ML091480172
| ML091480172 | |
| Person / Time | |
|---|---|
| Site: | Farley  |
| Issue date: | 05/28/2009 |
| From: | NRC/RGN-II |
| To: | Southern Nuclear Operating Co |
| References | |
| FA2008301 | |
| Download: ML091480172 (165) | |
Text
Scenario #2 2008 NRC exam Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario HLT-32 NRC EXAM SCENARIO #2 FA2008301 Technical Review:
GTOhmstede Date:
07-2008 Training Department Approval:
NRC approved Date:
10-2008 COMPANY Energy to Serve Your World'"
AppendixD Scenario 2 Form ES-D-I
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Facility: I Farley Nuclear Plant I
Scenario No.:
2 Op-Test No.:
2008-301 Examiners:
Operators:
SRO RO BOP Initial Conditions: 74% power, ramping down to MODE 3 due to Hurricane warnings in effect. Winds in excess of75 mph expected at the plant site in 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />. 1138 ppm, MOL; B train on service, B Train protected Turnover:
1B EHC pump T/O for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
I&C is working on PT -455 which failed low last shift.
- L T -115 failed low - I&C working on it. Auto make up is in manual control.
- AOP-21, Severe Weather, is in effect due to Hurricane and high winds in the area.
Current Risk Assessment is and projected is I B Train On-Service - B Train Protected.
Event Mal£No.
Event Type*
Event Description No.
1 R(RO&
Ramp at 5 MW Imin BOP) 2 I (BOP)
PT-508, Feedwater header pressure, fails high.
3 C(RO)
HV-8175A fails closed. Letdown relief opens.
Restore letdown or place excess letdown on service.
5 C (ROIBOP) 1 C inverter fails and does not automatically transfer to the bypass TS(SRO) source.
6 C(RO)
Two rods drop into the core during ramp. The team should enter and perform the actions of AOP-19 for a dropped rod and trip the reactor.
7 M(ALL)
LOSP for BOTH units upon reactor trip -spurious SI due to PT-455 failed low 8
C (BOP) 1A CCW pump trips on start, 1B CCW pump will not auto start M(ALL)
When ESP-1.1 entered and SI flow secured then:
9 1A S/G develops a large steamline break inside CTMT needing a SI.
C (BOP) 1B CS pump does not auto start and MOV 8820A does not open.
10 FRP-Z.I orange path entry required with the conditions given if the 1B CS pump is NOT started from the MCB prior to FRP-Z.1 entry.
Selected Ctmt coolers do not auto start.
C (BOP) 1B MSIVs do not auto close. BOP will have to manually close one 11 MSIV.
(N)ormal, (R)eactlVlty, (I)nstrument, (C)omponent, (M)aJor Farley Oct 2008 exam Scen 2 Page 2 of 12
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Appendix D Scenario 2 detailed summary sheet Form ES-D-1 Initial Conditions: 74% power, MOL, 10,000 MWD, B Train 0/5, B Train protected, RCS boron concentration is 1138 ppm, and Xe worth is -501 pcm. (IC-57)
Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event 7 Event 8 Event 9 Event 10 Event 11 1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
I&C is working on PT-455 which failed low last shift.
L T -115 failed low - I&C working on it. Auto make up is in manual control.
AOP-21, Severe Weather, is in effect due to Hurricane warning and high winds in the area.
Current Risk Assessment is and projected is
- J!. Train On-Service - B Train Protected.
Ramp down in power at 5 MW/min to be off line in 2.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> PT-508 fails high. Take manual control of the SGFP speed.
8175A fails closed. Letdown relief opens. Will have to reduce charging and seal injection. AOP-16 and Tech Spec 3.4.13 c. Condition A.
Place Normal letdown back in service or excess letdown on service.
1 C inverter fails and does not automatically transfer to the bypass source. The control room will have the Rover transfer to the bypass manually.
LCV-115B and D will open and borate the RCS. A faster ramp will be required until the inverter is swapped.
TWO bank 'B' rods drop into the core during ramp. The team should enter and perform the actions of AOP-19 for 2 dropped rods and Trip the reactor.
Dual unit LOSP. 1-2A and 1 B DGs auto start to restore power.
A spurious 51 occurs.
1A CCW pump trips on auto start. Will have to manually start 1 B CCW pump (CT)
When SI flow has been secured and ESP-1.1 entered (step 6), the following event occurs:
1 A SG develops a large steam line break inside ctmt.
1 B CS pump does not start and MOV 8820A does not open.
Transition will have to be made to EEP-2 (FRP-Z.1) to isolate the faulted SG (CT) The selected ctmt cooler (1 D) does not auto start in slow speed and 1 B trips when the Steam fault comes in (10 psig in ctmt).
FRP-Z.1 may be entered since the 1 B CS pump does not start and MOV8820A does not open. 1 B CS pump may be started at any time and MOV8820A opened (CT) and if done prior to FRP-Z.1 entry, then Z.1 does NOT have to be entered.
The 1 B MSIVs do not auto close on any auto signal. 1 B MSIV manual isolation is required (CT)
Terminate the scenario when ESP-1.1 entered for the second time.
Farley Oet 2008 exam Seen 2 Page 10 of 12
Appendix D Scenario 2 detailed summary sheet Form ES-D-1
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CRITICAL TASK SHEET
- 1.
Manually start the 1 B CCW pump before the 1C and/or 1 B chg pump trips on high LO temp. (WOG CT E-O - - K)
- 2.
Start the 1 B CS pump or open MOV-8820A after Containment pressure is/has been> 27 psig, and prior to a Red Path on FRP-Z.1 (54 psig). (WOG CT E-O - - E)
- 3.
Isolate the 1A SG (Feed flow and steam flow) and isolate the 1 B SG steam flow (WOG CT E - A)
SCENARIO OBJECTIVEI OVERVIEW:
Ramp in progress. Auto make up will not work.
The team should be able to:
Respond to a failed equipment and instruments and complete the appropriate ARPs, AOP-100, AOP-16 & Tech Specs Identify a spurious SI and then respond to a faulted SG inside ctmt, reinitiate SI flow, recognize that 1 C CCW pump tripped and start the 1 B CCW pump as required per EEP-O. Then transition properly to ESP-1.1, FRP-l.1 (maybe) and EEP-2, then back to ESP-1.1.
Farley Oet 2008 exam Seen 2 Page 11 of 12
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AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 1 Page 1 of30 Event
Description:
Ramp at 5 MW/min lAW UOP-3.1 Cue: Start of exam.
Time Position Applicant's Action or Behavior Crew is expected to begin the ramp when shift is relieved and get to 5 MW Imin per shift turnover sheet. UOP-3.1, version 96.0, section 8.3.
SRO Will direct ramp started lAW UOP-3.1, section 8.3.
SROIRO 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. For planned load reductions Engineering Support should provide a ramp strategy to maintain axial flux difference within the limits of COLR figure 3.
RO 8.5 Attempt to maintain the axial flux difference within +/- 5% from the target value by making adjustments in rod height and/or boron concentration as necessary. Refer to section 7.1 as necessary for guidance.
BOP Verify DEH is set up for a ramp down and the white HOLD light is LIT.
Press the GO button and ensure the light comes on and the Main Turbine starts to ramp down.
RO Verify rods are in AUTO or Manual and maintaining Tavg close to Tref.
When 5 MW ramp complete go to next event End Event #1
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 2 Page 2 of30 Event
Description:
PT-508, Feedwater header pressure, fails high Cue: B, Examiner Time Position Al plicant's Action or Behavior Annunciators:
Recognize indications ofPT-508 failure 0
lA,lB,OR lC SG LVL DEV (JFl, SGFP speed decreasing JF2, JF3 )
FR V s opening 0
lA, lB,OR 1 C SG LO L VL (JA 1, JA2, -
SGWL NR decreasing JA3)
Feed flows derease to zero 0
FEED FLOW (JBl, JB2, JB3)
In this event PT-508 fails high. SGFP speed will decrease and the FRVs will start to go full open.
AOP-lOO section 1.4 will be entered Immediate ol!erator action BOP Check that steam and feed flows matched on all SGs 0
Take manual control of SK-509A and decrease SGFP speed 0
Possibly take manual control of all FRVs Check no required automatic actions required or set points being SRO approached If any are approached then Trip the reactor and go to REACTOR TRIP OR SAFETY INJECTION BOP 0
Place the Main Turbine on HOLD 0
Adjust SGFP speed back to within the normal operating range for the feed flow/steam flow ~P required for the existing power level Unit 1 NO LOAD ~P is 50 psid from 0-28.1 %. PROGRAM ~P is linear from 50-190 psid from 28.1 % to 100%. TABLE-l provides approximate ~P values for varying power levels.
BOP Approximate ~P can be determined from the following MCB indications 0
SGFP DISCH PRESS PI4003 0
SG Pressure indications At this power level DP should be approx. 130 psid SRO Call Shift Manager and Submit a condition report on the failed instrument, and notify the Work Week Coordinator (Maintenance A TL on backshifts) of the condition report SRO Brief crew on the manual control of the SGFP and then re-commence the ramp and continue ramping off line.
End Event #2
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 3/4 Page 3 of30 Event
Description:
HV-817SA fails closed. Letdown relief opens. Letdown is secured and then restored.
Cue: By Examiner Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of LETDOWN RELIEF L TDN ORlF ISO VL V REL LINE TEMP LIFTING HI (DE3)
TI -141 is rising and indicating 250°F VCT L VL HI-LO (DF3)
PRT parameters are rising Letdown flow and pressure decreases to zero VCT level starts to decrease Auto makeup starts and eventually the VCT low level alarm comes in if no action is taken When HV8175A closes, the relief valve opens and water goes to the PRT. The ARP instructs the crew to secure letdown.
BOP Recognize, announce and reference the ARPs.
SRO 0
Direct the crew to isolate letdown and place the main turbine on HOLD 0
Direct the crew to enter AOP-16.0 NOTE:
Transients that will require boration or dilution should be avoided if letdown has been secured.
Excess letdown may be placed on service anytime it is desired during the performance of this procedure in accordance with FNP-1-S0P-2.7, CHEMICAL AND VOLUME CONTROL SYSTEM EXCESS LETDOWN RO Monitor VCT level to ensure proper level is maintained.
RO Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.
PI-121 AMMETER FOR RUNNING CHG PUMP RO Check charging pump - RUNNING YES RO Check Charging flow FK-122 controlling in YES
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 3/4 Page 4 of30 Event
Description:
HV-8175A fails closed. Letdown relief opens. Letdown is secured and then restored.
AUTO with flow indicated RO Check DE3 clear NO RO Check PRT parameters - STABLE should be rising PRT PRESS PI 472 PRT LVL LI-470 PRT TEMP TI-471 SRO Determine Status of Normal Letdown Check normal CVCS letdown - AFFECTED BY MALFUNCTION YES 0
LTDN HX OUTLET FLOW, FI-ISO - NO FLOW INDICATED 0
Minimize RCS makeup 0
Manually close charging flow control 0
Minimize seal injection between 6-13 gpm 0
Direct Chemistry to shutdown the zinc addition system (ZAS) 0 Dispatch personnel to investigate cause of the Letdown malfunction 0
Tech Spec - RCS leakage until isolated 3.4.13 c. > 10 gpm identified leakage Condition A - Reduce leakage to within limits in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> SRO IF desired due to plant conditions, THEN place excess letdown in service using FNP-I-S0P-2.7, CHEMICAL AND VOLUME CONTROL SYSTEM EXCESS LETDOWN SRO Determine if normal letdown should be re-established:
Check normal letdown malfunction(s) - CORRECTED BOOTH Phone call from radside SO that a facilities person is standing here with a cart that bumped the handswitch and closed 8175A RO 0
Verify all letdown orifice isolation valves - CLOSED
- HV8149A, Band C 0
Place PCV-14S in Manual and SO% demand 0
Place TK-144 in AUTO and set to 3.3 to maintain temp at approx. 100°F.
0 Verify LCV-IISA is aligned
- VCT light LIT
- Handswitch in - AUTO 0
IF necessary, THEN OPEN both L TDN LINE PENE RM ISO's from the Penetration Room Isolation Panel
- Call Radside SO to open 817 S A and B
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AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 3/4 Page 5 of30 Event
Description:
HV-8175A fails closed. Letdown relief opens. Letdown is secured and then restored.
0 Verify 8152 is open 0
Verify LCV-459 and 460 open 0
Initiate minimum charging flow by verifying FK-122 in manual and open to approx 40 gpm 0
Establish Letdown flow of approx 60 gpm by opening 8149B ORC 0
Adjust PK-145 to a setting between 4.3 and 7.5 to obtain approx.
260 - 450 psig 0
Verify letdown flow stable and place PK-145 in AUTO 0
Control LTDN HX OUTLET TEMP TK 144 to maintain Letdown temperature at approximately 100°F 0
- TI-116 VCT TEMP 0
TI-143 DIVERTLTDNHXTEMP 0
TI-144 CCW L TDN HX TEMP SRO Determine ifletdown flow from either Normal YES Letdown or Excess letdown exists.
Direct going to procedure and step in effect.
SRO Call Shift Manager and Submit a condition report on the failed component (8175A), and notify the Work Week Coordinator (Maintenance A TL on backshifts) of the condition report.
END - Event 3 and 4
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 5 Page 6 of30 Event
Description:
1 C inverter fails and the inverter does not auto swap Cue: By Examiner Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of INVERTER lC INY FAULT (VDl)
FAILURE SSPS A TRN TRBL (EC4)
Loss of power to NI-43 with associated PROC CAB PWR FAILURE (EC 1) alarms, bistable trip status lights and RCP BUS UV SINGLE INPUT ALERT indication (EF4)
Loss of power to the inverter (amps on RCP BUS UF SINGLE INPUT ALERT EPB = 0)
(EFS)
There are many other annunciators and bistables that come in to alarm (FCl, FCS, FD3, FD4, FAl)
When the 1 C Inverter fails, the bypass source to load does not transfer automatically.
NOTE In addition to items listed under Automatic Action, the following controls and indications are affected if 1 C Vital Panel is De-energized.
PRZR PORV - QIB31PCV44SA will not open on high przr pressure signal.
RWST TO CHG PUMP - Q1E21LCVl1SB and D will open ifLT lIS is inoperable.
Annunciator KG4, TURB TV closed alert, will be in alarm and TSLB2, 14-3 will be lit Annunciator KHS, TURB Auto/Stop oil press low, will be in alarm and TSLB2, 13-3 will be lit.
