file to be used for plant parameter data collection:
Simview! sv DataCollection.uvl sv DataCollection.uvl If needed, adjust sim time back to 00:00:00 SIMVIEW I Sim_Clock.uvl Hours: clock(3) = 0 Minutes: clock(2) = 0 sv sim_clock.uvl Seconds: clock(1) = 0 VERIFY MICROPHONES READY Batteries installed TURNOVER SHEET AVAILABLE Farley June 2012 exam Page 6 of 15
Appendix D Scenario 6 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND Priorto 0 RUN Start data collection for Simview file On DataCoIIectionuvI file press DATA for drop down and_then_COLLECT_to_start_collecting_data 0 Begin Exam
-..I.
RUN simulator Verify Horns ON: hornflag Turn Horns ON/OFF 1ORNS ON = TRUE ann horn Start of STP-1 1.11 provided 1 Perform STP-1 1.11, 1A RHR Pump Operability Check.
NRC Initiate an entry into A0R27 for emergency boration Phone call 2
CUE (SSS phone call due to SDM OOS).
3 AFW FCV-3227C fails open lmf HIC3227CA-O 420 Reflash JK1 as required 4 PK- 444A fails HIGH lmfpk444a-d035 - -
5 1 C CCW pump trips on Overcurrent imfcccpolc_d_col preset 6 CCW leak when 1 B CCW pump starts TRG 3 imf MaI-ccw2B 150 60 ... --.
7 NRC PK-145 fails HIGH.
CUE imfpkl45-a 1030 8 NRC A LBLOCA occurs CUE Imf mal-rcs2a Farley June 2012 exam Page7ofl5
Appendix D Scenario 6 Booth Guide Form ES-D-1 EXAM EVENT# TIME EVENT DESCRIPTION COMMAND 9 preset M0V881 I B de-energizes 10 minutes after LBLOCA TRG 4 preset 1A RHR pump automatically starts, but will trip when TRG 5 RWST level reaches 30 feet.
Termination: when power is restored to 881 1 B and transition to EEP-1 .0 or ESP-1 .3 has been determined Endof Exam HORNS OFF
..-.
FREEZE simulator Stop data collection for Simview file sv_DataCollection.uvl Export data to file with the name of NRC examOl Ensure data file created.
grpX.txt NOTE: Substitute grpX with grpl, grp2, or grp3 as appropriate.
NOTE: file will be saved in the OPENSIM directory.
Farley June 2012 exam Page 8 of 15
Appendix D Scenario 6 Local Operator Action sheet Form ES-D-1 Local operator actions:
EVENT NO. TIME ACTIONS 1 NONE REQUIRED 2 WHEN REQUESTED Open v185 locally lrf Ioa-cvcO33 1 25 3 WHEN REQUESTED ROVER If reguested to isolate HV3227C Locally:
NOTE: If a local operation is requested for AFW isolation delay isolation for at least 3 minutes. This is to allow the crew to take action from the control room.
Note: The response here is dependent on if isolation is asked for locally.
Manually close FCV-3227c imf raf3227cm 0 25 OR irf cafO335c cdl OR Q1N23VO17F is manually isolated.
REMOTE / N23 I LOA-AFWOIO / 0 I 30 ramp 4 NONE REQUIRED 5 NONE REQUIRED 6 Wait 5 minutes after Isolate CCW leak makeup is initiated, then STOP the leak dmf MaI-ccw2B 7 NONE REQUIRED Farley June 2012 exam Page 9 of 15
Appendix D Scenario 6 Local Operator Action sheet Form ES-D-l Local operator actions:
EVENT NO. TIME ACTIONS 8 WHEN REQUESTED SSS I RADSIDE:
I have performed steps 1 and 2 of attachment 1 of EEP-1 and need you to perform step 3 of attachment I Button goes here CAE ECCSdisc_delayed.cae 8 WHEN REQUESTED Unit Two UO: RESET FIRE ALARM MHI ANN I MH1 failoff Fire alarm is reset. Fire alarm was 1A-22 in Unit One CTMT 9 When ECP-1.1 is entered and evaluation of equipment running complete, then restore power to 8811B.
Farley June 2012 exam Page 10 of 15
Appendix D Scenario 6 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME ACTIONS WHEN REQUESTED Radside SO:
Report that RHR pump looks normal, normal oil levels and other requested information, report all are normal.
Report that F15602A reads 570 gpm.
2 As Directed by NRC SSS:
An extra operator has performed a SDM lAW STP-29.1. There is insufficient SDM and requires an emergency boration of 500 gallons.
I will write the LCO on Tech Spec 3.1.1.
If asked, after 500 gallons they can secure the boration and SSS will call for a sample.
Radside SO:
May be requested to check FAC4. The breaker is closed.
SSS-plant, SM and Dispatcher:
MOV-8104 will not open and 1A BAT pump will not start, CRs written.
WHEN REQUESTED SSS/ ROVER:
FCV-3227C is full open, the air line was broken and leaking. I isolated air to the valve to stop the air leak.
4 WHEN REQUESTED 555-plant, SM and Dispatcher:
Recognize and repeat back PK-444A failure, CR in the cue and that type of communications.
5 WHEN REQUESTED ROVER:
- The 1C CCW pump motor has an acrid smell in the area.
- DFO4 has an overcurrent trip flag.
6 WHEN REQUESTED ROVER:
acknowledges and goes to look for leak Wait 5 minutes
The relief on the IC CCW pump was lifting. The relief has makeup is initiated, then reseated but the relief is still leaking slightly. No valves were STOP the leak from the closed.
LOA page 7 WHEN REQUESTED SSS-plant, SM and Dispatcher:
Recognize and repeat back PK-145 failure, CR in the cue and that type of communications.
Farley June 2012 exam Page 11 of 15
Appendix D Scenario 6 Communications sheet Form ES-D-1 Communications sheet EVENT NO. TIME ACTIONS 8 WHEN REQUESTED SM:
I will make the classifications and notifications.
EXTRA CONTROL ROOM OPERATOR:
Both CRACS mode selector switches are in ON.
Turbine Bldg SO:
Back up cooling to the condensate pumps are aligned.
SMISSS:
I will get someone to perform step 6 of EEP-1 I will get an extra operator to secure the 1 B DG ANY CALL TO SHIFT CHEMIST:
Acknowledge to requirement for sampling 8 WHEN REQUESTED RADSIDE SO:
The A RHR pump has a burnt insulation smell in the room, and the motor is hot to the touch.
2 minutes after I dont see any problem with the MOV-881 I B (CTMT SUMP TO 1 B REQUESTED RHR PUMP) breaker FV-B5, except that its tripped.
ROVER:
WHEN REQUESTED The A RHR pump breaker, DF-09, is tripped on overcurrent.
9 RADSIDE SO:
AS DIRECTED I have reset Breaker FV-B5 for MOV 8811 B, CTMT sump to lB RHR pump.
Farley June 2012 exam Page 12 of 15
Scenario 6 detailed summary Appendix D Form ES-D-1 sheet Initial Conditions: Mode 3, MDL, Shutdown banks are pulled, Xe decreasing from its peak following the reactor trip, The reactor tripped 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months ago as a result of loss of both SGFPs, ATrain On-Service A Train Protected.
Turnover:
0% RTP, MOL, 893 ppm Cb, 10,000 MWD, Xe concentration is slowly decreasing,
Reactor tripped 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months ago as a result of loss of both SGFPs & repairs are in progress,
Reactor Startup planned in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , ECC being calculated by Reactor Engineering,
Current Risk Assessment is and projected is
A Train On-Service A Train Protected
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Event 1 Perform STP-11.11, IA RHR Pump Operability Check.
Verifiable actions: Start 1A RHR pump and record indicated flow, then secure the pump.
Event 2 Initiate an entry into AOP-27 for emergency boration (SSS phone call due to SDM DOS).
Boric acid pump lAwill not start and MDV 8104 will not open. lB Bat pump will start.
Verifiable actions: Start the other BAT pump, align Boration flow path after MOV-81 04 will not open, then align another orifice on service for letdown and increase charging flow.