RO Recognize loss of inverter from alarms and loss ofNIs Respond to alarms and recognize loss of inverter from loss of Nis and no BOP amperage on 1 C Inverter.
SRO Direct actions of VD 1 Assess plant and analyze IF a reactor trip is called for NO BOP Call ROVER to Attempt to restore power from the bypass source by performing the following:
IF the "BYPASS SOURCE A V AILABLE" lamp is illuminated on the inverter, THEN transfer lC INVERTER MANUAL BYPASS SWITCH to the "BYPASS SOURCE TO LOAD" position
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 5 Page 7 of30 Event
Description:
1 C inverter fails and the inverter does not auto swap RO 0
LCV -115B and D will roll open 0
Efforts should be made to continue the ramp in progress or start a ramp to keep up with the loss of Tavg due to the boration in progress.
BOP Commence or continue the ramp RO When the inverter is powered back up:
Verify that VCT OUTLET ISO valves - QIE21LCVl15C and E are open and can remain open.
Verify that RWST TO CRG PUMP valves - QIE21LCVl15B and D are closed.
Verify PRZR PORV - QIB31PCV445A is closed.
BOP Reset the positive rate trip on NI-43 and verify proper operation on NI-43.
SRO Refer to TECH SPECs 3.8.7 and 3.8.9 mandatory LCO 3.8.7 Condition A applies while the inverter is supplied from the bypass source and not connected to the battery. 24 hour2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> mandatory LCO 3.8.9 Condition B applies for the time the vital panel was de-energized.
8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> mandatory LCO to restore the vital panel to operable status End event 5
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 6 Page 8 of30 Event
Description:
TWO bank B rods drop into the core during ramp Cue: By Examiner Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of DROPPED ROD ROD AT BOTTOM (FE3)
NIs decreasing PR CH DEV (FCS) -later RCS pressure dropping COMP ALARM ROD SEQIDEV OR PR RCS Tavg decreasing FLUX TILT (FFS)
Rod bottom light on DRPI PR UPPER! LOWER DET HI FLUX DEV Rods stepping out ifin AUTO OR AUTO DEF (FB4) (FBS)
Two Bank B rods drop and RCS temperature and pressure fall as well as power level decreases.
AOP-19 will be entered to deal with the problem SRO Directs entering AOP-19 and BOP looking at ARPs Verity NO load change in progress stop the ramp in progress BOP Place the ramp on HOLD.
SRO Check for unexplained rod motion NO (ifrods are in AUTO then the SRO may direct rods be placed in manual)
RO Rod motion may be occurring due to the dropped rod. The RO should stop the rod motion ifin AUTO SRO Check that no dropped rod(s) exist(s) in Mode 1 YES RO 0
Should report there are two dropped rods SRO 0
Direct Tripping the reactor and performing the IOAs ofEEP-O END-Event 6
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AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 9 of30 Event
Description:
LOSP for BOTH units -spurious 81 due to PT-455 failed low 1A CCW pump trips on start, 1 B CCW pump will not auto start Cue: Linked to opening the Reactor trip breakers Time Position Annunciators:
Many and various s Action or Behavior Recognize indications of Spurious SI No SI signal in alarm or degrading plant conditions Przr level increasing with all ECCS pumps running MLB-l-l and 11-1 LIT When a loss of power occurs, an automatic SI will occur due to PT-455 failed low. The crew will enter EEP-O Immediate operator actions. The reactor will trip due to the loss of both CRDM MG sets.
RO/BOP Immediate Operator actions ofEEP-O Check reactor trip.
SRO Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED 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 SWpump.
Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-l 1-1 lit
[] MLB-l 11-1 lit YES
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Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 10 of30 Event
Description:
L08P for BOTH units -spurious 81 due to PT-455 failed low 1A CCW pump trips on start, 1 B CCW pump will not auto start Directs the BOP to do attachment 2.
BOP Completes Attachment 2 and 4 See Tab at end of scenario Attachment 2 and 4 for actions rCA] Check containment pressure-HAS RO REMAINED LESS THAN 27 psig RO Announce "Unit 1 reactor trip and safety injection".
Check secondary heat sink Available 0
Check total AFW flow> 395 gpm
[] FI3229A
[] FI 3229B
[]FI3229C 0
Total Flow FI 3229 OR Check any SG NR level> 31 % {48%}
WHEN all SG narrow range levels less than 31 %{ 48%},
THEN maintain total AFW flow greater than 395 gpm.
WHEN at least two SG narrow range levels greater than 28%
AND TDAFWP NOT required, THEN stop TDAFWP.
rCA] WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
Control MDAFWP flow.
MDAFWP FCY 3227 RESET
[] A TRN reset
[] B TRN reset MDAFWP TO 1AIlB/1C SG BTRN
[] FCY 3227 in MOD 8.4.2 Control TDAFWP flow.
TDAFWP FCY 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO Check RCS temperature.
YES IF any RCP running, THEN check RCS average temperature - STABLE A T OR APPROACHING 547°F.
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Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 11 of30 Event
Description:
LOSP for BOTH units -spurious SI due to PT-455 failed low 1A CCW pump trips on start, 1 B CCW pump will not auto start TAVG lA(1B,lC) RCS LOOP
[] TI 412D
[] TI 422D
[] TI 432D RO RNO IF RCS temperature less than 547°F and falling, THEN perform the following.
Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET Verify atmospheric reliefs closed on MCB Demand at 0 and minimum red light LIT Control total AFW flow to minimize RCS cooldown, AFW FLOW TO lA(1B,lC) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFWTOTAL FLOW
[] FI 3229 Isolate steam loads in the turbine building while continuing with RNO Will call TBSO to accomplish this task RO Check pressurizer PORVs and spray valves.
[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-47 1
[CA] WHEN pressurizer pressure less than 2260 psig, THEN verify normal pressurizer spray valves closed OR in the process of closing.
[] PK 444C
[] PK 444D
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 12 of30 Event
Description:
LOSP for BOTH units -spurious SI due to PT-455 failed low 1 A CCW pump trips on start, 1 B CCW pump will not auto start Check any PRZR PORV ISO - OPEN RO Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F {45°F} SUB COOLED IN CETC MODE.
RO Monitor charging pump miniflow criteria.
Control charging pump mini flow valves based on RCS pressure.
[] PI 402A
[] PI 403A Based on RCS pressure, close miniflows < 1300 and open when> 100 psig.
Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
0 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
0 Check secondary radiation indication - NORMAL.
Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D 0
No SG level rising in an uncontrolled manner.
Check containment radiation - NORMAL.
[] R-2 CTMT 155 ft
[] R-7 SEAL TABLE
[] R-27 A CTMT HIGH RANGE (BOP)
[] R-27B CTMT HIGH RANGE (BOP)
D Check containment pressure - LESS THAN 3 psig.
D Check containment ECCS sump level - LESS THAN 0.4 ft.
Radiation levels will be elevated in ctmt and ctmt pressure will be < 3 psig and sump level is pre-event.
SRO Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 16°F SUBCOOLED IN CETC MODE. YES 0
Check secondary heat sink available.
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 13 of30 Event
Description:
LOSP for 80TH units -spurious SI due to PT-455 failed low 1A CCW pump trips on start, 18 CCW pump will not auto start
>395 gpm AFW flow
> 31 % SGNR level (a1212rox 40% -validation) 0 Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13 %
[] MLB-l 1-1 not lit (A TRN)
[] MLB-l 11-1 not lit (B TRN)
RO Stop all but one CHG PUMP.
RO Verify ReS pressure - STABLE OR RISING 1C(IA) LOOP RCS WR PRESS
[] PI402A
[] PI 403A RO Isolate HHSI flow.
Verify charging pump miniflow valves - OPEN.
1A(lB, 1 C) CHG PUMP MINIFLOW ISO
[] QIE21MOV8109A
[] QIE21MOV8109B
[] QIE21MOV8109C CHG PUMP MINIFLOW ISO
[] QIE21MOV8106 Close HHSI isolation valves.
[] QIE21MOV8803A
[] QIE21MOV8803B Establish normal charging.
Manually close charging flow control valve.
CHGFLOW
[] FK 122 Verify charging flow path aligned.
Verify charging pump discharge flow path - ALIGNED.
[] QIE21MOV8132A open
[] QIE21MOV8132B open
[] QIE21MOV8133A open
[] QIE21MOV8133B open CHG PUMPS TO REGENERATIVE HX
[] QIE21MOV8107 open YES YES Rising
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 7/8 Page 14 of30 Event
Description:
LOSP for BOTH units -spurious SI due to PT-455 failed low 1A CCW pump trips on start, 1 B CCW pump will not auto start
[] QIE2IMOV8108 open Verify only one charging line valve - OPEN.
RCS NORMAL CHG LINE
[] QIE2IHV8I46 RCS AL T CHG LINE
[] QIE2IHV8I47 NOTE: The RCS may be approaching solid plant conditions. In the event the RCS must be operated water solid, charging flow should be adjusted to maintain subcooling instead of pressurizer level.
The RCS should not be water solid but if it is the note here almlies (am2rox 51 % validation)
[CA] Control charging flow to maintain pressurizer level 25%-50%
using FK -122 FK-I22 should be taken to the fully closed position so there is no charging pump flow SRO Go to ESP-l.1, SI TERMINATION, step 6.
Adjust charging flow to maintain pressurizer level 25%-50%
ll\\I'?"-'Y)~... ;;li; after ESP-J.I entered and both RHR pumps are secured.
End of event 7/8
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 15 of30 Event
Description:
Faulted SO inside ctmt, IB CS pump will not auto start and MOV-8820A will not open Cue: ESP-1.1 step 6 Time Position Applicant's Action or Behavior Annunciators:
Various and many Recognize indications of LARGE FEED BREAK INSIDE CTMT Fire alarm (MHI)
Hi ctmt pressure (EEl) (EE2) (EE3)
Ctmt pressure rising Przr level decreasing SG pressures decreasing Depoints in ctmt rising Ctmt cooler drains increasing ESP-1.l step 7 below BOP 7 Secure LHSI system.
7.1 RHR pumps - ANY RUNNING WITH SUCTION ALIGNED TO RWST.
7.2 Stop any RHR Pumps running with suction aligned to the RWST.
7.3 Check on service train RHR pump - STOPPED.
7.4 Isolate CCW to the on service train RHR heat exchanger.
[] QIPl7MOV3185A closed OR
[] QIP17MOV3185B closed SRO Verify 51 flow not required.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F} SUBCOOLED IN CETC MODE.
Check pressurizer level GREATER THAN 13%{43%}.
Perform the following.
Establish HHSI flow using ATTACHMENT 3, RE-ESTABLISHING HHSI FLOW Go to EEP-1, LOSS OF REACTOR OR SECONDARY COOLANT.
Team The team should notice ctmt pressure rising, Pzrz level dropping and RCS pressure dropping and refer to the foldout page to make the transition or use step 8 above to transition to EEP-l after SI re-initiation is in progress. (both are similar to the above step)
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 16 of30 Event
Description:
Faulted SG inside ctmt, IB CS pump will not auto start and MOV-8820A will not open Information to examiner:
Step 8 says to verify SI flow not required. If this step is used for the event in progress, the team could Establish HHSI flow using ATTACHMENT 3, RE-ESTABLISHING HHSI FLOW and then transition to EEP-1. EEP-1 will Check SGs not faulted at step 2 and then transition the team to EEP-2.
Also ESP-O.O could be used here if the team was unsure of the best procedure flowpath.
Transition to EEP-2 would be directed by ESP-O.O.
The team could also go straight to EEP-2, and then establish SI flow when EEP-l.O entered due to low pressurizer level.
At this point in the scenario the 1B CS pump does not start and MOV-8820A did not open when Ctmt pressure rises to 27 psig HI-3. Transition to FRP-Z.l would be required unless either the IB CS is started or MOV-8820A is opened.
Actions for EEP-2 below followed by FRP-Z.l
.iI!.IIII~..
tI'2.,.II
... *.. II.I. to start the 1 B CS pump or open MOV-8820A ATTACHMENT 3 RE-ESTABLISHING HHSI FLOW RO Align charging pump suction to RWST.
RWST TO CHG PUMP
[] Q1 E21 LCV115B open
[] Q1 E21 LCV1150 open CHG PUMP SUCTION HOR ISO
[] Q1 E21 MOV8130A open
[] Q1E21MOV8130B open
[] Q1E21MOV8131Aopen
[] Q1 E21 MOV8131 B open VCT OUTLET ISO
[] Q1E21LCV115C closed
[] Q1 E21 LCV115E closed Verify charging pump miniflow valves - OPEN.
1A(1B,1C) CHG PUMP MINIFLOW ISO
[] Q1E21MOV8109A
[] Q1E21 MOV8109B
[] Q1E21 MOV8109C CHG PUMP MINIFLOW ISO
[] Q1E21MOV8106 Isolate normal letdown and charging.
L TON ORIF ISO 45 GPM
[] Q1E21HV8149A closed L TON ORIF ISO 60 GPM
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 17 of30 Event
Description:
Faulted SO inside ctmt, IB CS pump will not auto start and MOV-8820A will not open
[] 01 E21 HV8149B closed
[] 01 E21 HV8149C closed LTDN LINE CTMT ISO
[] 01 E21 HV8152 closed Manually close charging flow control valve.
CHG FLOW
[] FK 122 Verify charging flow path aligned.
[] 01 E21 MOV8132A open
[] 01 E21 MOV8132B open
[] 01 E21 MOV8133A open
[] 01 E21 MOV8133B open CHG PUMPS TO REGENERATIVE HX
[] 01 E21 MOV81 07 closed
[] 01 E21 MOV81 08 closed Open HHSI isolation valves.
[] 01 E21 MOV8803A
[] 01 E21 MOV8803B Start additional CHG PUMPs as required.
Monitor charging pump miniflow criteria.
Control charging pump miniflow valves based on RCS pressure.
[] PI402A
[] PI403A SRO Direct transition to EEP-2 or FRP-Z.l EEP-2 below and FRP-Z.l on page 20 BOP qtiti~alt~
Verify all main steam isolation and bypass valves - CLOSED.
Place handswitches for all MSIVs to the CLOSED position (6 total)
SRO Check if any SG not faulted.