When the boration is complete, then secure the lineup.
Event 3 AFW FCV-3227C fails OPEN. TS 3.7.5 Condition C for inoperable MDAFW Flowpath to 1 C SG (2 MD trains mop, to C SG. STP-22.8 says Performance of this procedure affects the operability of both MDAFW pumps briefly while MOV-3764A, B, C, D, E & F are stroked closed.
Verifiable actions: Close SOP MOV3764C (B train) OR M0V3764F (A train) OR Jacking closed locally HV3227C OR Isolating HV3227C locally with manual isolation valve OR power up MOV335OC and close it.
Event 4 PK- 444A fails HIGH. RCS pressure will increase to PORV setpoints to open. AOP-100 entry to restore RCS pressure.
Verifiable actions: Take manual control of Sprays and Heaters to control RCS pressure manually.
Event 5 1 C CCW pump trips on Overcurrent. 1 B CCW pump does not auto start. AOP-9 will be entered. TS 3.7.7 Condition A Verifiable actions: Start the I B CCW pump.
Event 6 CCW leak when I B CCW pump starts-Verifiable actions: Makeup to the CCW surge tank.
When the I B CCW pump trips the relief valve will lift and stick open. The relief will reseat when makeup is started to the CCW surge tank per the ARP.
Event 7 PK-145 fails HIGH.
Verifiable actions: Take manual control of PK-145 and reduce controller to open PCV-145.
Due to the letdown relief opening letdown may be removed from service. Then PK-145 taken to manual and closed and then either restore letdown or place excess letdown on service per the ARP and AOP-1 6.
Farley June 2012 exam Page 13 of 15
Scenario 6 detailed summary Appendix D Form ES-D-1 sheet Event 8 A LB LOCA occurs. Auto SI fails to actuate. 1A and lB CTMT coolers do not start in slow speed. 1 B RHR pump will not auto start but can be manually started.
Verifiable actions: Actuate a reactor trip and safety injection. (CT) Start BOTH CTMT coolers in A Train.
Start lB RHR pump. (CT) This is critical since when the RWST gets to 30 feet, 1A RHR pump will trip.
Event 9 1A RHR pump automatically starts, but will trip when RWST level reaches 30 feet and M0V881 1 B (CTMT SUMP to 1 B RHR Pump) will be de-energized.
Verifiable actions: Transition to ECP-1 .1 and secure the CS pumps and CTMT coolers to meet step 10.2 table alignment and call to makeup to the RWST per step 12. (CT)
When step 12 is complete the TSC will call to inform the crew that MOV-881 lB is powered up, then the crew can exit ECP-1 .1 and return to either EEP-1 .0 or ESP-1 .3 depending on RWST level.
Procedures used:
Isolation of FCV-3227C will be per OPS policy for skill of the craft, NMP-AP-003, Procedure and work Instruction Use and Adherence, in combination with AOP-6.0, Loss of Instrument air step 8.2 that allows use of MOVs being cycled to control SGWL 35-69% or SOP-22 step 4.12.1.
STP-l 1.11/ AOP-27 I AOP-1 00 I AOP-9.0 I ARP I AOP-1 6 I EEP-0 I EEP-1 .0! ECP-1 .1 Farley June 2012 exam Page 14 of 15
Scenario 6 Critical Task sheet Appendix D Form ES-D-1 Sheet CRITICAL TASK SHEET
1. Manually actuate at least one train of SIS-actuated safeguards before any of the following: Manually actuate at least one train of SIS-actuated safeguards before any of the following: (WOG CT E-O - - D)
Transition to any E-1 series procedure or
Transition to any FRP Manually Actuate SI
2. Manually start at least one low head ECCS pump before transition out of E-0.
(WOG CT E-0 - - H)
3. Makeup to the RWST and minimize RWST outflow. (WOG CT ECA-1.1 - - B)
Begin makeup to the RWST using the makeup system in the manual mode per SOP-2.3 or Direct the TSC to begin evaluating alternate makeup methods, and
Establish the required number of CS pumps running in of ECP-1 .1 per step 10.2 table alignment SCENARIO Mode 3 with component and instrumentation failures, SBLOCA and LBLOCA, OBJECTIVE! failure of CTMT cooling and RHR systems, ECP-1 .1 entry required.
OVERVIEW:
The team should be able to:
recognize and respond to failures of various instruments and components per ARPs, AOP-6.0, AOP-27, AOP-1 00, AOP-9.0, AOP-1 6 & Tech Specs
identify a LBLOCA and initiate a manual SI,
recognize that the required Containment Cooling System components are not operating and start Ctmt coolers and I B RHR pump
and then enter ECP-1.1 when MOV-8811B is de-energized and IA RHR pump trips, then secure running CS pumps per the table in ECP-1 .1 and call to have RWST makeup aligned.
Target Quantitative Attributes (Per Scenario; See Section D.5.d) Actual Attributes
1. Total malfunctions (58) 9
2. Malfunctions after EOP entry (12) 3
3. Abnormal events (24) 6
4. Major transients (12) 1
5. EOP5 entered/requiring substantive actions (12) 1
6. EOP contingencies requiring substantive actions (02) 1
7. Critical tasks (23) 3 Farley June 2012 exam Page 15 of 15
Appendix D Operator Action Form ES.D-2 Op Test No.: FA2012301 Scenario # 6 Event # I Page 1 of 40 Event
Description:
Perform STP-11.I1, IA RHR Pump Operability Check STP-l 1.1 1 will be completed satisfactorily.
Indications Available:
none none Time Pos. Expected Actions/Behavior Comments
. Version 11.0 Initial conditions will be signed off as Sign-off 3.1 through 3.4 completed BOP (step 4.1) IF 1A RHR pump is NOT running, 1A RHR pump is started THEN start RHR PMP 1A (step 4.2) Verify that pump motor amps are stable and that discharge pressure has increased ACCEP TANCE CRITERIA: IA RHR pump can be manually stirted from the control room.
(step 4.3) Verify 1A RHR pump has indicated flow on QI El I FIS6O2A.
QIEIIFIS602A qpm ACCEPTANCE CRITERIA: IA RHR pump has indicated flow on QIEIIFIS6O2A.
(step 4.4) IF 1A RHR pump is NOT running 1A RHR pump is secured for cooldown requirements, THEN stop the 1A RHR PUMP.
When the IA RHR pump is secured and at the discretion of the Lead Examiner move to Event #2.
1
Appendix D Operator Action Form ESD-2 Op Test No.: FA2O1 2301 Scenario # 6 Event # 2 Page 2 of 40 Event
Description:
Initiate an entry into AOP-27 for emergency boration A phone call from the SSS will initiate this event; that an extra operator has performed a SDM lAW STP-29.1 and the result is positive. This requires emergency boration of 500 gallons.
Indications Available:
Annunciators: Recognize indications of AOP-27 entry
- NONE - Phone call Time Pos. Expected Actions/Behavior Comments version_16 RO (step 1) Start a BAT pump
[] 1A BAT pump handswitch turned to IA BAT pump will not start START
[1 lB BAT pump started RO (step 2) Align normal emergency boration flow path.
[j Open MOV 8104 RO RNO (step 2) Align manual emergency boration flow path BORIC ACID TO BLENDER
[1 Q1E21FCVII3A open MAN EMERG BORATION
[] Q1E21V185 open (100 ft, AUX BLDG rad-side chemical mixing tank area)
NOTE: F emergency boration is being aligned to the manual emergency boration flow path, THEN consideration should be given to starting a boration through the blender via FCV113A & B in accordance with SOP-2.3, CVCS REACTOR MAKEUP CONTROL SYSTEM, while personnel are beinq dispatched to locally open Q1E21V185.
RO (step 3) Verify one chg pump started RO (step 4) Establish adequate letdown
[] Verify 8149A and either 8149B or C open 2
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 2 Page 3 of 40 Event
Description:
Initiate an entry into AOP-27 for emergency boration Time Pos. Expected ActionsiBehavior Comments RD (step 5) Establish charging flow rate > 40 gpm (step 6) Verify boration flow> 30 gpm on Fl-113 RD (step 7) Secure ZAS Chemistry called Step 8 is N/A SRO (step 9) WHEN 500 gallons has been injected, THEN proceed to step 10 and secure the emeraencv boration.
(step 10) Stop running boric acid transfer oumo.
RNO step 11 Secure manual emergency boration flow path.
BORIC ACID TO BLENDER
[] QI E21 FCV1 I 3A closed MAN EMERG BORATION
[1 Q1E21V185 closed (step 12) Direct Chemistry to sample RCS for boron concentration using CCP 651, SAMPLING THE RCS (step 13) Verify reactor makeup control system aligned for auto makeup using SOP-2.3 (step 14) Check Shutdown Margin verified>
Technical Specification requirement When the emergency boration is in progress and at the discretion of the Lead Examiner move to Event #3.
3
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 3 Page 4 of 40 Event
Description:
AFW FCV-3227C fails open FCV-3227C will fail open. In this mode, SG level will be maintained using AFW. The crew will have to make a decision on control of AFW flow to the 1 C SG.
LCO 3.7.5 applies and evaluate the operability of the AFW system with one flowpath potentially inoperable.
Indications Available:
Annunciators: Indications of FCV-3227C failing open:
- 1A MDAFWP SUCT PRESS LO (JK1) - AFW flow to 1C SG (Fl-3229C) 4.
- AFW flow to 1A and lB SG (Fl-3229A and Fl-3229B) 4.
- Total AFW flow indicator Fl-3229 I
- AFW pump discharge pressure 4.
- AFW pump suction pressure 4.
- MDAFW flow indicator Fl-3402A I
- AFW pump amps slightly 4.
- FCV-3227C position indication GREEN lamp_extinguishes Time Pos. Expected ActionslBehavior Comments I
version_47.0 SRO Directs ARP Performance when alarm comes in:
- JK1, 1A MDAFWP SUCT PRESS LO BOP (step 1) Determine actual suction pressure Determines actual suction as indicated by P1-321 IA and the CST level. pressure by P1-321 IA is LOW
& CST level is adequate BOP (step 2) IF an actual low suction pressure condition exists, THEN stop 1A MDAFW Puma BOP (step 3) IF auxiliary feedwater flow is required AND condensate storage tank level is NOT low, THEN start Motor Driven Auxiliary Feedwater Pump lB OR the Turbine Driven Auxiliary Feedwater Pump.
BOP (step 4) Determine the cause of the alarm Determines FCV3227C is full open & wont go closed when demanded by potentiometer 4
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 3 Page 5 of 40 Event
Description:
AFW FCV-3227C fails open Time Pos. Expected Actions/Behavior Comments SRO Directs isolating MDAFW flow to 1 C SG by AOP-6.0 step 8.2 has actions one of the following methods: that could be used here as
- Closing BOP M0V3764C (B train) OR well. Starting and stopping the M0V3764F (A train) MDAFW pumps and/or
- Jacking closed locally HV3227C TDAFWP is allowed as well.
Isolating HV3227C locally with manual isolation valve
- closing vOl7F locally
- power up MOV-3350C and close the MOV BOP (step 5) IF the alarm is due to an improper valve lineup, THEN verify a correct valve lineup AND return the Auxiliary Feedwater System to operation.
SRO (step 7) Refer to Technical Specifications, sect 3.7.5 for LCO Requirements TS 3.7.5 Condition C for inoperable MDAFW Flowpath to IC SG (2 MD trains mop, to C SG.)
STP-22.8 says Performance of this procedure affects the operability of both MDAFW pumps briefly while MOV-3764A, B, C, D, E & F are stroked closed.
TECHNICAL SPECIFICATION 3.7.5, AFW System LCO 3.7.5 Three AFW trains shall be OPERABLE.
APPLICABILITY: MODES 1,2, and 3.
SRO CONDITION REQUIRED ACTION COMPLETIO N TIME C. Two AFW C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trains AND inoperable. C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SRO - Notify the Shift Manager
- Requests a CR be written & Work Week Coordinator notified of the failure
- Requests SSS write LCO 3.7.5, Condition C for inoperable MDAFW Flowpath to IC SG (2 MD trains mop, to 1C SG)
At the discretion of the Lead Examiner move to Event #4.
5
Appendix D Operator Action Form ES..D-2 Op Test No.: FA2012301 Scenario # 6 Event # 4 Page 6 of 40 Event
Description:
PK-444A, Pzr pressure controller, fails HIGH PK-444A will go to 100% demand, Sprays will close and all heaters will be demanded ON. Actual pressure will increase, but the sprays and PORV-444B will not respond. If manual control of individual components is not taken, PORV-445A will open. Manual control of PK-444A is not possible due to the failure.
Indications Available:
Annunciators: Recognize indications of PK-444A FAILING
- PRZR PRESS REL 445A OR B/U HTRS HIGH ON (HD1) - PK-444A demand
- All BU Htrs ON
- RCS pressure I Time Pos. Expected ActionslBehavior Comments
_I -.. 11, section 1.1 SRO Check RCS pressure stable or rising RCS pressure I Set control band for RCS pressure.
SRO SRO will direct entry to AOP-100.
RO (step 1) Verify RCS pressure is stable. NOTE: Step 1 and 2 are immediate operator action Take manual control of the PK-444A, PRZR steps PRESSURE REFERENCE CONTROLLER.
Due to the failure mode, the RO can NOT take manual control of PK-444A
. Take manual control of the spray valves
. Take manual control heaters Control PRZR pressure Steps 2 and 3 do not apply RO (step 4) IF an alarm was caused by a component failure, THEN perform the following as required to restore RCS pressure to desired value.
Take manual control of the following as Required:
. PORVs
. Heaters
. Spray valves 6
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 4 Page 7 of 40 Event
Description:
PK-444A, Pzr pressure controller, fails HIGH Time Pos. Expected ActionslBehavior Comments SteDs 5 and 6 do not apply SRO (steo 7) Inform the SM of the failure.
SRO (step 9) Submit a condition report on the failed component, and notify the Work Week Coordinator (Maintenance ATL on backshifts) of the condition report.
SRO (step 10) IF the pressurizer PORVs operated, THEN perform the following:
. Refer to SOP-i .2, REACTOR COOLANT PRESSURE RELIEF SYSTEM, for cooldown of the PRT
. Refer to SOP-0.0, General Instructions To Operations Personnel, for reporting reauirements.
When Pzr pressure is being controlled and at the discretion of the Lead Examiner move to Event #5.
7
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 6 Event # 5 Page 8 of 40 Event
Description:
ICCW pump trips on overload When the COW pump trips a leak will start in the CCW surge tank (Event 6). Level will be slowly decreasing and eventually the Surge tank low level alarm will alert the operator to this event. AOP-9 will be used to combat the tripped COW pump and the ARP will take care of the leak.
Indications Available:
Annunciators: Indications of a Tripped CCW pump and loss of
- IC COW PUMP OVERLOAD TRIP (AA3) CCW flow
- COW FLOW FROM RCP OIL CLRS LO - No flow on F13043CA (DD3) - Temoerature risina on runnina comoonents version 520 SRO Reference ARP AA3 and decide the standby COW pump did not auto start.
Direct entry into AOP-9 to get the 1 B COW oumo runnina.
BOP (step 1) Check 10 COW PUMP has tripped.
BOP (step 2) Check auto start of standby pump SRO (step 3) Perform the actions required by AOP-9.0, LOSS OF COW Version 23.0 BOP (step 1) Verify 00W pump started in affected train:
- handswitch for 1 B CCW pump taken to START 8
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 5 Page 9 of 40 Event
Description:
ICCW pump trips on overload Time Pos. Expected ActionslBehavior Comments ROI (step 2) Check CCW system adequate for BOP continued plant support.
- Check CCW flow adequate in affected train.
- Check RCP motor bearing temperatures less than 195°F.
- Check CCW pump not cavitating. Stop any cavitating CCW pump.