2.1 Check pressure in at least one SG - STABLE OR RISING.
Only lA SG will be blowing down once the MSIVs are closed Identity the faulted SG lASG
(
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 18 of30 Event
Description:
Faulted SG inside ctmt, IB CS pump will not auto start and MOV-8820A will not open BOP Isolate all faulted SGs.
o Verify ALL ARVs closed - PC3371A, B, C minimum demand o
Verify ALL Feed stop valves closed MOV3232A, B, C o
Verify blowdown from all faulted SGs - ISOLATED.
HV7614A o
Isolate TDAFWP steam supply from 1B SG.
The TDAFW pump should not be required.
This will be called to the booth to be completed by the extra operator
\\
4.5.1 IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from 1B SG at HSD panel.
[] Q1N12HV3235A/26 in LOCAL (HSDP-F)
[] Q1N12HV3235A/26 to STOP (HSDP-D)
BOP 4.6 Verify SG blowdown sample ISOLATED MLB lights lit.
[] MLBI 19-2 lit Q1P15HV3328 closed
[] MLBI 19-3 lit Q1P15HV3329 closed
[] MLBI 19-4 lit QIP15HV3330 closed Isolate AFW flow to all faulted SGs.
Close MDAFWP isolation valves to all faulted SGs. (BOP)
Closes MOV3764A and E on the BOP RO Close TDAFWP flow control valves to all faulted SGs.
TDAFWP FCV 3228
[] RESET reset Close HV3228A pot to 0 Have ROVER close QIN23V017A key Z-139 SRO Call to SSS-P or TSC to have QIN23V017A closed in the MSVR BOP Check CST level 19I;;Utl;;l than 5.3 feet
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 19 of30 Event
Description:
Faulted SG inside ctmt, IB CS pump will not auto start and MOV-8820A will not open Check secondary radiation indication - NORMAL.
YES Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D SRO Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 16°F{45°F} SUBCOOLED IN CETC MODE.
0 Check secondary heat sink available.
>395 gpm AFW flow
> 31 %{ 48%} SGNR level 0
Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13%{43%}.
Enter EEP-I or ESP-I.l depending on SI termination criteria RO 0
VerifY PHASE A CTMT ISO - ACTUATED.
[] MLB-2 1-1 lit
[] MLB-2 11-1 lit
- Check all MLB-2 lights - LIT.
0 VerifY containment ventilation isolation.
0 VerifY all containment purge dampers - CLOSED.
0 Verify containment mini purge dampers - CLOSED.
0 Stop MINI PURGE SUPP/EXH FAN.
~';;'i{£)I_;;L;
[CAl Check if containment spray is required.
0 Containment pressure - HAS RISEN TO GREATER THAN 27 psig.
0 VerifY PHASE B CTMT ISO - ACTUATED.
[] MLB-3 1-1 lit
[] MLB-3 6-1 lit 0
Verify containment spray pumps - RUNNING NO 0
Check containment spray flow in both trains - GREATER
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 20 of30 Event
Description:
Faulted SO inside ctmt, IB CS pump will not auto start and MOV-8820A will not open THAN 0 gpm.
NO CSFLOW
[] FI 958A
[] Fl958B BOP Check all MLB-3 lights - LIT.
[]lA
[JIB
[]IC BOP Verify containment fan cooler alignment.
Verify all available containment fan coolers - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED
[]lA
[] IB - TRIPPED
[]IC
[] ID - DID NOT START Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM lAO B, 1 C, 1 D) CTMT CLR
[] QIP16MOV3024A
[] QIP16MOV3024B
[] QIP16MOV3024C
[] QIP16MOV3024D BOP Ctiticat'task Verify main steam line isolation and bypass valves - CLOSED.
BOP 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.
MOV3232A SRO Evaluation - IF all SGs faulted THEN maintain 20 gpm AFW flow to each SG.
NO
AppendixD Reguired Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 21 of30 Event
Description:
Faulted SO inside ctmt, IB CS pump will not auto start and MOV-8820A will not open BOP Isolate AFW flow to all faulted SGs.
Close MDAFWP isolation valves to all faulted SGs. (BOP)
Closes MOV3764A and E on the BOP RO Close TDAFWP flow control valves to all faulted SGs.
TDAFWP FCV 3228
[] RESET reset Close HV3228A pot to 0 SRO Call to SSS-P or TSC to have QIN23V017A closed in the MSVR If EEP-l is entered these actions will be performed.
NOTE to examiner: FRP-P.l may come in on an ORANGE path due to the steam break. If this were to occur2 then the scenario should be secured when the appropriate transition is made.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F} SUBCOOLED INCETC MODE.
YES BOP Check SGs not faulted.
2.1 Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
YES BOP 3 Check intact SG levels.
3.1 Check any intact SG narrow range level-YES GREATER THAN 31 %{ 48%}.
[CAl WHEN SG narrow range level greater than 31%{48%},
THEN maintain SG narrow range level 31%-65%{48%-65%}.
Control MDAFWP flow.
[] A TRN reset
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 22 of30 Event
Description:
Faulted sa inside ctmt, IB CS pump will not auto start and MOV-8820A will not open
[] B TRN reset MDAFWP TO 1A/lBIlC SG BTRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted BOP Check secondary radiation indication - NORMAL.
Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D RO Check pressurizer PORVs Check any PRZR PORV ISO - power available
[CAl 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 FALLING.
[] PRT LVL LI-470
[] PRT TEMP TJ-471 Check at least one PRZR PORV ISO - OPEN SRO The following will be passed off to the Shift Manager Perform the following within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of start of event.
0 Close recirculation valve disconnects using A TT ACHMENT 1.
0 Establish 1A and lB post LOCA containment hydrogen analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.
0 Plot hydrogen concentration on FIGURE 1.
0 Check containment hydrogen concentration - LESS THAN 3.5%.
0 Less than 0.5%
SRO Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 23 of30 Event
Description:
Faulted SG inside ctmt, IB CS pump will not auto start and MOV-8820A will not open GREATER THAN 16F {45F} SUBCOOLED IN CETC MODE.
0 Check secondary heat sink available.
>395 gpm AFW flow
> 31 %{ 48%} SGNR level 0
Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13%{ 43%}.
If SI termination criteria is met then go to ESP-t.l IF NOT~ then continue in ~rocedure RO
[CA] Check containment spray system.
8.1 Check any CS PUMP - STARTED.
NO RO 9 [CAl Check ifLRSI Pumps should be stopped.
Check RCS pressure - GREATER THAN 275 psig{ 435 psig}
YES PT -402 AND 403 Check RCS pressure - STABLE OR RISING YES Verify the SI reset Secure any running RHR pumps Take HS to stop SRO Evaluation point -
Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER.
Check RCS pressure on PT-402/403.
This differentiates between a steam break and an RCS leak SRO should direct the team to return to step 1 of EEP-l until SI termination criteria is met.
When SI termination criteria is met then go to ESP-t.l RO Verify SI reset.
[] MLB-l 1-1 not lit (A TRN)
[] MLB-l 11-1 not lit (B TRN)
RO Verify RCS pressure - STABLE OR RISING Rising lC(1A) LOOP RCS WR PRESS
[] PI 402A
[] PI 403A
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9/10/11 Page 24 of30 Event
Description:
Faulted SG inside ctmt, IB CS pump will not auto start and MOV-8820A will not open RO Isolate HHSI flow.
Check CHG PUMP - SUCTION ALIGNED TO RWST QIE21LCV115B open QIE21LCV115D open Verify charging pump miniflow valves - OPEN.
lA(lB,lC) CHG PUMP MINIFLOW ISO
[] QIE21MOV8109A
[] QIE21MOV8109B
[] QIE21MOV8109C CHG PUMP MINIFLOW ISO
[] QIE21MOV8106 20.2 Close HHSI isolation valves.
[] QIE21MOV8803A
[] QIE21MOV8803B Establish normal charging.
21.1 Manually close charging flow control valve.
CHGFLOW
[] FK 122 21.2 Verify charging flow path aligned.
21.2.1 Verify charging pump discharge flow path - ALIGNED.
[] QIE21MOV8132A open
[] QIE21MOV8132B open
[] QIE21MOV8133A open
[] QIE21MOV8133B open CHG PUMPS TO REGENERATIVE HX
[] QIE21MOV8107 open
[] QIE21MOV8108 open 21.2.2 Verify only one charging line valve - OPEN.
RCS NORMAL CHG LINE
[] QIE21HV8146 RCS ALT CHG LINE
[] QIE21HV8147 END OF SCENARIO
AppendixD Required Operator Actions Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Event
Description:
Attachment 2 and 4 of EEP-O Cue: BOP will accomplish when at step S ofEEP-O Time Position licant's Action or Behavior of EEP-O AUTOMATIC ACTIONS VERIFICATION Form ES-D-2 Page2S of30 Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (lA,lB or IC)
BOP Verify each train of eew - STARTED.
Verify one CCW PUMP in each train-STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX IA or lB CCWFLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SWFROM IA(IB, IC) CCWHX
[] QIPI6FI3009AA > 0 gpm
[] QIPI6FI3009BA > 0 gpm
[] QIPI6FI3009CA > 0 gpm Verify one eHG PUMP in each train - STARTED.
[] A train (IA or IB) amps> 0
[] B train (IC or lB) amps> 0 BOP Verify RHR PUMPs - STARTED.
RHRPUMP
[] IA amps> 0
[] lB amps> 0 NO YES
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Page 26 of30 Event
Description:
Attachment 2 and 4 ofEEP-O BOP Verify Safety Injection Flow.
Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943 BOP Check RCS pressure - LESS THAN 5.2 Proceed to Step 6.
275 psig{435 psig}.
BOP Verify containment ventilation isolation.
Verity containment purge dampers - CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B Verify containment mini purge dampers - CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3 196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN. Will place HS to STOP BOP Verify containment fan cooler alignment.
Verity at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED o A train
[]lA
[]IB DB train
[]IC
[]ID Verity associated emergency service water outlet valves -
OPEN.
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Page 27 of30 Event
Description:
Attachment 2 and 4 ofEEP-O EMERG SW FROM lA(lB,IC,ID) CTMT CLR
[] QIP16MOV3024A
[] QIP16MOV3024B
[] QIP16MOV3024C
[] QIP16MOV3024D BOP Verify AFW Pumps - STARTED.
Verify both MDAFW Pumps - STARTED
[] lA MDAFW Pump amps> 0
[] lB MDAFW Pump amps> 0 AND
[] FI-3229A indicates> 0 gpm
[] FI-3229B indicates> 0 gpm
[] FI-3229C indicates> 0 gpm Check TDAFW Pump start required.
o Condition o TSLB OSetQoint o Coincidence 0 RCPBus TSLB21-1 02680 V 112 Detectors Undervoltage 1-21-3 on 2/3 Busses LowLowSG 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 Verify TDAFWP started.
[] MLB-4 1-3 lit
[] 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 lA(lB,lC) SG
[] QIN23HV3228A in MOD
[] QIN23HV3228B in MOD
[] QIN23HV3228C in MOD TDAFWP TO lA(lB,IC) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Page 28 of30 Event
Description:
Attachment 2 and 4 of EEP-O BOP Verify main feedwater status.
Verify main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs - TRIPPED.
Verify SG blowdown - ISOLATED.
[] QIG24HV7614A closed
[] QIG24HV7614B closed
[] QIG24HV7614C closed Verify SG blowdown sample - ISOLATED MLB lights lit.
lA(lB,IC) SGBD SAMPLE STEAM GEN ISO
[] MLBI 19-2 lit QIP15HV3328 closed
[] MLBI 19-3 lit QIP15HV3329 closed
[] MLBI 19-4 lit QIP15HV3330 closed BOP Check no main steam line isolation actuation signal present.
Signal Setooint LO SG PRESS < 585 psig Hi stm flow and Lo-Lo Tavg
>40%
and
<543°F coincidence 2/3
~ on 2/3 2/3 HI-HI ctmt press> 16.2 psig 2/3 IF MSLI present then shut MSIVs BOP Verify PHASE A CTMT ISO.
Verify PHASE A CTMT ISO - ACTUATED.
[] MLB-2 1-1 lit
[] MLB-2 11-1 lit Check all MLB-2lights - LIT.
TSLB TSLB4 19-2,3,4 TSLB4 16-3,4 17-3,418-3,4 TSLB2 10-1,2,3 TSLB 1 2-2,3,4 BOP Check all reactor trip and Perform the following.
reactor trip bypass breakers - OPEN. Open reactor trip breaker(s) manually from MCB or locally.
Reactor trip breaker A Record any breaker(s) Reactor trip breaker B manually opened.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Page 29 of30 Event
Description:
Attachment 2 and 4 ofEEP-O Reactor trip bypass breaker A Reactor trip bypass breaker B BOP Trip CRDM MG set supply breakers.
lA(lB) MG SET SUPP BKR
[] NICIIE005A
[] NICIIE005B BOP Secure secondary components.
Stop both heater drain pumps.
HDP
[]1A
[]IB Check any condensate pump started.
IF started, THEN stop all but one condensate pump.
[]1A
[]1B If NO condensate pumps are started then place all HSs to STOP IF condensate pump operating, THEN verify backup cooling aligned to condensate pumps per SOP-O.O, APPENDIX B, TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.
Will call TBSO to accomplish this.
BOP 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 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KVBKR
[] 810 - OPEN
[] 914 - OPEN BOP Verify two trains of ECCS equipment aligned.
Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICA TION.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 2 Event No.: 9 Page 30 of30 Event
Description:
Attachment 2 and 4 ofEEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION BOP Verify two trains of ECCS equipment aligned.
Check DFO 1 closed Verify DF02 closed Check DG 15 closed Verfiy DG02 closed Verify two trains of battery chargers - energized Amps> 0 Verify two trains of ESF equipment aligned.
Check all MLB-l lights LIT Verify charging pump suction and discharge valves - OPEN.
[J QIE21MOV8132A
[J QIE21MOV8132B
[J QIE21MOV8133A
[J QIE21MOV8133B CHG PUMP SUCTION HDR ISO
[J QIE21MOV8130A
[] QIE21MOV8130B
[J QIE21MOV8131A
[J QIE21MOV8131B Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[]IA
[JIB
[]IC
[]1D RX CAY H2 DILUTION FAN
[]1A
[JIB WHEN power restored to any deenergized emergency bus, THEN verify alignment of associated equipment.