- CCW Surge tank level being maintained at or above 13 inches.
- RCP seal injection to all RCPs greater than 6 aom.
BOP (step 3) Verify SW flow supplied to the ON SERVICE train CCW HX SW DISCH
[1 Q1P16FI3009AA IA CCW HX DISC
[1 Q1 P1 6F13009BA I B CCW HX DISC
{] QIPI6FI3009CA 1C CCW HX DISC SRO (step 4) Check ON SERVICE train affected. Go to step 9 BOP (step 9) Check both RHR pumps stopped SRO (step 10) Inform the SM to evaluate event classification and notification requirements using EIP-8, NON-EMERGENCY NOTIFICATIONS AND EIP-9, EMERGENCY CLASSIFICATION AND ACTIONS BOP (step 11) Check SFP cooling aligned to an Go to procedure and step in operating CCW train effect (step 12) Check on service CCW train operating Return to ARP AA3 SRO (step 4) IF 1 B CCW Pump is aligned to A Train, THEN rack out I C CCW Pump supply breaker DFO4.
(step 5) Refer to Technical Specification 3.7.7 for LCO requirements with a loss of the on service train of component cooling water.
9
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 5 Page 10 of 40 Event
Description:
ICCW pump trips on overload Time Pos. Expected ActionslBehavior Comments SRO IF 1 B COW Pump is aligned to A Train, THEN rack out 1 C CCW Pump supply breaker DFO4.
- Notify Plant Personnel to determine and correct the cause of the fault.
Refer to Technical Specification 3.7.7 for LCO requirements Due to the loss of the IC COW pump and the I B CCW pump did not autostart, maintenance personnel will have to determine if the 1 B CCW pump is OPERABLE based on the autostart feature (SR 3.7.7.3). Until that time, the CCW system is INOPERABLE until the 10 COW pump is racked out and may be INOPERABLE when the results of troubleshooting are known.
Mandatory LCO until the IC COW pump is racked out and 3.7.7 condition A restore within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months is in effect.
TE r.HNICAL SPECIFICATION 3.7.7, CCW System LCO 3.7.7 Two CCW trains shall be OPERABLE APPLICABILIT:
, Y MODES 1,2, 3, and 4.
SRO CONDITION REQUIRED ACTION COMPLETION TIME A. One CCW A.1 NOTE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.6, RCS LoopsMODE 4, for residual heat removal loops made inoperable by CCW.
Restore CCW train to OPERABLE status Event #6 will start when the IC CCW pump trips. Go to event 6 for actions and return here for Tech Spec actions after event 6 10
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 6 Page 11 of 40 Event
Description:
CCW leak when the I B CCW pump starts 1A MSIV will close causing a Main Turbine trip, A Reactor trip will be required.
Indications Available:
Annunciators: Indications:
- BOP PANELS ALARM (BE5) - Ll-3027A and B decreasing rapidly
- BOP panel L and N (LH2 and NH2)
CCW SUMP NORTH AND SOUTH HI-HI
- COW SRG TK LVL A TRN and B TRN HI-LO (AA4 and AB4)
Pos. Expected Actions/Behavior Comments version 52.0 SRO Direct actions required by AA4 BOP (step 1) Check A Train CCW SURGE TANK level indication and determine whether level is HIGH or LOW.
SRO (step 2) Dispatch personnel to locate and 5 minutes after makeup has isolate the source of leakage. been initiated the leak will be secured and a phone call will come in from the ROVER (step 3) IF CCW Surge Tank level is LOW, THEN perform the following:
3.1.1 Notify Shift Chemist that the CCW surge tank is to be made up to.
3.1.2 Verify open CCW SRG TK VT valves:
(MCB)
Q1P175V3028A
Q1P17SV3O28B 3.1 .3 Monitor CCW surge tank level indications.
Ll-3027A
Ll-3027B (step 3.1.5/.6) OPEN MKUP TO COW FROM DW STOR TK MOV3O3OA to add makeup to A portion of COW surge tank.
OPEN MKUP TO CCW FROM DW STOR TK MOV3O3OB to add makeup to B iortion of CCW surqe tank.
11
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 6 Page 12 of 40 Event
Description:
CCW leak when the I B CCW pump starts Pos. Expected ActionslBehavior Comments (step 3.1.7) WHEN makeup addition is completed, THEN close appropriate valve(s).
- MKUP TO CCW FROM DW STOR TK MOV3O3OA.
- MKUP TO CCW FROM DW STOR TK MOV3O3OB.
When the leak is secured and the CCW makeup is secured, and at the discretion of the Lead Examiner, go to event 7.
12
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2O1 2301 Scenario # 6 Event # 7 Page 13 of 40 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 letdown to be secured and AOP-16 entered as shown below.
Indications Available:
Annunciators: Recognize indications of PK-145 failing:
- LTDN ORIF ISO VLV REL LINE TEMP HI - Letdown HX outlet pressure (P1-145)
(DE3) increases to 600 psig
- LTDN HX OUTLET PRESS HI (DE4) - Letdown flow (Fl-i 50) decreases to zero
- Letdown orifice isolation relief line to PRT temperature (TI-141) I
- LI-i 12/115, VCT level, Time Pos. Expected Actions/Behavior Comments version 51.0 SRO Direct entry into DE4.
RO (step 1) Monitor LTDN HX Outlet Flow (Fl 150) and LTDN HX Outlet Press (P1-145).
RO (step 2) Ensure proper orifice isolation valve selection.
RO (step 3) IL the high pressure is due to LP PK-145 placed in manual and LTDN PRESS PK-145 malfunction, THEN controlled manually.
place valve controller in manual and attempt to reduce the pressure.
RO (step 4) IF pressure can NOT be controlled manually with LP LTDN PK-i45, 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.
RO (step 6) Go to AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.
Entry into DE3 will reguire letdown to be See DE3 steps below secured and to AOP-16 entered 13
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 14 of 40 Event
Description:
PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close Time j Pos. Expected ActionstBehaviór Comments version 51.0 SRO Direct entry into DE3 If required RO (step 1) Monitor the LTDN ORIF ISO REL line to PRT Temperature (Tl-141) and LTDN HX Outlet Press (P1- l45.
RO (step 2) IF temperature continues to rise Letdown secured rapidly indicating a lifted relief valve, THEN close LTDN ORIF ISO 45 (60) GPM Qi E21 HV8149A, B AND C.
RO (step 3) If the high temperature is due to LP LTDN press PK-145 malfunctions, THEN place valve controller in manual and adiust as required.
RO (step 4) IF a ramp is in progress, THEN place turbine load on HOLD.
(step 5) Go to AOP-16.0, CVCS MALFUNCTION to address the loss of letdown flow.
If letdown is secured then AOP-16 guidance is below:
r d E-,, 17.0 RO (Step 1) Verify charging flow adequate to cool letdown.
RNO close all LTDN ORIF ISOs
Letdown flow is secured
[] Q1E21HV8149A
[] Q1E21HV8149B
[1 QIE2IHV8I49C RO (Step 2) Stop any load change in progress RO (Step 3) Monitor VCT level to ensure proper level is maintained 14
Appendix 0 Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 15 of 40 Event
Description:
PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close Time Pos. Expected Actions!Behavior Comments RO (Step 4) [CA] Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.
[] P1-121
[1 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
- LTDN HX OUTLET FLOW, Fl-ISO, NO FLOW INDICATED (Step 8.2) Minimize RCS makeup:
Manually close charging flow control:
CHG FLOW fl 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:
Check normal letdown malfunction(s) -
Yes PCV-145 is in manual CORRECTED control Restore letdown with the following stei,s:
15
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 16 of 40 Event
Description:
PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close Time Pos. Expected ActionslBehavior Comments RO (Step 9.2) Verify all letdown orifice isolation valves CLOSED
-
LTDN ORIF ISO 45 GPM
[] QIE2IHV8149A LTDN ORIF ISO 60 GPM
[j QIE2IHV8I49B
[j Q1E2IHV8I49C (Step 9.3) Place LP LTDN PRESS PK 145 on service:
[j Place controller in MANUAL
[j Adjust demand signal to 50% or less (Step 9.4) Place LTDN HX OUTLET TEMP TK 144 on service:
[] Place controller in AUTO
[1 Set to maintain temperature 90 to 115°F RO (Step 9.5) Verify VCT HI LVL DIVERT VLV LCV-1 1 5A alignment:
[] Position indicator VCT light LIT
-
[] Handswitch in AUTO -
RO (Step 9.6) Verify LTDN HI TEMP DIVERT VLV QIE21TCV143:
[] DEMIN light LIT-
[] Handswitch in AUTO (Step 97) IF necessary, THEN OPEN both LTDN LINE PENE RM ISOs from the PRIP.
[] QIE2IHV8175A
[] QIE2IHV8175B (Step 9.8 Verify LTDN LINE CTMT ISO Q1E21HV8152 OPEN -
(Step 9.9 Verify LTDN LINE ISO valves -
OPEN
[1 Q1E21LCV459
[1 QI E21 LCV46O 16
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 17 of 40 Event
Description:
PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close 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:
EJ 1 Orifice 18 gpm
-
OR E 2 Orifices 40 gpm
-
(Step 9.11) Establish approximately 60 gpm letdown flow by OPENING:
[1 QIE21HV8149B OR
[1 Q1E2IHV8I49C RO (Step 9.12) [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 9.13) Adjust LP LTDN PRESS PK 145 to maintain desired letdown pressure -
BETWEEN 260-450 PSIG RO (Step 9.13.1) Set controller between 4.3 and 7.5 (Step 9.13.2) Check letdown flow STABLE
(Step 9.13.3) Place PK 145 in AUTO (Step 9.13.4) Control Letdown pressure as desired (Step 9.14) Control LTDN HX OUTLET TEMP,TK 144 to maintain LTDN temp 90 to 115°F.
[] TI-Il 6 VCT TEMP
[] Tl-143 DIVERT LTDN HX TEMP
[] Tl-144 CCW LTDN HX TEMP (Step 9.15) Refer to SOP-2.I, 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
-
17
Appendix D Operator Action Form ES-D-2 Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 18 of 40 Event
Description:
PK-145 fails high in automatic, letdown pressure controller failure causes PCV-145 to close Time Pos. Expected ActionslBehavior Comments 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 letdown is restored and at the discretion of the Lead Examiner move to Event #8.
18
Op Test No.: FA2012301 Scenario # 6 Event # 8 Page 19 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and lB CTMT coolers do not shift to SLOW speed The Large Break LOCA will cause RCS pressure to decrease and Ctmt pressure to increase.
The safety injection will not automatically initiate, the lB RHR pump will not start and the A Train ctmt coolers will not shift to on in slow speed.
Indications Available:
Annunciators: Indications of LB LOCA Various and numerous - Pzr level
-
RCS pressure
- Radiation monitor (R-217/1 1/12)
- Ctmt pressure I Time I Po Expected ActionslBehavior omments.
I ,rev43 RO/ Immediate Operator actions of EEP-0 Immediate Action steps of BOP (step 1) Check reactor trip. EEP-0 Check all reactor trip breakers and reactor trip bypass breakers OPEN.
-
Check nuclear power FALLING.
-
Check rod bottom lights LIT. -
(step 2) Check turbine TRIPPED.
-
TSLB2 14-1 thru 4 lit NOTE: 3 DGs will be running (step 3) Check power to 4160 V ESF when the SI is initiated busses. manually.
4160 V ESF busses AT LEAST ONE
- OATC will check SW header ENERGIZED pressure, ctmt cooler flows and CCW Hx SW flows and SW A Train (F 41 60V bus) power available lights pump lights.
lit 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. CRITICAL TASK to initiate SI BOP Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[J ACTUATED status light lit
[1 MLB-1 1-1 lit
[j MLB-1 11-1 lit 19
Op Test No.: FA2012301 Scenario # 6 Event # 8 Page 20 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and I B CTMT coolers do not shift to SLOW speed Time Pos. Expected Actions/Behavior Comments SRO (step 5) Directs continuing into EEP-0 at step See Tab at end of scenario for
5. Attachment 2 and 4 actions.
Directs the BOP to perform One CRITICAL TASK is in Attachment 2 starting on Attachment 2. aae 34 below (step 6) Check containment pressure- HAS NOTE: [CA] step For a LB RO REMAINED LESS THAN 27 psig LOCA ctmt pressure will rise
>27 psici RO (step 6.1 RNO) Verify Phase B CTMT ISOL MLB-3 1-1 and 6-1 will be LIT
- ACTUATED
[] MLB-3 1-1 lit
[1 MLB-3 6-1 lit RO (step 6.2) Stop all RCPs. Secures ALL RCPs RCP fliA fiB
[] 1 C RO (step 6.3) Verify PHASE B CTMT ISO alignment. All MLB-3 lights will be LIT (step 6.3.1) Check All MLB-3 lights lit.
IF any MLB-3 light NOT lit, THEN verify PHASE B CTMT ISO using ATTACHMENT 5, PHASE B CONTAINMENT ISOLATION.
RO (step 6.4.1) Check containment spray flow in Both CS pumps will be running both trains greater than 0 gpm. and flow will be >0 gpm CS FLOW
[1 Fl 958A Ii Fl 958B RO (step 7) Announce Unit 1 reactor trip and safety injection.
20
Op Test No.: FA2012301 Scenario # 6 Event # 8 Page 21 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and lB CTMT coolers do not shift to SLOW speed Time Pos Expected ActionslBehavior Comments RO (step 8) Check AFW status.
Check secondary heat sink Available o Check total AFW flow> 395 gpm
[] Fl 3229A
[] Fl 3229B
[1 Fl 3229C o Total Flow Fl 3229 OR Check any SG NR level> 31% {48%}
WHEN all SO narrow range levels less than 31%{48%}, THEN maintain total AFW flow greater than 395 gpm.
WHEN at least two SG narrow range levels greater than 28% AND TDAFWP NOT required, THEN stop TDAFWP.
RO (step 8.4) WHEN SG narrow range level greater than 31 %{48%}, THEN maintain SG NOTE: [CA] step narrow range level 31%-65%{48%-65%}.
. Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[1 A TRN reset
[j B TRN reset MDAFWP TO 1NI B/IC SG B TRN
[1 FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO (step 9) Check RCS temperature.
IF any RCP running, THEN check RCS average temperature STABLE AT OR
-
APPROACHING 547°F.
TAVG 1A(1B,1C) RCS LOOP
[1 TI 412D
[1 TI 422D
[1 TI 432D 21
Op Test No.: FA2O1 2301 Scenario # 6 Event # 8 Page 22 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and lB CTMT coolers do not shift to SLOW speed Time Pos Expected ActionslBehavior 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
{]ATRN 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, AFWFLOWTO IA(IB,IC)SG
[] Fl 3229A
[1 Fl 3229B
[1 Fl 3229C AFW TOTAL FLOW
[1 Fl 3229 IF MSIVs are closed THEN proceed to step 9.1.8 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing NOTE: Will call TBSO to with RNO step 9.1.6. accomplish this task 22
Op Test No.: FA2O1 2301 Scenario # 6 Event # 8 Page 23 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and lB CTMT coolers do not shift to SLOW speed Time Pos Expected ActionslBehavior Comments RO (step 10) Check pressurizer PORVs and spray valves.
WHEN pressurizer pressure less than 2335 NOTE: [CAl step psig, THEN verify both PRZR PORVs closed.
Verify both PRZR PORVs indicate CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[1 PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT PRESS P1472
[] PRT LVL Ll-470
[1 PRT TEMP Tl-471 WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing. NOTE CA ste P 1A(1B) LOOP SPRAY VLV
[]PK444C
[]PK444D Check any PRZR PORV ISO OPEN -
RO (step 11) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16°F{45°F}
SUBCOOLED IN CETC MODE RO (step 12) Monitor charging pump miniflow NOTE: Based on RCS criteria, pressure, close miniflows <
Control charging pump miniflow valves 1300 psig.
based on RCS pressure.