BOP Call Radside SO to Verify Spent Fuel Pool Cooling in service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
Verify SFP cooling in service End of Attachment 2 and 4
Scenario #3 2008 NRC exam Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario HLT-32 NRC EXAM SCENARIO #3 FA2008301 Technical Review:
GTOhmstede Date:
07-2008 Training Department Approval:
NRC approved Date:
10-2008 Energy to SertJ(? Your WOrld'"
AppendixD Scenario #3 Outline FOnTI ES-D-l Facility:
I Farley Nuclear Plant 1 1 Scenario No.: J 3
I Op-Test No.: I 2008-301 Examiners:
Operators:
SRO RO BOP Initial Conditions: 4% power, UOP-1.2, v89, completed thru step step 5.55. Ready to perform step 5.56.
524 ppm, EOL; A train on service, A Train protected.
1 A SGFP on service. Aux steam from U-2. Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) lA CW pump only O/S.
Turnover:
IB EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
FRV bypasses controlling feedwater to the SGs Current Risk Assessment is and projected is A Train On-Service - A Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event Malf. No.
Event Type*
Event Description No.
R Ramp up to 12% power and get ready to roll the turbine to 1800 rpm 1
(ROIBOP) 2 C (BOP)
The GSSC EXH fan trips to start this event.
Loss of Vacuum 3
I (RO)
LT-459 fails high slowly. LCO 3.3.1 TS (SRO)
C(RO) 1 C charging pump high lube oil temperature. Will have to be secured 4
TS (SRO) and lA or 1B Chg pump started lAW AOP-16.
LCO 3.5.2, 13.1.5.
5 I (BOP) lA SGFP controller failure. SGFP will run up to 5500 rpm until control of SGFP is regained.
6 R(RO) lA SGFP Trips - ramp down to <2% power and get on AFW lAW SRO AOP-13 7
M(ALL) lA SGTR 300 gpm ramped in over 5 minutes 8
C(RO)
Block auto SI. Block manual and auto Rx trip. Crew must open CRDM MG set breakers to trip the reactor.
9 C (BOP) 1 A atmospheric fails open lO C (BOP)
FCV-3227A lA AFW FCV fails open (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Farley Oct 2008 exam Scen 3 Page 2 of 13
Appendix D Scenario 3 detailed summary sheet Form ES-D-1 Initial Conditions: 4% power, EOL, 15,000 MWD, A Train OIS, A Train protected, RCS boron concentration is 524 ppm. 1A SGFP on service. Aux steam from U-2.
Only partial of 2 sets of cooling tower fans will be on service. (i.e. half of the A, B,C towers) 1A CW pump only ols Turnover:
1B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
Current Risk Assessment is **
and projected is FRV bypasses controlling feedwater to the SGs A Train On-Service - Ii Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Event 2 Event 3 Event 4 Increase Reactor power to 12% and get ready to roll the Main Turbine.
The GSSC EXH fan trips to start this event. ARP will be entered.
Loss of Vacuum will occur due to this failure -call to start ALL Ct fans, Start 1B CW pump and the other GSSC EXH fan from the MCB. -AOP-8 Regain vacuum by restarting the other GSSC EXH fan L T -459 fails high slowly. AOP-lOO will be entered to control pressurizer level. Charging flow will decrease and it is possible at this low power to have letdown isolate. A OP-I 00 will restore letdown and control charging. Tech Spec entry 3.3.1 IC charging pump high lube oil temperature. Will have to be secured and IA or IB Chg pump started. TS entry mandatory until the IB chg pump is swapped to the other train.
LCO 3.5.2, 13.1.5.
The 1 C Chg pump will be tripped iftemperature is allowed to reach 170°F.
Event 5 IA SGFP controller failure. SGFP will run up to 5500 rpm until control of SGFP is regained. Since the FRV Bypass valves are being used to control Feed flow, this will be a different response. AOP-lOO entry. Possible trip of the IA SGFP if control not taken and this will lead to event 6. Ramp down will not be initiated if this happens.
Event 6 IA SGFP Trips - ramp down to <2% power and get on AFW lAW AOP-13 Event 7 IA SGTR 300 gpm ramped in over 5 minutes with the AUTO SI and AUTO & manual trip blocked.
Event 8 Actuate a manual Rx trip by opening CRDM MG set breakers (CT) and initiate a manual SI (CT)
Event 9 IA atmospheric fails open when SI occurs.
Event 10 FCV-3227A IA AFW FCV fails open after 6.667 minutes after the SI occurs. Isolate SGs (CT) 1 C chg pump will auto start on the SI. If allowed to run and increase temperature to 170°F, then IC chg pump will be tripped. Not critical task since one chg pump will be running.
Farley Oct 2008 exam Scen 3 Page 10 of 13
Appendix D Scenario 3 detailed summary sheet CRITICAL TASK SHEET Form ES-D-1
- 1.
Actuate a manual Rx trip prior to SI (WOG CT E-O - - A)
- 2.
Start one AFW pump manually prior to tripping RCPs in FRP-H.l.
- 3.
Isolate FCV-3227A lA AFW FCV in EEP-3.0 before a transition to ECP-3.1 occurs.
- 4.
Close 1A ARV while in EEP-3.0 before a transition to ECP-3.1 occurs. (WOG CT E - A)
SCENARIO OBJECTIVE/O VERVIEW:
While at 12% power, the team will have to:
Respond to a loss of vacuum and use AOP-8 to correct vacuum problem.
Respond to several instrument and component problems and respond using the appropriate ARPs, AOP-lOO and AOP-13.
Respond to a SGTR and isolate AFW flow and Steam flow from the SG using EEP-3.0.
Farley Oct 2008 exam Seen 3 Page 11 of 13
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 1 Page 1 of30 Event
Description:
Increase Reactor power to 12% lAW UOP-l.2.
Cue: Start of exam.
Time Position Applicant's Action or Behavior When simulator is taken to run the crew is expected to increase Reactor power to 12% lAW UOP-l.2.
This evolution will take approx. 15 -20 minutes RO Begin to increase reactor power to greater than 12% with following controls.
D Manual adjustment of control rods D Steam dumps in Steam Pressure Control Mode SRO Monitor reactor power and Steam Dump adjustments as reactor power rises BOP Will be reviewing UOP-l.2 and getting ready to roll the main turbine.
RO WHEN Nuclear at Power Permissive P-l 0 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.
D Place INTEMEDIA TE RANGE BLOCK TRN A to BLOCK.
D Place INTEMEDIA TE RANGE BLOCK TRN B to BLOCK.
On the Bypass and Permissive Panel verify the following:
D The INTERM RANGE TRAIN A TRIP BLOCKED light illuminated.
D The INTERM RANGE TRAIN B TRIP BLOCKED light ill umi nated.
Block the power range low setting reactor trip.
D Place POWER RANGE BLOCK TRN A to BLOCK.
D Place POWER RANGE BLOCK TRN B to BLOCK.
On the Bypass and Permissive Panel verify the following:
D The POWER RANGE LOW SETTING TRAIN A TRIP BLOCKED light illuminated.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 1 Page 2 of30 Event
Description:
Increase Reactor power to 12% lAW UOP-1.2.
D 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.
D Pressurizer Low Pressure D Pressurizer High Water Level D Loss of Flow-Two Loops RO Verify NR-45B is in the desired speed, i.e., 2na speed (2 min/div)
OR normal speed. (10 minldiv)
Go to event 2 when 12% power is reached.
End Event #1
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 2 Page 3 of30 Event
Description:
GSSC EXH fan trips and vacuum gets worse Cue: By Examiner.
Time Position Ar plicant's Action or Behavior Annunciators:
Recognize indications of VACUUM 600V BKR TRIPPED (LG3)
PROBLEMS TURB COND VAC LO (KKl)
Vacuum rising from 1.0 to 1.6 psia IPC alarm on GSSC brker open In this event the GSSC EXH fan will trip causing main condenser vacuum to rise or get worse.
There is only one set ofCT fans on service and one Circ water pump. AOP-S has the crew start this equipment and then send people out to find the problem. Vacuum is being adjusted in the booth so until the actions are completed vacuum will remain low and slowly decreasing.
SRO Direct crew to reference LG3 to determine reason it is in alarm.
There are 12 breakers listed in this ARP as to the reason, among them is EQ21, Old Gland Steam exhauster Manual; overcurrent; or undervoltage.
The other GSSC EXH fan is not normally lined up so that if the fan was started w/o referencing the procedure, there would be no effect on condenser vacuum.
Step 6 of AOP-S has SOP-2S.4 used to place the fan on service.
SRO Direct Monitoring Condenser pressure WHEN turbine power less than 30%, THEN verify condenser pressure less than 1.7 psia (3.5 inHga) pressure should be approx 1.3 and slowly rising Team Stabilize condenser vacuum using any or all of the following actions based on plant conditions, and the rate at which vacuum is worsening BOP 0
Start additional cooling tower fans -
call OSSO 0
Verify proper operation of on service SJAEs TBSO called 0
Start an additional CW PUMP Start IB CW pump 0
Dispatch personnel to check main turbine gland sealing steam pressures-TBSO called HP gland pressure LP gland seal pressure HP gland steam supply SRO Dispatch personnel to verify SJAE steam supply regulator -
OPERA TING PROPERLY. (155 ft, TURB BLDG)
And to verify on service GSSC EXH FAN - OPERATING PROPERLY.
(155 ft, TURB BLDG)
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 2 Page 4 of30 Event
Description:
GSSC EXH fan trips and vacuum gets worse TBSO or SSS-Plant called This steR may be done earlier since LG3 is in alarm and the GSSC EXH fan will be found with a triR flag on it.
After report that GSSC EXH fan is tripped then start standby GSSC EXH FAN using SOP-28.4, GLAND SEALING STEAM System SRO Dispatch personnel to inspect the main condenser for leaks and to vent the main condenser TBSO or SSS-Plant called BOP Check Hotwell level less than 4 ft Restore Vacuum slowly when GSSC EXH fan is running, CT fans called to be placed on service and 1 B CW pump has been started.
Go to event 3 when vacuum restored End Event #2
AppendixD Required Operator Actions Form ES-D-2
(
Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 3 Page 5 of30 Event
Description:
LT-459 fails high Cue: By Examiner.
Time Position Al plicant's Action or Behavior Annunciators:
Recognize indications ofL T -459 failing high PRZR L VL HI B/u HTRS ON (HA2) slowly PRZR L VL HI RX TRIP ALERT (HAl)
CHG decreasing to 0 GPM CHG HDR FLOW HI-LO (EA2)
VCT level increasing Actual Przr level decreasing LT-459 will increase slowly and charging flow will slowly decrease. AOP-lOO will be entered for the failed Level transmitter.
SRO Direct entry into AOP-1OO RO Check pressurizer level is on or trending to program value NO Take Manual control ofFK-122 and raise the demand to approximately 80 - 100 gpm RO Check RCP Seal Injection flows 6-13 gpm Adjust as necessary using HIK 186 SRO Determine if a pressurizer level transmitter/indicator loop has failed Failed or erroneous reading on LI459, LI460 or LI461 RO Select an unaffected pressurizer level channel on LS-459Z CH III/II selected Select an unaffected channel on the Pressurizer level recorder control switch LS/459Y CH III or II selected Check letdown inservice YES RO WHEN plant conditions permit, THEN restore components to automatic control as follows:
Restore charging flow control to automatic per SOP-2.l, CVCS SYSTEM PLANT STARTUP AND OPERATION Restore control of pressurizer heaters as necessary
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 3 Page 6 of30 Event
Description:
L T -459 fails high SRO Refer to Tech Specs 3.3.1 & 3.3.3 for any LCO requirements:
3.3.1 table 3.3.1-1 # 9 above P-7 mandatory LCO condition M Place one channel in trip in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> or reduce power to <P-7 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> 3.3.3 Table 3.3.3-1 Admin LCO due to required channels is 2 0
Notify the Shift Manager SRO 0
Submit a Condition Report for the failed level channel, and notify the Work Week Coordinator (Maintenance A TL on backshifts) of the Condition Report Go to event 4 when notifications made and all actions complete END-Event 3
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 4 Page 7 of30 Event
Description:
1 C Charging pump has a high lube oil temperature Cue: By Examiner. (From the time this is initiated until the alarm is 2.5 minutes.)
Time Position Applicant's Action or Behavior Annunciators:
CHG PUMP LUBE OIL TEMP HI (EA3)
Recognize indications ofCHG PUMP LUBE OIL TEMP HI Annunciator Only The charging pump will be running without CCW. Oil temperatures will rise slowly and the alarm will come in at 140°F. 2 minutes after the alarm* comes in the temperature will be at 160°F.
Then 2 minutes later the temperature will be at 170°F. We will trip the pump at 170°F if action is not taken to remove it from service.
SRO Direct entry into the ARP and evaluate securing the 1 C charging pump.
RO Call the Radside SO to look at the 1 C Chg pump temperature.
(A report will be given in approx 2 minutes and will be the actual value from the plant computer.)
RO After the report IF local temperature indication is ~ 160°F, THEN immediately shutdown the 1 C charging pump.
Start another charging pump and stop the affected pump, in accordance with SOP-2.1, CVCS PLANT STARTUP AND OPERATION RO SOP-2.1 version 96 step 4.7, Starting a Charging Pump or Swapping a Charging Pump When RCS Temp is > 180°F:
o Check auxiliary oil pump running for charging pump to be started as indicated by white light illuminated on MCB o
Check open miniflow isolation Q1E21MOV8109A or B o
Verify Q1E21MOV8106, is open.
o Verify a lA or lB CCW pump is running o
Verify FCV-122 and HIK 186 are closed o
Start lA OR 1 B Charging pump o
Observe CHG HDR PRESS indicator PI 121 and motor ammeter to check proper pump operation o
WHEN charging pump comes up to speed, THEN check auxiliary oil pump stops as indicated by white light NOT being illuminated on MCB.
o Adjust SEAL WTR INJECTION HIK 186 to maintain 6-13 gpm seal injection flow to each RCP o
Adjust FCV-122 to obtain chg flow proper flow o Place FCV-122 in Auto
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 4 Page 8 of30 Event
Description:
1 C Charging pump has a high lube oil temperature SRO Refer to Technical Specifications LCOs 3.5.2, and Technical Requirements TR 13.1.5.
3.5.2 mandatory LCO Condition A; since this pump is aligned to B Train and the swing pump is aligned to A Train. 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO 13.1.5 mandatory LCO Condition A. Two charging pumps shall be operable and this is a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> LCO.
SRO The actions to place IB Chg pump on service in the B train should be initiated here.
Direct the Radside SO, Rover and the SSS-Plant to place the IB chg pump on B Train.