1C(IA) LOOP RCS WR PRESS
[] P1 402A 11 P1 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.
[j Check no SG pressure FALLING IN AN
UNCONTROLLED MANNER OR LESS THAN 50 osio.
23
Op Test No.: FA2012301 Scenario # 6 Event # 8 Page 24 of 40 Event
Description:
Large Break LOCA, Auto SI fails to actuate, lB RHR pump does not start, IA and lB CTMT coolers do not shift to SLOW speed Time Pos. Expected ActionslBehavior Comments SRO (step 14) Check SGs not ruptured.
[] Check secondary radiation indication -
NORMAL.
{j Checks rad monitors R-15, 19, 23A and B, 1 5B and C, and 60 A, B, C, D
[] No SG level rising in an uncontrolled manner.
SRO (step 15) Check RCS intact. NOTE: Phase B Ctmt isolation Check containment radiation - signal will be in and transition
[] R-2 CTMT 155 ft to EEP-1 .0 required
[1 R-7 SEAL TABLE
[1 R-27A CTMT HIGH RANGE (BOP)
[1 R-27B CTMT HIGH RANGE (BOP)
Trncif in to EEP-I.O fl Check containment pressure LESS THAN 3 psig.
[1 Check containment ECCS sump level LESS THAN 0.4 ft.
Response to Imminent Pressurized Thermal Shock Conditions, rev 19 (step 1) Check RCS Pressure >435 psig RNO HERE IC(IA) LOOP RCS NR PRESS
[1 PI4O2B
[] P1403B (step 1 RNO) IF LHSI flow> 1500 gpm, then RETURN to EEP-I.O return to procedure and step in affect:
1A(1B) RHR HDR FLOW
[] F1605A fl FI6O5B 24
Op Test No.: FA2O1 2301 Scenario # 6 Event # 9 Page 25 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV4BIIB is de-energized
. Rev 30 MOV-8811B will be de-energized and FO page requirement to IA RHR pump will trip at 30 feet in the transition to ECP-1.1 or step RWST 14 of EEP-1.0- go to page 29 for ECP-1.1 RD (step 1) Check RCP criteria.
Check SUB COOLED MARGIN MONITOR RCPs will already be secured indication GREATER THAN 16°F{45°F}
-
SUBCOOLED IN CETC MODE.
BOP (step 2) Check SGs not faulted.
Check no SG pressure FALLING IN AN
UNCONTROLLED MANNER OR LESS THAN 50 psiq.
BOP (step 3) Check intact SG levels.
Check any intact SG narrow range level GREATER THAN 31%{48%}.
NOTE: [CA] step WHEN SG narrow range level greater than 31%{48%}, THEN maintain SG narrow range level 31 %-65%{48%-65%}.
Control MDAFWP flow.
MDAFWP FCV 3227 RESET
[] A TRN reset
[1 B TRN reset MDAFWP TO IA/lB/iC SG B TRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[1 RESET reset TDAFWP SPEED CONT
[1 SIC 3405 adiusted BOP (step 4) Check secondary radiation [] R-15 indication NORMAL.
-
[] 19 Checks rad monitors [] 23A and B
[] 15B and C, Ii 60A,BC,D 25
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 26 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized RO (step 5) Check pressurizer PORVs Check any PRZR PORV ISO power available NOTE: [CA] step WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.
[] Verify both PRZR PORVs CLOSED Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp Tl-463 Check PRT parameters STABLE or FALLING.
[1 PRT PRESS P1472
{] PRT LVL LI-470
[] PRT TEMP TI-471
[1 Check at least one PRZR PORV ISO -
OPEN SRO (step 6) Perform the following within I NOTE: These steps will be hour of start of event, passed off to the Shift
[] Close recirculation valve disconnects using Manager ATTACHMENT 1.
[] Establish 1A and 1 B post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.
[] Plot hydrogen concentration on FIGURE 1.
Check containment hydrogen concentration
[1 LESS THAN 3.5%.
Ii Less than 0.5%
26
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 27 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energ ized SRO (step 7) Evaluate SI termination criteria U Check SUB COOLED MARGIN MONITOR indication GREATER THAN 16F{45°F}
SUBCOOLED IN CETC MODE Check secondary heat sink available.
[1 >395 gpm AFW flow OR
[1 > 31%{48%} SGNR level
[1 Check RCS pressure STABLE OR
-
RISING
[] Check pressurizer level GREATER THAN 1 3%{43%}.
Continue to step 8 since a known LOCA exists RO (step 8) Check containment spray system. NOTE: [CA] step Check any CS PUMP STARTED.
-
Reset containment spray signals.
CS RESET
[]ATRN
[1 B TRN NOTE: [CA] step WHEN containment spray recirculation flow has been aligned for at least 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months , AND containment pressure is less than 16 psig, THEN stop both CS PUMPs.
RO (step 9) Check if LHSI Pumps should be NOTE: [CA] step stopped. RCS pressure will be < 435
- Check RCS pressure GREATER 9
psi THAN 275 psig{435 psig}
U PT-402 AND 403 (step 9.1.1 RNO) Establish CCW flow to RHR Hxs CCW TO IA(1B) RHR HX
[] Q1PI7MOV3185A open
[1 QIPI7MOV3185B open BOP (step 10) Check no SG pressure FALLING
-
IN AN UNCONTROLLED MANNER.
27
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 28 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV.8811B is de-energized RO (step 11) Check RCS pressure LB LOCA
[1 PT-402 AND 403 If oressure is risinci then return to steo 1.
Perform Attachment 4 to Verify 4160 V busses energized.
BOP (step 12) Attachment 4 Check DFO1 closed YES Verify DFO2 closed - YES Check DG15 closed - YES Verfiy DGO2 closed - YES Verify all RCP busses - ENERGIZED.
[1 1A4160V bus- YES
[]lB4l6OVbus- YES
[]lC4l6OVbus- YES Check 1E 4160V busENERGIZED-YES Check 1D 4160V bus- ENERGIZED-YES BOP (step 13) Check diesel generators. NOTE: [CA] step Monitor any loaded diesel generator for NOTE: Securing unloaded proper voltage, frequency and load. DGS will be accomplished by the extra operator or the BOP Secure any unloaded diesel generators using if time permits. This is FNP-0-SOP-38.0, DIESEL GENERATORS. generally not the case and the DGs will continue to run.
MOV-881 I B will be de-energized and FO page requirement to IA RHR pump will trip at 30 feet in the transition to ECP-1.1 or step RWST 14 of EEP-1.0 28
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 29 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized SRO (step 14) Begin evaluation of plant status. NOTE: This is Foldout page Verify cold leg recirculation capability - criteria as well AVAILABLE.
Train A equipment available:
fl IA RHR Pump IA RHR pump has tripped
[1 CTMT SUMP TO 1A RHR PUMP Qi Eli M0V881 1A
[1 CTMT SUMP TO iA RHR PUMP Qi E11MOV8812A
[1 1ARHRHXTOCHG PUMP SUCT Qi Eli MOV87O6A
[1 CCWTO1ARHRHX QI P1 7MOV31 85A OR Train B equipment available:
[JiB RHR Pump
[1 CTMT SUMP TO I B RHR PUMP MOV-88l 1 B has no power QIEIIMOV88IIB
[1 CTMT SUMP TO 1 B RHR PUMP Ql Eli MOV8812B
[] lB RHR HXTO CHG PUMP SUCT Ql Eli MOV87O6B
[1 CCWTO1BRHRHX Qi Fl 7MOV31 85B
-.
Rev 28 RO (step I) Verify ECCS pumps not affected by sump blockage.
[CA] Monitor ECCS pump suction conditions
- NO INDICATION OF CAVITATION SRO (step 2) [CA] WHEN emergency coolant recirculation capability is restored, THEN go to orocedure and steo in effect.
29
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 30 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized RO (step 3) Check cold leg recirculation equipment AVAILABLE.
-
Train A equipment available:
fl IA RHR Pump 1A RHR pump has tripped
[] CTMT SUMP TO 1A RHR PUMP Qi El 1 M0V881 IA
[] CTMT SUMP TO IA RHR PUMP Ql El 1 MOV881 2A
[] 1ARHRHXTOCHG PUMP SUCT Qi Eli M0V8706A
[] CCWTOIARHRHX Ql P1 7MOV3I 85A OR Train B equipment available:
[1 lB RHR Pump
[] CTMT SUMP TO I B RHR PUMP MOV 8811 B has no power Q1EIIMOV88IIB
[1 CTMTSUMPTO lB RHR PUMP Q1E1 1MOV8812B
[1 lB RHR HX TO CHG PUMP SUCT QI Eli M0V8706B
[1 CCWTO1BRHRHX QI P1 7M0V31 85B RO (step 4) Verify SI - RESET.
[] MLB-l 1-1 off (A TRN) 1] MLB-l 11-1 off (B TRN)
RO (step 5) Check PHASE B CTMT ISO -
RESET
[1 MLB-3 1-I not lit
[1 MLB-3 6-1 not lit (step 6) Verify containment spray signals RESET.
-
CS RESET
[]ATRN
[1 B TRN (step 7) Reset containment sump to RHR valve switches.
CTMT SUMP TO RHR PUMP RESET
[] A TRN
[j B TRN 30
Op Test No.; FA2012301 Scenario # 6 Event # 9 Page 31 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized (step 8) Verify containment fan cooler alignment.
8.1 Verify all available containment fan coolers -
STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED
[1 1A
[Ji B
[ji C U 1D (step 9) [CA] Check RWST level -
GREATER THAN 4.5 ft.
(step 10) Evaluate containment spray requirements.
Check containment spray pumps ALIGNED TO RWST.
RWST TO 1A(1B) CS PUMP
[1 Q1E13MOV88I7A open
[1 Q1E13MOV8817B open Determine number of CS pumps required based on the Table below.
RWST Ctmt FAN COOLERS RUNNING IN EMERGENCY CS PUMPS REQUIRED LEVEL PRESS MODE URE
>54 - 2 PSIG 27to 0,1 2 54 2,3 1 PSIG 4 0
>54 0 EEN PSIG 4.5 27to 1,2 AND 54 3,4 0 12.5 PSIG FEET <27 - 0 PSIG 31
Op Test No.: FA2012301 Scenario # 6 Event # 9 Page 32 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized (step 11) [CA] Check status of containment spray.
11.1 Check any containment spray pump -
STARTED.
CS PUMP
[]1A
[JiB CS FLOW
[JFI 958A
[JFI 9588 (step 11.2) Check containment sump level -
GREATER THAN 3.8 ft{4.2 ft}.
CTMT SUMP LVL
[ILl 3594A POST ACCIDENT CTMT WTR LVL
[I LR 3594B (STEP 11.3) [CA] Align containment spray for recirculation mode.
11.3.1 Open cs pump lAand 18 Containment sump suction isolation valves.
CTMT SUMP TO 1A(1 B) CS PUMP
[I Q1E13M0V8826A
[I Q1E13M0V8826B
[]Q1E13MOV8827A
[]Q1E13M0V8827B 11.3.2 Close CS pump 1 A and 18 RWST suction isolation valves.
RWST TO IA(1B) CS PUMP
[]Q1E13MOV8817A
[]Q1E13MOV8817B (step 12) Makeup to the RWST as CRITICAL TASK to call for necessary. RWST makeup 12.1 Makeup to the RWST lAW SOP-2.3, OR CVCS REACTOR MAKEUP CONTROL direct RWST makeup per SYSTEM. SOP-2.3 OR 12.2 Consult TSC staff to determine alternate method of makeup to the RWST.
32
Op Test No.: FA2012301 Scenario # 6 Event# 9 Page 33 of 40 Event
Description:
IA RHR pump trips when RWST level reaches 30 feet and MOV-8811B is de-energized (step 13) Monitor CST level.
13.1 [CA] Check CST level greater than 5.3 ft.
CST LVL
[j LI 4132A
[j LI 4132B 13.2 Align makeup to the CST from water treatment plant OR demin water system using SOP-5.0, DEMINERALIZED MAKEUP WATER SYSTEM, as necessary.
When RWST makeup Critical Task step has been impiemented, then the Radside SO will call the control room and FV-B5 will have been reset and power restored to MOV-881 I B.
Per Step 2 of ECP-1 .1 Transition to EEP-1 .0 will be required to complete the scenario, step 14.2 below:
continued here SRO (step 14.2) Direct extra operator to begin taking ECCS logs.
SRO (step 14.2) Evaluate RCS sampling Notifies SM requirements.
Consult TSC staff to evaluate need for RCS sampling.
IF RCS sample required, THEN direct Chemistry to sample RCS using FNP-0-CCP-1 300, CHEMISTRY AND ENVIRONMENTAL ACTIVITIES DURING A RADIOLOGICAL ACCIDENT SRO (step 14.4) Check no intersystem LOCA [] R-3 RADIOCHEMISTRY BOP outside CTMT. LAB
[1 Check auxiliary building radiation - [] R-4 IC CHG PUMP RM NORMAL. [] R-5 SFP RM
[1 R-6 SAMPLE RM AREA
[] R-8 DRUMMING STATION
[] R-10 PRF
[1 R-17A OR R-17B CCW When the decision to transfer back to EEP-1 .0 announced, then terminate the exam.
33
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 34 of 40 Event
Description:
Attachment 2 of EEP-O Cue: BOP will accomplish when at step 5 of EEP-O Attachment 2 of EEP-O AUTOMATIC ACTIONS VERIFICATION Tinie, Pos; Exnctéd Actiórn/Behavior Comments (Step 1) Verify one CHG PUMP in each train STARTED.
-
BOP flAtrain(lAorlB)amps>0 Fl B train (1 C or 1 B) amos> 0 BOP (Step 2) Verify RHR PUMPs STARTED.
- CRITICAL TASK after IA RHR PUMP RHR pump trips at 30 feet fllAamps>0 RWSTIeve(
fl 18 amps> 0 BOP (Step 3) Verify Safety Injection Flow.
(Step 3.1) Check HHSI flow GREATER
-
THAN 0 gpm.
Fl Fl 943 BOP (Step 3.2) Check RCS pressure - LESS THAN 275 psig{435 psig}.
BOP (step 3.3) Check LHSI flow greater than
1.5 XlO gpm 3
1] 1A RHR HDR FLOW Fl-605A Fl lB RHR HDR FLOW Fl-605B BOP (Step 4) Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (1A,1B or 1C)
Ii B train (iDlE or 1C) 34
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 35 of 40 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (Step 5) Verify each train of CCW -
STARTED.
(Step 5.1) Verify one CCW PUMP in each train- STARTED.
A train HX 10 or 1 B COW FLOW U Fl 3043CA> 0 gpm OR
[1 Fl 3043BA> 0 gpm B train HX 1A or lB CCW FLOW
[] Fl 3043AA> 0 gpm OR
[1 Fl 3043BA> 0 gpm Verify SW flow to associated COW HXs SW FROM 1A(1B, 10) COW HX U Q1P16FI3009AA> 0 gpm U Q1P16FI3009BA> 0 gpm
[1 Q1P16FI3009CA> 0 gpm (Step 5.3) Check instrument air available.
Verify at least one air compressor started.
AIR COMPRESSOR U 1A U lB
[110 Check INST AIR PRESS P1 4004B greater than 85 psig.
35
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 36 of 40 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 6) Verify containment ventilation isolation.
Verify containment purge dampers -
CLOSED.
[1 3197
[1 3198D
[] 31980
[] 3196
[] 3198A
[1 3198B Verify containment mini purge dampers -
CLOSED.
CTMT PURGE DMPRS MINI-2866C & 28670 FULL-3198A& 3198D
[j 28660
[1 28670 CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 31980
[] 2866D
[j 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP BOP (step 7) Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train STARTED IN SLOW SPEED.