If AOP-16 were used to start the IA chg pump after the 1 C chg pump was secured would not be wrong, just a different procedure from what the the ARP had them use. The lA chg pump would still be started properly and be in service at the end of the procedure and essentially the same steps are outlined above Go to event 5 when notifications made and all actions complete End event 4
(
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 5 Page 9 of30 Event
Description:
1A SGFP controller will fail. (SGFP speed will increase to 5500 rpm)
Cue: By Examiner.
Time Position I Al plicant's Action or Behavior Annunciators:
lA, lB,OR 1 C SG FEED FLOW> STM FLOW (JG 1, JG2, OR JG3)
Recognize indications of lA SGFP controller failing ALL FRVs close lA, lB, lC SG LVL DEV (JFl, JF2, JF3) lA SGFP will speed up ALL SG levels increase Power rising Stm dumps close The bypass FRVs close down as the lA SGFP speed increases. Due to the slow reaction time of the bypass valves if the operator does not take manual control of the SGFP, letdown may secure due to the przr level dropping due to the cooldown in progress, ALL SGWLs will increase and may trip the SGFP at 82%.
AOP-13, section 3 or AOP-lOO, section 1.5 may be used depending on if the team recognizes what the problem is.
Team Check that steam and feed flows matched on all SGs -
NO BOP Take manual control of SGFP speed by:
o Place SK 509B in Manual and lower demand as necessary.
o Take manual control of all FRV bypass valves lA SG BYPASS FLOW FK-479 lB SG BYPASS FLOW FK-489 lC SG BYPASS FLOW FK-499 Check no required automatic actions required or set points being SRO approached The SRO is in charge of monitoring SGWLs and directing action based on the level.
IF a loss of main feedwater occurs, THEN perform the actions required by AOP-13.0, LOSS OF MAIN FEEDWA TER If an automatic action is required or set points is approached:
Trip the reactor and go to EEP-O
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 5 Page 10 of30 Event
Description:
1A SGFP controller will fail. (SGFP speed will increase to 5500 rpm)
SRO Determine the instrument failure. The alarm is due to the failure ofthe controIler for IA SGFP.
Check Steam flow and Feed flow indicators.
BOP Adjust speed back to within the normal operating range for the feed flow/steam flow ~P required for the existing power level Since the main turbine is offline, the SGFP speed should be adjusted back to 50 psid.
0 Notify the Shift Manager SRO 0
Submit a condition report for the failed instrument, and notity the Notify the Work Week Coordinator Go to event 6 when notifications made and all actions complete END-Event 5
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 6 Page 11 of30 Event
Description:
IA SGFP will trip Cue: By Examiner. (The SGFP auto trip is blocked)
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of BOTH SGFPs tripped 1A OR 1B SGFP TRIPPED (Ke3)
SGFP speed decreasing JFl, JF2, JF3 - 1A(lB,1C) SG LVL DEV Feed flow decreasing JG1, JG2, JG3 - 1A(lB,1C) SG FEED All FRV bypass valves opening FLOW> STM FLOW JA1, JA2, JA3 - 1A(lB,1C) SG LO LVL The 1A SGFP may trip on high SGWL or will be tripped by the Booth operator when the recovery from the controller failure has been completed.
AOP-13 actions Team 0
Check Both SGFPs - TRIPPED 0
Check main generator OFF LINE
(
0 Check turbine tripped YES TSLB2 14-1 LIT TSLB2 14-2 LIT TSLB2 14-3 LIT TSLB2 14-4 LIT SRO Direct reducing reactor power to less than 2% using control rods and boron RO 0
Verify rod control in MANUAL 0
Stabilize T A VG by adjusting rod position and/or boron concentration BOP 0
Check for proper operation of steam dumps erultIQL'nAsK ¥.: STARTaitlimst:oj)'~\\~AFW<pu.mp 0
Verify all available AFW pumps RUNNING
- BOTH MDAFW pumps amps> 0
- TDAFW pump 3226/3235A and B white bi-stable lights LIT and speed increasing. The RED light on handswitch for 3235A/3226 will be LIT.
0 Verify SG blowdown - ISOLATED QIG24HV7614A closed Q1G24HV7614B closed Q1G24HV7614C closed
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 6 Page 12 of30 Event
Description:
lA SGFP will trip Maintain SG narrow range level approximately 65% by controlling BOP MDAFWPflow MDAFWP FCV 3227 RESET MDAFWP TO lAIlBIlC SG B TRN in MOD Pots adjusted for 3227 A, B, C Control TDAFWP flow TDAFWP FCV 3228 RESET TDAFWP SPEED CONT SIC-3405 adjusted 3228A, B, C adjusted When Reactor power is stable at 2% OR the reactor is tripped, then go the next event.
END-Event 6
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 7 Page 13 of30 Event
Description:
IA SGTR 300 gpm Cue: By Examiner Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of SGT leak RMS HI RAD (FBI)
Chg flow increases CHG HDR FLOW HI-LO (EA2)
R-15,R-19R-23AandB VCT level decreasing and possible auto makeup RCS PRESSURE DECREASING Przr level decreasing The SGTR will ramp in over 5 minutes. The crew will enter AOP-2.0 based on entry conditions for AOP-2 since R-15 is in alarm.
NOTE: The intent of step I is to ensure that SI is actuated if PRZR level cannot be restored to and maintained stable at the normal programmed value.
SRO Directs ARPs referenced and AOP-2.0 entered.
RO Maintain pressurizer level stable at programmed level by :
RO Control charging flow Take manual control - FCV-122 OR Reduce letdown flow OR Isolating letdown remove I orifice remove all orifices Maintain VCT level greater than 20% by:
Verifing reactor makeup system -
OR Control makeup in manual lAW SOP-2.3 IN AUTOMATIC IfVCT level can not be maintained >20%, then Trip the reactor and actuate a SI, go to EEP-O.
SRO Check reactor power conditions Check NO power ascension in progress.
NO Check NO power reduction in progress.
NO Check reactor power greater than 20%.
NO RNO - Direct the counting room to determine the R-70 leak rate using CCP-31, LEAK RATE DETERMINATION.
Begin trending R-70A (B,C) or R-15 using the Plant Computer and DA T A SHEET 1.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 7 Page 14 of30 Event
Description:
IA SGTR 300 gpm BOP Place the SJAE filtration unit in service using SOP-28.5, CONDENSER AIR REMOVAL SYSTEM.
Direct chemistry to perform grab samples and leak rate determinations in SRO accordance with CCP-201, SCHEDULE, CHEMISTRY AND WATER TREATMENT PLANT ACTIVITIES Table 55.
SRO WHEN RCS leak rate determined, THEN notify Shift Manager SRO Leak rate will continue to get worse until a Reactor trip and Safety Injection is called for.
End of event 7
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No~: 8-10 Page 15 of30 Event
Description:
IA SGTR 300 gpm Cue: preset Time Position Annunciators:
Many and numerous s Action or Behavior Recognize indications of SGTR Przr level falling rapidly RCS pressure dropping rapidly As the leak builds in the team will have to trip the reactor and safety inject the plant.
SRO open BOTH CRDM MG set breakers Direct the reactor trip and safety injection and enter EEP-O.
ROIBOP Immediate Operator actions of EEP-O Check reactor trip.
Check all R T breakers and R T bypass breakers -
CRDM MG set breakers Check nuclear power -
check rod bottom lights -
Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit 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 CLOSED OPEN FALLING.
LIT.
VerifY operating diesel generators are being supplied from at least one SWpump.
Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-l 1-1 lit
[] MLB-l 11-1 lit Check SI required o
Pzrz press 10 1850 psig2/3 TSLB2 17-1 THRU 3 o
Stm Line differential TSLB4 NO
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 16 of30 Event
Description:
Low Stm line press 585 psig 2/3 TSLB4 19-2 thru 4 o
Ctmt press high 4 psig 2/3 TSLBI 1-1 THRU 1-4 If SI required then actuate an SI, If not then go to ESP-O.1, Reactor trip rf'CnAn,,~~
~ ~
Directs safety injection if not previously performed.
SRO Directs continuing into EEP-O at step 5.
RO Directs the BOP to do attachment 2.
See Tab at end of scenario Attachment 2 and 4 for actions 6 [CAl Check containment pressure-HAS REMAINED LESS THAN 27 psig RO 7 Announce "Unit 1 reactor trip and safety injection".
8.1 Check secondary heat sink Available o
Check total AFW flow> 395 gpm
[] FI3229A
[] FI 3229B
[]FI3229C o
Total Flow FI 3229 OR Check any SG NR level> 31 % {48%}
8.2 WHEN all SG narrow range levels less than 31%{48%},
THEN maintain total AFW flow greater than 395 gpm.
8.3 WHEN at least two SG narrow range levels greater than 28%
AND TDAFWP NOT required, THEN stop TDAFWP.
YES 8.4 [CAl WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
8.4.1 Control MDAFWP flow.
MDAFWP FCY 3227 RESET
[] A TRN reset
[] B TRN reset MDAFWP TO 1AIIBIIC SG BTRN
[] FCY 3227 in MOD
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 17 of30 Event
Description:
IA SGTR 300 gpm 8.4.2 Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO 9 Check RCS temperature.
IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547°F.
[] TI 412D
[] TI 422D
[] TI 432D RO RNO IF RCS temperature less than 547°F and falling, THEN perform the following.
9.1.1 Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed on MCB Demand at 0 and minimum red light LIT 9.1.3 Control total AFW flow to minimize RCS cooldown, AFW FLOW TO IA(1B,IC) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFW TOTAL FLOW
[] FI 3229 9.1.4 IF MSIVs are closed THEN proceed to step 9.1.8 9.1.5 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing with RNO step 9.1.6.
Will call TBSO to accomplish this task RO 10 Check pressurizer PORVs and spray valves.
10.1 [CAl WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
10.1.1 Verify both PRZR PORVs indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 18 of30 Event
Description:
IA SaTR 300 gpm 10.1.3 Check PRT parameters STABLE or FALLING.
[] PR T PRESS PI 472
[] PRT LVL LI-470
[] PRT TEMP TI-471 10.2 rCA] WHEN pressurizer pressure 10.2 Stop 1A AND 1B RCPs to less than 2260 psig, stop spray flow.
THEN verify normal pressurizer spray valves closed OR in the process of closing.
1A(lB) LOOP SPRAY VL V
[] PK 444C
[] PK444D 10.3 Check any PRZR PORV ISO - OPEN RO 11 Check RCP criteria.
11.1 Check SUB COOLED MARGIN 11.1 IF HHSI flow greater than MONITOR indication - GREATER 0 gpm, THEN stop THAN 16°F{45°F} SUB COOLED IN all RCPs.
CETCMODE RO 12 Monitor charging pump miniflow criteria.
12.1 Control charging pump miniflow valves based on RCS pressure.
[] PI 402A
[] PI 403A Based on RCS pressure, close mini flows < l300 and open when> 100 psig.
Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
o Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
SRO 14 Check SGs not ruptured.
o Check secondary radiation indication - NORMAL.
Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D No SG level rising in an uncontrolled manner.
1A SGWL will be rising in an uncontrolled manner with rad monitors in alarm
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 19 of30 Event
Description:
lA SOTR 300 gpm Go to EEP-3, SGTR.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F} SUBCOOLED INC ETC MODE.
YES BOP
[CA] Identify ruptured SG(s).
Check any SG level - RISING IN a) WHEN ruptured SG(s) AN UNCONTROLLED MANNER YES Event 9 SROIRO CRllJilIf4AI;.;':JASK - ARV-3371A will fail o~en and must be isolated IA W this step
[CA] WHEN ruptured SG(s) identified, THEN isolate flow from ruptured SG(s).
Verify ruptured SG(s) atmospheric relief valve - ALIGNED.
PC3371A set 8.25 and in auto Verify 3371A is closed NO Verify lA SG is less than 1035 psig and ARV open, then manually close the ARV - take PC to manual and close on PC3371A If the ARV cannot be closed then unlock and close Q1N11 V004A or B
Event BOP CRitICAl-TASK' - FCV-3227A will fail open and must be isolated 10 lAW this step
[CA] WHEN ruptured SG(s) NR level greater than 31%{48%},
THEN perform the following:
[CAl Isolate AFW flow to ruptured SG(s) using FCVs.
FCV 3227 A in MOD, and closed NQ HV 3328A in MOD and closed YES If AFW flow from MDAFWP(s) NOT isolated, THEN isolate flow to lA SG by closing MOV 3764A OR E SRO Check ruptured SG(s) pressure GREATER THAN 250 psig.
YES
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 20 of30 Event
Description:
IA SGTR 300 gpm SRO Evaluate performing an RCS cooldown.
Determine required CETCs for cool down based on ruptured SG ressure.
RUPTURED SG PRESSURE (psig) 1151 - 1200 1101 -
1150 1051 - 1100 1001 -
1050 951 - 1000 901 -
950 651 -
700 601 -
650 551 -
600 501 550 451 -
500 401 450 351 -
400 301 -
350 251 -
300 250 REQUIRED CORE EXIT TEMPERATURE 536°F 531 <> F 525'" F 519<> F 513t>F 454°F 445 G F 434G F 423°F 411°F 398<>F 383<>F 365t>F 453<>F
{443<> F}
{434"F}
{423°F}
{412°F}
(4000 F}
{386t> F}
{3 lOG F}
{353"'F}
[332" F}
SRO Direct the STA to Display the hottest CETC page I TCI on plant computer.
This is normally selected by the STA and put on the control board display.
SRO Will direct these steps:
Begin ReS cooldown to cold shutdown.
Depending on RCS temperature the BOP will either start the cooldown and then bypass the stm dump interlock for P-12 or will bypass initially.
The Stm Dumps will be set up in the STM Press mode and the cooldown.
started at the maximum rate. This means the steam dupms are to be opened to approx. 20%.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 21 of30 Event
Description:
IA SGTR 300 gpm BOP WHEN P-12 light lit (543°F), THEN perform the following:
Block low steam line pressure SI.
Place handswitches for STM LINE PRESS SI BLOCK - RESET
[] A TRN to BLOCK
[] B TRN to BLOCK Verify blocked indication.
BYP & PERMISSIVE STM LINE ISOL.
SAFETYINJ.
[] TRAIN A BLOCKED light lit
[] TRAIN B BLOCKED light lit Bypass the steam dump interlock.