-
CTMT CLR FAN SLOW SPEED A train
[1 IA Ctmt cooling fans IA and lB
[j lB will not be in correct alignment.
B train
[j IC
[1 ID Verify associated emergency service water outlet valves OPEN.
-
EMERG SW FROM 1A(1B,1C,1D) CTMT CLR
[] QIPI6MOV3O24A
[] QIPI6MOV3O24B
[] QIPI6MOV3O24C
[] Q1PI6MOV3O24D 36
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 37 of 40 Event
Description:
Attachment 2 of EEP-O Time Pos., Expected ActionslBehavior Comments SOP (step 8) Verify AFW Pumps STARTED.
-
Verify both MDAFW Pumps STARTED-fl 1A MDAFW Pump amps> 0 fl lB MDAFW Pump amps >0 AND U Fl-3229A indicates> 0 gpm
[j FI-3229B indicates > 0 gpm
{j FI-3229C indicates > 0 gpm (Step 8.2) Check TDAFW Pump start required.
E Condition CTSLB C Setooint C CoincidenceLl RCP Bus TSLB2 1-1 [2680 V 1/2 Detectors Undervoltaae 1-2 1-3 on 2/3 Busses Low Low SG TSLB4 28% 2/3 Detectors Water Level 4-14-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 2/3 SGs 6-1,6-2,6-3 SOP (step 8.3) Verify TDAFWP started.
[1 MLB-4 1-3 lit U MLB-4 2-3 lit
[1 MLB-4 3-3 lit TDAFWP SPEED fl SI 3411A> 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
Verify TDAFW flow path to each SO.
TDAFWP TO 1A(IB,1C) SO
[1 Q1N23HV3228A in MOD fl Q1N23HV3228B in MOD
[1 Q1N23HV3228C in MOD TDAFWPTO 1A(1B,1C)SG FLOW CONT
[1 HIC 3228AA open
[j HIC 3228BA open U HIC 3228CA open 37
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 38 of 40 Event
Description:
Attachment 2 of EEP-O Time Pos. Expected ActionslBehavior Comments BOP (step 9) Verify main feedwater status.
Verify main feedwater flow control and bypass valves CLOSED.
-
1A(1B,1C) SG FW FLOW
[1 FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs TRIPPED.
-
Verify SG blowdown ISOLATED.
-
IA(1B,1C) SGBD ISO fl Q1G24HV7614A closed
[] Q1G24HV7614B closed
[1 Q1G24HV7614C closed 9.4 Verify SG blowdown sample -
ISOLATED MLB lights lit.
1A(1B,1C) SGBD SAMPLE STEAM GEN ISO
[1 MLB1 1 9-2 lit Q1 P1 5HV3328 closed
[j MLB1 19-3 lit Q1P15HV3329 closed
[1 MLB1 19-4 lit Q1P15HV3330 closed BOP (Step 10) Check no MSL isolation actuation signal present.
SiQnaI Setpoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow >40% % on 2/3 TSLB4 16-3,4 and and 17-3,4 18-3,4 Lo-LoTavg <543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press >16.2 psig 2/3 TSLBI 2-2,3,4 (Step 11) Verify PHASE A CTMT ISO. RNO (Step 11.1) Verify PHASE A CTMT ISO - Step 11.2 Verify PHASE A ACTUATED. CTMT ISO alignment using BOP fl MLB-2 1-1 lit ATTACH 3, PHASE A CTMT fl MLB-2 11-1 lit ISO 1 1.2 Check all MLB-2 lights LIT.
-
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 trio bvoass breaker B 38
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 39 of 40 Event
Description:
Attachment 2 of EEP-0 Time Pos. Expected ActionslBehavior Comments BOP (step 13) Trip CRDM MG set supply breakers.
1A(1B) MG SET SUPP BKR U N1C11EOO5A
[1 NICI1EOO5B BOP (step 14) Secure secondary components.
Stop both heater drain pumps.
HDP
[j 1A
[1 1 B Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
[] IA
[] lB If NO condensate pumps are started then place all HSs to STOP 14.3 IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per FNP-0-SOP-0.0, APPENDIX B, Will call TBSO to TB SO Actions Following A Reactor Trip Or accomplish this.
Safety Injection.
BOP (step 15) Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[jATRAIN
[] B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP (step 16) WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KV BKR U 810- OPEN fl 914- OPEN BOP (step 17) Verify two trains of ECCS equipment aligned.
Perform ATTACHMENT 4, Two Train ECCS Alignment Verification.
End of Attachment 2 39
Op Test No.: FA2012301 Scenario # 6 Event # 7 Page 40 of 40 Event
Description:
Attachment 4 of EEPO Time Pos. I Expected ActionslBehavior I Comments Attachment 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION (Step 1) Verify two trains of ECCS equipment aligned.
U Check DFO1 closed U Verify DFO2 closed U Check DG15 closed
[} Verfiy DGO2 closed
[1 Verify two trains of battery chargers energized Amps > 0 (Step 1.6) Verify two trains of ESF equipment aligned.
[] Check all MLB-1 lights LIT Verify charging pump suction and discharge valves OPEN.
-
CHG PUMP DISCH HDR ISO
[] QIE21MOV8132A
[] Q1E21MOV8132B
[] Q1E21MOV8I33A
[] Q1E21MOV8133B CHG PUMP SUCTION HDR ISO U QIE2IMOV813OA
[1 Q1E21MOV813OB
[] Q1E21MOV8131A U Q1E21MOV8131B (Step 1 .7) Verify all post accident containment air mixing system fans STARTED. (BOP)
-
POST ACCIDENT MIXING FAN
[] 1A
[] 18
[] 1 C
[1 1 D RX CAV H2 DILUTION FAN U 1A U lB (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 40
Appendix D Crew Briefing sheet Form ES-D-2 Op-Test No.: FA2012-301 Page 1 of 2 Brief This simulator performance scenario is performed in the EVALUATION MODE. You should not direct questions to the evaluators. Otherwise, you should perform as if you were in the MCR.
Your ability to maintain a log is not being graded, but maintaining a rough log is recommended to help during briefs.
If you need to communicate with the Unit 2 operator, verbally state, Unit 2 and an instructor will locate to the Unit 2 area and respond to you as quickly as possible.
In the unlikely event that the simulator fails such that illogical indications result, the session will be terminated. In other words, respond to what you see. If there is a problem with the simulation, the session will be terminated or adjusted as appropriate based on the specific problem.
Assign ojerating positions.
Ask for and answer questions.
Appendix D Turnover sheet Form ES-D-2 J_X]Unitl [ ]Unit2 Shift: Date I Off-going SS Oncoming SS I [ ] N [ X] D I Today Part I To be reviewed by the oncoming Supervisor prior to assuming the shift.
Security Keys A, 5, D, SW, X on key ring. 55 Unit Mode 3, MOL, 893 ppm boron, Shutdown banks are pulled, Xe decreasing from its peak Status following the reactor trip. The reactor tripped 21 hours2.430556e-4 days 0.00583 hours 3.472222e-5 weeks 7.9905e-6 months ago as a result of the loss of both SGFPs.
STPslEvolutions: A Train On-Service A Train STP-1 1.11 Protected 1 0_; 109.1 Noadi.; 63.7_; FSP-20,0 Status of Special Testing Perform STP-11.11, IA RHR Pump Operability Check immediately upon taking the shift.
General Information
1. Reactor Startup planned in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , ECC being calculated by Reactor Engineering
2. Currently in UOP-1.3, v69, step 5.17 3 Current Risk Assessment is and projected is GREEN
4. Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
5.
6.
7.
8.
9.
Equipment Status Maintain VCT gas pressure 25-30 psig Reactivity Plan Waste Manager ent Status
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 Ill: STP-1 .0 Operator Logs Cond. Report Autolog ELDS & GEN Keys Reviewed/Signed Reviewed Queue Reviewed Spreadsheet Turned Reviewed verified Over
[X]Yes [X]Yes [X]Yes [X]Yes [X]Yes [X]Yes

ML12214A335: Difference between revisions

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