STM DUMP INTERLOCK
[] A TRN to BYP INTLK
[] B TRN to BYP INTLK Adjust steam header pressure controller to maximize the cooldown rate D STM HDR PRESS
[] PK 464 adjusted Use Stm dumps to cooldown since they are available.
Stop the cooldown when the hottest CETC temperature is less than the required temperature and then maintain CETCs at the required Temp.
Check any intact SG narrow range level-GREATER THAN 31 %{ 48%}.
YES
[CA] WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
Control MDAFWP flow.
[] A TRN reset
[] B TRN reset MDAFWP TO 1AIlBilC SG BTRN
[] FCV 3227 in MOD Control TDAFWP flow.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 22 of30 Event
Description:
1 A SGTR 300 gpm TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO Check pressurizer PORVs Check any PRZR PORV ISO - power available I
[CA] WHEN pressurizer pressure less than 2335 psig, THEN verify I
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 FALLING.
I
[] PRT LVL LI-470
[] PRT TEMP TI-471 I
Check at least one PRZR POR V ISO - OPEN II BOP Verify SI - RESET.
(
I MLB-l 1-1 not lit (A TRN) and MLB-l 11-1 not lit (B TRN)
I Verify PHASE A CTMT ISO - RESET.
MLB-2 1-1 not lit and MLB-2 11-1 not lit I
BOP Check PHASE B CTMT ISO - RESET. - NO ctmt pressure increase RO IF instrument air available, THEN establish instrument air to containment.
Verify at least one air compressor started.
AIR COMPRESSOR
[]IA i
[] lB
[]IC
~
Check INST AIR PRESS PI 4004B greater than 85 psig.
Check instrument air to containment.
IA TOCTMT
[] MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO
[] Annunciator KDl clear YES
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 23 of30 Event
Description:
[9 [CAl Check if LHSI Pumps should be stopped.
Check RCS pressure - GREATER THAN 275 psig{435 psig}
YES PT-402 AND 403 Check RCS pressure - STABLE OR RISING YES Verify the SI reset Secure any running RHR pumps Take HS to stop.
SRO Check if Cooldown should be stopped.
Check hottest core exit TICs - LESS THAN REQUIRED Temperature.
Stop RCS cool down Maintain core exit TICs - LESS THAN REQUIRED TEMPERATURE.
RNO Do NOT proceed until hottest core exit TICs - LESS THAN REQUIRED TEMPERA TURE.
SRO 0
Check ruptured SG(s) pressure - STABLE OR RISING.
o Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 36°F{65°F} SUBCOOLED IN CETC MODE.
YES for BOTH NOTE: Normal pressurizer spray may become ineffective during pressure reduction. This situation justifies using a PRZR PORV per step 18.
RO Reduce RCS pressure to minimize break flow and refill pressurizer.
Open all available normal pressurizer spray valves.
[] PK 444C
[] PK 444D Reduce RCS pressure using ONE pressurizer POR V to minimize break flow and refill pressurizer.
One PORV may be used to increase the pressure reduction and will probably be the case.
SRO Reduce RCS pressure until one of the following three conditions occurs, then stop RCS pressure reduction.
Res pressure less than ruptured SG pressure
(
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 8-10 Page 24 of30 Event
Description:
IA SGTR 300 gpm AND pressurizer level greater than 13%{ 43%}
OR Pressurizer level greater than 73%{ 66%}
OR SCMM indication less than 16°F {45°F} subcooled in CETC mode.
Then verify the sprays and PORVs are closed.
SRO Check RCS pressure - RISING.
PI-402 and 403 rising Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
GREA TER THAN 16°F {45°F} SUBCOOLED IN CETC MODE.
0 Check secondary heat sink available.
>395 gpm AFW flow
> 31 %{ 48%} SGNR level 0
Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13%{ 43%}.
Suggested END OF SCENARIO: STEP 21 OF EEP-3.0 This scenario can be terminated any time the NRC examiner deems enough actions have been taken.
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page2S of30 Event
Description:
Attachment 2 and 4 ofEEP-O Cue: BOP will accomplish when at step 5 ofEEP-O Time Position Applicant's Action or Behavior of EEP-O AUTOMATIC ACTIONS VERIFICATION 1 Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (lA,lB or 1C)
[] B train (lD,lE or 1C) 2 Verify each train ofCCW - STARTED.
2.1 Verify one CCW PUMP in each train-STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX 1A or 1B CCWFLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM 1A(lB, 1C) CCW HX
[] Q1P16FI3009AA > 0 gpm
[] Q1P16FI3009BA > 0 gpm
[] Q1P16FI3009CA > 0 gpm 3 Verify one eHG PUMP in each train - STARTED.
[] A train (lA or lB) amps> 0
[] B train (lC or lB) amps> 0 BOP 4 Verify RHR PUMPs - STARTED.
RHRPUMP
[] 1Aamps>O
[] 1B amps> 0 BOP 5 Verify Safety Injection Flow.
5.1 Check HHSI flow - GREATER THAN 0 gpm.
[] PI 943
AppendixD Required Operator Actions Form ES-D-2
(
Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page 26 of30 Event
Description:
Attachment 2 and 4 ofEEP-O BOP Check RCS pressure - LESS THAN 5.2 Proceed to Step 6.
275 psig{435 psig}.
BOP 6 Verity containment ventilation isolation.
6.1 Verify containment purge dampers - CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B 6.2 Verify containment mini purge dampers - CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D 6.3 Stop MINI PURGE SUPPIEXH FAN. Will place HS to STOP BOP 7 Verity containment fan cooler alignment.
Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED o A train
[]1A
[]IB DB train
[]lC
[]1D 7.2 Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM 1A(IB,lC,lD) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024B
[] Q1P16MOV3024C
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page 27 of30 Event
Description:
Attachment 2 and 4 of EEP-O
[] QIP16MOV3024D BOP 8 Verify AFW Pumps - STARTED.
8.1 VerifY both MDAFW Pumps - STARTED
[] lA MDAFW Pump amps> 0
[] lB MDAFW Pump amps> 0 AND
[] FI-3229A indicates> 0 gpm
[] FI-3229B indicates> 0 gpm
[] FI-3229C indicates> 0 gpm 8.2 Check TDAFW Pump start required.
o Condition OTSLB OSetQoint o Coincidence 0 RCPBus TSLB21-1 02680 V 112 Detectors Undervoltage 1-2 1-3 on 2/3 Busses LowLowSG 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 Verify TDAFWP started.
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
8.4 VerifY TDAFW flow path to each SG.
TDAFWP TO 1A(1B,lC) SG
[] Q1N23HV3228A in MOD
[] Q1N23HV3228B in MOD
[] QIN23HV3228C in MOD TDAFWP TO lAClB,l C) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open BOP 9 Verify main feedwater status.
9.1 VerifY main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
[] FCV 488
(
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page 28 of30 Event
Description:
Attachment 2 and 4 ofEEP-O
[] FCV 498 9.2 Verify both SGFPs - TRIPPED.
9.3 Verify SG blowdown - ISOLATED.
[] QIG24HV7614A closed
[] QIG24HV7614B closed
[] QIG24HV7614C closed 9.4 Verify SG blowdown sample - ISOLATED MLB lights lit.
lA(lB,lC) SGBD SAMPLE STEAM GEN ISO
[] MLBI 19-2 lit QIP15HV3328 closed
[] MLBI 19-3 lit QIP15HV3329 closed
[] MLBI 19-4 lit QIP15HV3330 closed BOP 10 Check no main steam line isolation actuation signal present.
Signal SetQoint coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow
>40%
Y2 on 2/3 TSLB4 16-3,4 and and 17-3,418-3,4 Lo-Lo Tavg
<543°F 2/3 TSLB2 10-1,2,3 HI -HI ctmt press > 16.2 psig 2/3 TSLB 1 2-2,3,4 11 Verify PHASE A CTMT ISO.
11.1 Verify PHASE A CTMT ISO - ACTUATED.
[] MLB-2 1-1 lit BOP
[] MLB-2 11-1 lit 11.2 Check all MLB-2lights - LIT.
11.2 Verify PHASE A CTMT ISO alignment using ATTACH 3, PHASE A CTMT ISO BOP 12 Check all reactor trip and 12 Perform the following.
reactor trip bypass breakers - OPEN. 12.1 Open reactor trip breaker(s) manually from MCB or locally.
Reactor trip breaker A 12.2 Record any breaker(s)
Reactor trip breaker B manually opened.
Reactor trip bypass breaker A Reactor trip bypass breaker B BOP 13 Trip CRDM MG set supply breakers.
lA(IB) MG SET SUPP BKR
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page 29 of30 Event
Description:
Attachment 2 and 4 of EEP-O
[] NICIIE005A
[] NICIIE005B BOP 14 Secure secondary components.
14.1 Stop both heater drain pumps.
HDP
[]IA
[]IB 14.2 Check any condensate pump started.
14.2.1 IF started, THEN stop all but one condensate pump.
[] lA
[]IB 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-O-SOP-O.O, APPENDIX B, TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.
Will call TBSO to accomplish this.
BOP 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 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KVBKR
[] 810 - OPEN
[] 914 - OPEN BOP 17 Verify two trains ofECCS equipment aligned.
17.1 Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICA TION.
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 3 Event No.: 9 Page 30 of30 Event
Description:
Attachment 2 and 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION BOP 1 Verify two trains of ECCS equipment aligned.
Check DFO 1 closed Verify DF02 closed Check DG 15 closed Verfiy DG02 closed Verify two trains of battery chargers - energized Amps >0 1.6 Verify two trains of ESF equipment aligned.
Check all MLB-l lights LIT Verify charging pump suction and discharge valves - OPEN.
[] Q1E21MOVS132A
[] Q1E21MOVS132B
[] Q1E21MOVS133A
[] Q1E21MOVS133B CHG PUMP SUCTION HDR ISO
[] QIE21MOVS130A
[] Q1E21MOVS130B
[] QIE21MOVS131A
[] Q1E21MOVS131B 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[]lA
[]IB
[]lC
[] ID RX CAY H2 DILUTION FAN
[]lA
[]1B 1.S WHEN power restored to any de-energized emergency bus, THEN verify alignment of associated equipment.
BOP Call Radside SO to Verify Spent Fuel Pool Cooling in service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
End of Attachment 2 and 4
Scenario #4 2008 NRC exam Southern Nuclear.
J.M. Farley Nuclear Plant
. Operations Training Simulator Exam Scenario HLT-32 NRC EXAM SCENARIO #4 FA2008301 Technical Review:
GTOhmstede Date:
07-2008 Training Department Approval:
NRC approved Date:
10-2008 Energy to Serve Your World'"
AppendixD Scenario #4 Outline Form ES-D-l Facility: I Farley Nuclear Plant I I Scenario No.: I 4
1 Op-Test No.: I 2008-301 Examiners:
Operators:
SRO RO BOP Initial Conditions: 25% power, on hold for 1-2A DG RTS. 1254 ppm, MOL; A train on service, B Train protected. lA SGFP on service. Bypass FRVs in auto and transfer to the main FRV s is in progress Turnover:
1-2A DG TIO for governor work. (OOS 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />, ETR 4 hrs) 1B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
Current Risk Assessment is and projected is A Train On-Service - J! Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event Malf.No.
Event Type*
Event Description No.
(I) (RO)
TK-144 fails HIGH. TCV-143 fails to divert on high temperature.
1 Controller can NOT be controlled in manual. Letdown will have to be secured.
N(BOP)
Place Excess letdown on service lAW AOP-16.
2 3a C (BOP) lC CCW pump trips on Overcurrent. IB CCW pump does not auto TS (SRO) start.
C (BOP)
CCW leak when 1 B CCW pump starts-3b Leak can be isolated locally at the 1 C CCW pump due to relief valve lifting.
C (ALL)
Air side Seal oil pump trips and the DC pump does not auto start.
4 This causes High Vibration on Main Turbine. 10 mils -
R(RO&
The crew will be instructed to ramp down BOP) 5 I (RO)
PORV will stick open. MOV isolation will have to be closed.
6 C (ALL)
Main Turbine vibrations increase to 15 mils - AOP-3.0 entered to trip the MT and ramp to 8% power.
7 M(ALL)
LOSP - 1 C DG goes to unit 2 and 1 B DG starts and trips. 2C DG will not start. Enter ECP-O here.
8 C(RO)
TDAFW pump will not auto start, start from MCB.
9 M(BOP)
When at ECP-O step 16, reduce intact SGs to 200 psig, then restore off site power.
(N)ormal, (R)eactlvlty, (I)nstrument, (C)omponent, (M)aJor Farley Oct 2008 exam Scen 4 Page 2 of 15
Appendix D Scenario 4 detailed summary sheet Form ES-D-1 Initial Conditions: 25% power, on hold for 1-2A DG RTS, MOL, 10,000 MWD, A Train 0/5, B Train protected, RCS boron concentration is 1254 ppm, and Xe is -75 pcm. 40 gal dilutions as necessary to maintain temperature and power. Rods are in manual. 1A SGFP is on service, Bypass FRVs in auto and transfer to the main FRVs is in progress.
Turnover:
1-2A DG TIO for governor work. (OOS 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br />, ETR 4 hrs) 1 B EHC pump TIO for motor bearinI replacement. (OOS 6 hrs, ETR 2 hrs)
Current Risk Assessment is and projected is A Train On-Service - B Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event?
Event 8 Event 9 TK-144 fails HIGH. TCV-143 fails to divert on high temperature. Controller can not be controlled in manual. Letdown will be secured and AOP-16 will be entered to place excess letdown on service.
Place Excess letdown on service lAW AOP-16.
1 C CCW pump trips on Overcurrent. 1 B CCW pump does not auto start.
CCW leak when 1 B CCW pump starts-AOP-9 will be entered.
Leak can be isolated locally at the 1 C CCW pump due to relief valve lifting.
Air side Seal oil pump trips and the DC pump does not start. This causes High Vibration on Main Turbine. 10 mils - crew will be instructed to ramp down.
This may require a TBSO report that the vibrations on the turbine deck are high.
PT-445 fails high. PORV will stick open. MOV isolation will have to be closed.
Main Turbine vibrations increase to 15 mils - AOP-3.0 entered to trip the Main Turbine and ramp to 8% power.
LOSP - 1 C DG goes to unit 2 and 1 B DG starts and trips.
2C DG will not start.
TDAFW pump will not auto start, start from MCB. (CT)
In ECP-O, direct isolating RCP seal injection before a charging pump starts or is started. (CT)
When ECP-O step 16, reduce intact SGs to 200 psig then restore off site power. (CT is to decrease intact SGs to 200 psig)
Restore off site power.
Farley Oct 2008 exam Seen 4 Page 11 of 15
Appendix D Scenario 4 detailed summary sheet Form ES-D-1 CRITICAL TASK SHEET
- 1.
Start the TDAFW pump. (WOG CT ECA-O.O - -B)
- 2.
Isolate RCP seal injection before a charging pump starts or is started.
- 3.
Depressurize the intact SG(s) at the maximum rate such that all the following limiting conditions are met:
SG depressurization is not initiated until narrow-range level in at least one intact SG is greater than 4%
If narrow-range level cannot be maintained greater than 4% in at least one intact SG (after depressurization is commenced), then SG depressurization is stopped until narrow-range level is restored to greater than 4% in at least one intact SG SG pressure does not decrease to less than 130 psig RCS cold leg temperature does not decrease to less than 243°F If a positive SUR is indicated on either the source range or the intermediate range (after depressurization is commenced), then SG depressurization is stopped and the RCS is allowed to heat up (WOG CT ECA-O.O - -G)
SCENARIO Ramp up in progress.
OBJECTIVE/O VERVIEW:
The team should be able to:
Respond to a failed equipment and instruments and complete the appropriate ARPs, AOP-9, AOP-IOO, AOP-3.0 & Tech Specs Respond to a loss of off-site power for which no DG will start. When ECP-O is in progress and reducing SGs to 200 psig, off-site power will be restored.
The crew will restore off-site power and then exit ECP-O.O.
Farley Oet 2008 exam Seen 4 Page 12 of 15
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 112 Page 1 of 19 Event
Description:
TK-144 fails HIGH; place excess letdown on service Cue: Two minutes after the start of the exam.
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of TK -144 failing high L TDN TO DEMIN DIVERTED-TEMP -
TI-143 indicating off scale high (>200°F)
HI (DFl)
TI -144 indicating off scale high (>200°F)
Possible boration and RCS temperature decrease if prolonged This failure does NOT allow manual control of TCV 144 and therefore letdown will have to be secured. AOP-16 will be entered and excess letdown placed on service lAW SOP-2.7.
RO Ensure Letdown is diverted to the VCT NO
- TCV 143 white light LIT (VCT) on MCB Try to take manual control of TCV 144 will not be able to Monitor charging and letdown flows and temperatures.
FI 122 FI 150 TI 140 TI 144 and 143 Adjust charging or letdown flow as required to reduce the letdown flow temperature.
SRO Direct removing letdown from service by closing L TON ORlF ISO 45 (60) GPM Q1E21HV8149A, B, and C Direct entering AOP-16 RO Takes handswitches to close for L TDN ORIF ISO 45 (60) GPM QIE21HV8149A, B, and C Monitor VCT level to ensure proper level is maintained Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation.
Check charging pump running YES Check Charging flow FK-122 controlling in AUTO with flow indicated YES Check DE3 clear YES Check PRT parameters - STABLE should be stable RO PRT PRESS PI 472 PRT LVL LI-470 PRT TEMP TI-471
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 112 Page 2 of19 Event
Description:
TK-144 fails HIGH; place excess letdown on service SRO Determine Status of Normal Letdown Check normal CVCS letdown - AFFECTED BY MALFUNCTION YES o
LTDN HX OUTLET FLOW, FI-150 - NO FLOW INDICATED o
Minimize RCS makeup o
Manually close charging flow control o
Minimize seal injection between 6-l3 gpm o
Direct Chemistry to shutdown the zinc addition system (ZAS) o Dispatch personnel to investigate cause of the Letdown malfunction IF desired due to plant conditions, THEN place excess letdown in SRO service using FNP-I-S0P-2.7, CHEMICAL AND VOLUME CONTROL SYSTEM EXCESS LETDOWN Excess letdown flow will be limited to approximately 10-15 gpm.
BOP Verify the RCDT system in operation per SOP-50.0, LIQUID WASTE PROCESSING SYSTEM Will call Radside SO and check on status and notify himlher to expect an increase in RCDT level due to excess letdown being placed on service.
BOP 0
Verify the following valves open:
HV3095 HV3443 HV3067 o
Verify HV-l37 is closed o
Then open HV 8153 and 8154 o
Place excess letdown divert valve QIE21HV8143 control switch in the RCDT position - flushing to RCDT o
Slowly throttle open the excess L TDN HX discharge valve QIE21HCVl37 to establish excess letdown flow not to exceed 1650 F excess letdown heat exchanger outlet temperature SRO Should read the Caution in the procedure and speak to reactivity changes associated with placing excess letdown on service.
CAUTION A small portion of excess letdown piping can not be flushed to the RCDT (calculated to be approximately one gallon) and there are uncertainties associated with achieving a complete flush. Therefore, the
.. ",,,,,ti.,ih, affects associated with.
excess letdown to the
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 112 Page 3 of19 E
tD ven
- f escnpllOn: TK 144 f:*l HIGH al s 1 td
- pi ace excess e own on servIce VCT/Charging pump suction must be considered and contingencies established for mitigating the consequences.
SRO Should decide and brief the crew on aligning excess letdown to the VCT/Charging pump suction and the expectations on this. This is not required to be done since it will take a significant amount of time to do this evolution.
SRO Direct crew back to AOP -16 to do the following:
Continue actions to restore normal letdown Determine status of excess letdown flow Verify CRG FLOW FK-122 - MANUALLY CLOSED Check Reactor - Critical Check PZR level - LESS THAN 75%
Maintain PZR level 60%
Reduce power and Tavg as necessary Check normal boration flow path - ADEQUATE FOR DESIRED RAMP RATE Maintain PZR Level 60% by maintaining Seal injection 6-13 gpm and VCT level 20 - 60%,
Go to next event when AOP-16 is exited End Event # 1 12
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 3 Page 4 of 19 Event
Description:
1 C CCW pump trips and 1 B CCW pump does not auto start and a CCW leak develops Cue: By Examiner.
Time Position Ar piicant's Action or Behavior Annunciators:
Recognize indications of a Tripped CCW pump lC CCW PUMP OVERLOAD TRIP (AA3) and loss of CCW flow CCW FLOW FROM RCP OIL CLRS LO No flow on FI3043CA (DD3)
Temperature rising on running components When the leak starts the following will alarm BOP PANELS ALARM (BES)
BOP panel L and N (LH2 and NH2)
CCW SUMP NORTH AND SOUTH HI-HI CCW SRG TK L VL A TRN and B TRN HI-LO (AA4 and AB4)
When the CCW pump trips a leak will start in the CCW surge tank. 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 CCW pump and the ARP will take care of the leak.
NOTE to examiner: with excess letdown is in service and a loss ofCCW2 monitor TI-139 on MCB2 Excess letdown TEMP2 to stay <165°F SRO Reference ARP and decide the standby CCW pump did not auto start.
Direct to start the IB CCW pump or entry into AOP-9 to get the IB CCW pump running.
Note inARP:
SRO Resetting the lockout relay could prevent proper operation of the standby pump in the event of an LOSP.
Do not reset lockout relay without Shift Supervisor approval.
If AOP-9.0 entered the following will be accomplished:
BOP Verify CCW pump started in affected train:
handswitch for 1B CCW pump taken to START Check CCW system adequate for continued plant support Check CCW flow adequate in affected train.
Check RCP motor bearing temperatures less than 19S0F.
Check CCW pump not cavitating. Stop any cavitating CCW pump.
CCW Surge tank level being maintained at or above 13 inches. YES BOP Verify SW flow supplied to the ON SERVICE train YES Check ON SERVICE train affected NO
(
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 3 Page 5 of 19 Event
Description:
Ie eew pump trips and IB eew pump does not auto start and a eew leak develops Check both RHR pumps stopped YES SRO Inform the SM to evaluate event classification and notification requirements using EIP-8, NON-EMERGENCY NOTIFICATIONS AND EIP-9, EMERGENCY CLASSIFICATION AND ACTIONS BOP Check SFP cooling aligned to an operating CCW train YES Check on service CCW train operating YES SRO IF lB CCW Pump is aligned to A Train, THEN rack out I C CCW Pump supply breaker DF04.
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 CCW pump and the lB CCW pump did not autostart, maintenance personnel will have to determine if the IB CCW pump is OPERABLE based on the autostart feature (SR 3.7.7.3). Until that time, the CCW system is INOPERABLE until the 1 C CCW pump is racked out and may be INOPERABLE when the results of troubleshooting are known.
Mandatory LCO until the lC CCW pump is racked out and 3.7.7 condition A restore within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is in effect.
A~tidd$for';'de'cr(i'3Sin2Sutl!e1~'jkl~"et BOP Check ST level to determine which train the leak is on Dispatch personnel to locate and isolate the leak Attempt to fill CCW surge tank per SOP-23.0,COMPONENT COOLING WATER SYSTEM, to maintain level above the 10 level alarm point.
Step 4.18 Open QIPl7SV3028A and B on the MCB Monitor CCW ST level Maintain level between 33 and 50 inches When addition is complete the close the above valves SRO Call Chm to help in locating the source of the leak BOP Secure filling after the source of the leak determined and corrected and filling is no longer required.
Go to next event when filling the Surge Tank has been secured.
End Event #3
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 4 Page 6 of19 Event
Description:
Air Side Seal Oil Pump trips which leads to HIGH main turbine vibrations Cue: By Examiner.
Time Position Al plicant's Action or Behavior Annunciators:
Recognize indications of LOSS OF SO pumps, AIR SIDE SEAL OIL PUMP OFF (LF4) decreasing Hydrogen pressure and high SEAL OIL PRESS LO (LF5) vibrations on the main turbine.
H2 PRESS HI-LO (LJ2)
Hydrogen pressure dropping EMERG AIR SIDE SEAL OIL B/U PUMP AMBER light LIT above the Air Side SO ALARM (LG5) pump DEH TRBL (LBl) and subsequent high Air Side DC emerg Seal Oil pump starts vibration alarms on the DEH panel screen and then trips Red lights Iit for high vibration for #5 and
- 6 bearings When the air side SO pump trips the emerg DC SO pump starts and then trips. The ARP is a little confusing and the candidate mayor may not start the Seal Oil backup pump. The SO backup pump does not have an auto start feature for this situation and if the Main Turbine tripped there would be no source of SO. They should look at and address all the alarms, but if they do not see the high vibration alarms, a phone call will alert the crew as to the high vibrations. Preferably this will be done after the TBSO is sent to investigate the main turbine and the seal oil system.
Actions for the high vibrations are found in SOP-28.1.
Note inARP The intent of the following steps is to ensure that generator hydrogen pressure remains within the capability of the first available backup source of air side seal oil. See SOP-28.3, HYDROGEN SEAL OIL SYSTEM, precautions and limitations for additional guidance.
ARP step 3 IF the DC Air Side Emergency Seal Oil Pump is supplying the seal oil pressure, (and the Attached Oil Pump is not available), THEN start the Seal Oil Backup Pump AND reduce hydrogen pressure in the generator to 45 psig or less.
Intent of step 3 - with the AC pump tripped and the DC pump not available, the SO Back up should be started.
BOP Start the Back up seal oil pump IA W LF5 SRO Reference ARPs and decide course of action Send TBSO to SO skid and main turbine to check for problems BOP Receive report from TBSO of high vibrations in the turbine building.
Source unknown at this time.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 4 Page 7 of19 Event
Description:
Air Side Seal Oil Pump trips which leads to HIGH main turbine vibrations SRO Enter SOP-28.1 to look for guidance on high vibrations for the Main Turbine.
P&Ls 3.4.1 Observe the following vibration limits: The limits provided below in vibration indications apply to readings taken from the Bently Nevada or DEHC displays.
- 4.0 mils: Satisfactory
- 7.0 mils: Alarm (Investigation is necessary if vibration is continuous.)
- 14.0 mils: Decrease turbine speed or load to reduce vibration. Prior to exceeding 14 mils vibration, contact Westinghouse Coordinator for guidance. If turbine vibration exceeds 14 mils, trip the main turbine.
SRO Call Shift Manager to explain vibration problems.
SM will tell the SS to ramp the unit offline at 2 MW/min. Stop at 12%
power, remove the Main Turbine from the grid and secure the Main Turbine. Hold Reactor power at 12% until a plan is developed.
BOP Put in correct target and ramp rate (40 MW I 2 MW Imin)
Press the GO pushbutton RO Adjust rods and boron lAW UOP-2.1 to ramp unit to 12% power.
When the desired power level is reached (approx 20%), then go to event 5.
END-Event 4
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 5 Page 8 of19 Event
Description:
PT -445 fails high Cue: By Examiner.
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications ofPT-445 failure PRZR PRESS REL 445A OR B/u HTRS RCS pressure dropping ON (HD1)
PORV 445A indicates open PRZR SAFETY VL V TEMP HI (HA4)
All heaters ON PRZR PORV TEMP HI (HA5)
REL VL V 444B/445A OPEN (HE1)
PRZR PRESS HI-LO (HC1)
PT-445 failing high will cause PORV 445A to open. This will decrease actual RCS pressure and cause all the heaters to come on. Sprays will remain closed. Since the PORV is failed to remain open, the operator will not be able to close the PORV and will have to close the manual isolation valve.
AOP-lOO Section 1.1 RO Verify RCS pressure is stable.
NO Take manual control ofthe PORV 445A and close the valve. NO If the PORV will not close then close MOV 8000A YES SRO Check RCS pressure stable or rising YES SRO Refer to Tech Specs for LCO requirements that exist 3.4.1 for DNBR limits Pressurizer pressure~2209 psig Mandatory LCO condition A restore w/i 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 3.4.11 PORVs Mandatory LCO condition B Close the associated block valve and remove power from the block valve in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and restore to OPERABLE w/i 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> SRO Notify the Shift Manager SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance A TL on backshifts)
SRO IF the pressurizer power operated relief valves operated, THEN perform the following:
Refer to SOP-1.2, REACTOR COOLANT PRESSURE RELIEF SYSTEM, for cooldown of the pressurizer relief tank Refer to SOP-O.O, GENERAL INSTRUCTIONS TO OPERA nONS
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 5 Page 9 of 19 Event
Description:
PT -445 fails high PERSONNEL, for reporting requirements 15.5 Documenting and Reporting Safety Valve, Relief Valve, and Reactor Vessel Head Vent Valve Failures and Challenges In order to comply with NRC reporting requirements, an LCO and condition report must be filled out each time a pressurizer or steam generator power operated relief valve or safety valve becomes inoperable, OR a safety or power operated relief valve lifts on either the pressurizer or a steam generators.
The condition report should contain at least the following information:
- Which safety or power operated relief lifted or was inoperable.
- Reactor power level.
- RCS temperature and pressure.
- Steam generator level and pressure.
- Approximately how long the valve was open.
Go to next event when the above requirements are met.
End event 5
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 6 Page 10 of 19 Event
Description:
Main Turbine vibrations increase - MT trip required Cue: By Examiner.
Time Position Al plicant's Action or Behavior Annunciators:
Recognize indications of increasing vibrations NONE on the Main Turbine Monitor the DEH vibration panel Check the Turbine Supervisory panel for high vibrations Enter SOP-28.1 to look for guidance on high vibrations for the Main Turbine.
P&Ls 3.4.1 Observe the following vibration limits: The limits provided below in vibration indications apply to readings taken from the Bently Nevada or DEHC displays.
14.0 mils: If turbine vibration exceeds 14 mils, trip the main turbine.
Phone call from turbine deck may be needed to initiate this event SRO Direct a Turbine trip Direct entry in to AOP-3.0 RO/BOP Check Turbine tripped Check TSLB2 14-1 thru 4 Check DEH display for GV and TV closed RO Stabilize reactor power VerifY Rod Control in MANUAL Adjust control rods in MANUAL to control RCS TAVG VerifY steam dumps modulate to maintain reactor power less than 35%.
BOP WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped RO Check all RCPs - STARTED BOP Check SG levels - STABLE OR TRENDING TO 65%
VerifY MSRs - RESET Stop both heater drain pumps.
Transfer to STM PRESS mode by:
0 Reduce Rx power to less than 8%
0 Place stby conds pump in STOP
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 6 Page 11 of 19 Event
Description:
Main Turbine vibrations increase - MT trip required 0
WHEN SGFP suction pressure greater than 500 psig, THEN stop all but one CNDS PUMP 0
WHEN BYP & PERMISSIVE NUCLEAR AT POWER PERMISSIVE P-IO status light NOT lit, THEN perform the following 0
Verify intermediate range reactor trip and rod stop -
UNBLOCKED 0
Verify power range low setpoint reactor trip - UNBLOCKED 0
Verify BYP & PERMISSIVE LOW POWER TRIP BLOCK P-7 status light - LIT 0
Check reactor power - LESS THAN 8%.
When Rx power is less than 8%, then manually control the ARVs to reduce stm dump demand to O.
Place STM DUMP MODE SEL A-B TRN switch to RESET Place steam dump system in steam pressure mode using SOP-I8.0, STEAM DUMP SYSTEM Manaully close the ARVs and verifY they are set to 8.25 and in AUTO.
Go to procedure and step in effect Go to the next event when control of the unit at 8% power is achieved.
END-Event 6
(
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 12 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored Cue: By Examiner.
Time Position I Annunciators:
numerous Al plicant's Action or Behavior Recognize indications of LOSS OF ALL AC All lights in CR go out, then re-energize when Unit 2 DGs tie on.
All Unit 1 4160V emergency busses are de-energized Off-site power is lost with the 1-2A DG tagged out. Unit 2 will get the 1 C DG and 2B DG and 1B DG will trip on start. The 2C DG will not be available and the crew will have to implement the remaining steps in ECP-O.
The TDAFW Pump will not auto start and will be started from the MCB, and then Off site power will be restored when the ARVs are opened to decrease SG pressure to 200 psig.
Off site power will be brought back on to the bus to re-start emergency loads. When one train has been restored the scenario will be terminated.
SRO Recognize Rx trip and loss of all AC and do one of the following:
Enter EEP-O and do IOAs or go directly to ECP-O:
ROIBOP Immediate Operator actions ofEEP-O Check reactor trip.
Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED A Train (F & K) power available lights lit OR B Train (G & L) power available lights lit ENTER ECP-O HERE Immediate Operator actions of ECP-O NO Check reactor tripped.
No power 1.1 Check reactor trip and reactor trip bypass breakers - OPEN.
1.1.1 Manually trip reactor.
[] Reactor trip breaker A
[] Reactor trip breaker B
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 13 of 19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored
[] Reactor trip bypass breaker A
[] Reactor trip bypass breaker B IF any reactor trip breaker NOT open or any reactor trip bypass breaker NOT open, THEN locally open affected breaker. (121 ft, AUX BLDG rod control room) call for this ROVER Check nuclear power - FALLING.
PR1(2,3,4) PERCENT FULL POWER
[] NI 41B
[] NI 42B
[] NI 43B
[] NI 44B IRI(2) CURRENT
[] NI 35B
[] NI 36B Check turbine tripped.
[] TSLB2 14-1 lit
[] TSLB2 14-2 lit
[] TSLB2 14-3 lit
[] TSLB2 14-4 lit RO Verify ReS isolated.
YES YES o
WHEN RCS pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
o Verify normal letdown isolated.
YES All orifice isolation valves closed or leltdown isolation valves closed o
Verify excess letdown line - ISOLATED.
NO Close HV 8153 and 8154 o
Verify all reactor vessel head vent valves - CLOSED.
RX VESSEL HEAD VENT OUTER ISO
[] QIB13SV2213A
[] QIB13SV2213B RX VESSEL HEAD VENT INNER ISO
[] QIB13SV2214A
[] QIB13SV2214B
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 14 of 19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored BOPIRO y~rifr!()t~IA!}Ynow GREATER THAN 395 gpm.
[JkI1iI.:iIJT:i~1: -
VerifY proper AFW alignment.
Verify TDAFWP running.
Take handswitches for TDAFWP to 8T ART TDAFWP STM SUPP FROM 1 B(l C) SG
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEEDCONT
[] SIC 3405 adjusted to 100%
[CA] Restore power to any emergency bus.
Verify supply breakers for major loads on emergency 4160 V busses-OPEN.
[] BKR DFOI (lA SIU XFMR TO IF 4160 V BUS)
[] BKR DFl5 (lB SIU XFMR TO IF 4160 V BUS)
[] BKR DF-13-1 (IF 4160 V BUS TIE TO IH 4160 V BUS)
[] BKR DGOI (IA SIU XFMR TO IG 4160 V BUS)
[] BKR DG15 (IB SIU XFMR TO IG 4160 V BUS
[] lA BATT CHARGER BKR ED-04-1
[] 1 C BATT CHARGER A TRN BKRED-09-1
[] 1 C BATT CHARGER B TRN BKR EE-06-1
[] 1 B BATT CHARGER BKR EE-05-1
[] lC CCW PUMP BKR DF-04-1
[] IB CCW PUMP BKR DF-05-I
(
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 15 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored
[] 1B CCW PUMP BKR DG-05-I
[] 1B SW PUMP BKR DK-04-I
[] ID SW PUMP BKR DL-03-I
[] #4 RW PUMP BKR DJ-03-1
[] #5 RW PUMP BKR DJ-04-1
[] #8 RW PUMP BKR DH-03-1
[] #9 RW PUMP BKRDH-04-1
[] #10 RW PUMP BKR DH-05-1
[] 1B CRDM CLG FAN BKR ED-11-1
[] 1A CRDM CLG FAN BKR EE-13-1
[] 1ACSPUMPBKRDF-ll-l
[] IB CS PUMP BKR DG-11-1
[] 1A RHR PUMP BKR DF-09-1
[] 1B RHR PUMP BKR DG-09-I
[] IA CHG PUMP BKR DF-06-1
[] IB CHG PUMP A TRN BKR DF-07-I
[] IB CHG PUMP B TRN BKR DG-07-1
[] 1 C CHG PUMP BKR DG-06-I
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 16 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored BOP
[] 1B MDAFWP BKR DG-lO-I Check I-2A, 1 C or 1B diesel generator running for Unit 1.
o MSS in MODE 1 o
USS in UNIT 1 NO o
When load shed has been competed then depress START PB 2C DG will not start SRO Continue in procedure At step 5.8 Continue efforts to start at least one diesel generator.
5.9 Restore offsite power to any emergency bus and then continue efforts to energize any 4I60V emergency bus and proceed to step 6.
Request Shift Manager coordinate efforts to restore offsite power to at least one startup transformer.
SRO Direct step 6 actions:
rCA] WHEN power is restored to any emergency bus, THEN proceed to step 24.
rCA] WHEN an SI signal is present, THEN reset SI signal.
SRO Call for this to be done Defeat auto start of safeguards equipment using ATTACHMENT 2.
Isolate RCP seals using ATTACHMENT 3.
BOP Locally close HOTWELL FILL INLET ISO NIPII V50I and HOTWELL FILL MAN BYP NIPII V506. (137 ft TURB BLDG)
Call TSC for TBSO BOP Verify main steam isolation and bypass valves - CLOSED.
Verify main feedwater flow control and bypass valves - flow path(s).
CLOSED.
[] FCV 478
[] FCV 488
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 17 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored
[] FCV 498 lA(lB,lC) SG FW BYP FLOW
[] FCV 479
[] FCV 489
[] FCV 499 VerifY blowdown - ISOLATED.
lA(lB,lC) SGBD ISO QIG24HV7614A closed QIG24HV7614B closed QIG24HV7614C closed Check SGs not faulted.
NO Check SGs not ruptured.
NO Check intact SG narrow range level - GREATER THAN 31 %{ 48%}
[CA] WHEN intact narrow range SG level greater than 31 %{ 48%},
THEN maintain intact SG narrow range level 31 %-65%{ 48%-65%}.
Control TDAFWP speed. SIC 3405 adjusted Control TDAFWP flow control valves with hand wheels. Local action SRO Call to De-energize non-essential DC loads using A TT ACHMENT 4.
Direct electrical maintenance personnel to calculate remaining battery capacity.
CSTLVL
[] LI 4132A
[] LI 4132B BOP eiJlmilellii:lll~i - commencing this evolution is all that is required Reduce intact SGs pressure to 200 psig.
Check at least one intact SG narrow range level - GREATER THAN 31%{48%}.
RO 16.2 WHEN P-12 light lit, THEN perform the following.
16.2.1 Block low steam line pressure SI.
Appendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 18 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored STM LINE PRESS SI BLOCK - RESET
[] A TRN to BLOCK
[] B TRN to BLOCK 16.2.2 Verify blocked indication.
BYP & PERMISSIVE STM LINE ISOL SAFETY INJ.
[] TRAIN A BLOCKED light lit
[] TRAIN B BLOCKED light lit 16.3 WHEN pressurizer pressure less than 2000 psig, THEN perform the following.
16.3.1 Block low pressurizer pressure SI.
PRZR PRESS SI BLOCK - RESET
[] A TRN to BLOCK
[] B TRN to BLOCK 16.3.2 Verify blocked indication.
BYP & PERMISSIVE PRZR. SAFETY INJECTION
[] TRAIN A BLOCKED light lit
[] TRAIN B BLOCKED light lit BOP Co-ordinate this activity using radio handsets:
Dump steam from intact SGs at maximum controllable rate.
Locally control intact SG atmospheric relief valves with handwheel.
(127 ft, AUX BLDG main steam valve room) 3371A, B,C open locally Maintain at least one intact SG narrow range level GREATER THAN 31%{48%}.
Terminate the scenario.
If needed the following can be accomplished as follows:
Instructor Note: ACC informs crew that offsite power now available, and reliable. lA & 1 B Start Up transformers energized.
SRO Crew takes actions ofECP-O.O to power emergency busses SRO Energizes dead bus per ECP-O.O, step 5.9.2 or SOP-36.2
AppendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 4 Event No.: 7/8/9 page 19 of19 Event
Description:
LOSP - ECP-O entered, TDAFW pump does not auto start and then off-site power is restored When emergency busses energized, go to step 24 ofECP-O.O.
BOP WHEN any startup transformer energized, THEN close associated startup transformer output breaker.
Take the SYCH switch to the BYPASS position and then 0
DFO 1 and/or DG 15 BOP WHEN IF or IG 4160 V bus energized from any startup transformer, THEN verify the associated river water bus breaker closed.
SRO When emergency busses energized, go to step 24 ofECP-O.O.
Check at least one train of 4160 V ESF busses - ENERGIZED. YES BOP Verify SW system operating.
Verify electrical alignment.
Terminate the scenario.
END-Event 6
)
Scenario #5 2008 NRC exam Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario HLT-32 NRC EXAM SCENARIO #5 FA2008301 Technical Review:
GTOhmstede Date:
07-2008 Training Department Approval:
NRC approved Date:
10-2008 COMPANY Energy to !)'erve Your W'Orld'"
AppendixD Scenario #5 Outline Form ES-D-l Facility: I Farley Nuclear Plant I I Scenario No.: 5 I I Op-TestNo.: I 2008-301 Examiners:
Operators:
SRO RO BOP Initial Conditions: Mode 3, MOL, Xe decreasing from its peak following the reactor trip, The reactor tripped 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> ago as a result of loss of both SGFPs, Turnover:
0% RTP, MOL,917 ppm Cb, 10,000 MWD, I
Xe concentration is slowly decreasing (-2969).
Reactor tripped 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> ago as a result of a loss of both SGFPs & repairs are in progress.
CTMT mini-purge running for vibration analysis Reactor Startup planned in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, ECC being calculated br 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.
I Event Malf.
Event Type*
Event Description No.
No.
I (BOP)
Rad monitor R35A, control room radiation monitor, fails high. 3 1
Control room dampers fail to automatically close. Manual TS (SRO) isolation of dampers is required. 3.3.7 2
I (RO)
PT-444 fails high. AOP-100 entry to restore RCS pressure.
N (RO)
Initiate an entry into AOP-27 for emergency boration (SSS 3
phone call due to SDM OOS). Boric acid pump 1A will not start. 1 B Bat pump will start. TS will be handled by SSS per the phone call.
C(RO&
1A StU transformer trips on fault, 1A RCP loses power, AOP-4 4
BOP) required and AOP-5 required.
TS (SRO)
M (ALL)
A SBLOCA (200 gpm over 30 seconds) occurs.
(Automatic SI fails to actuate, man actuation required CT) 5 C (BOP) 1A & 1 B CTMT coolers fail to auto start, man start of at least one required C (BOP or RO) 1A RHR pump fails to automatically start, can be manually started.
)
Farley Oct 2008 exam Scen 5 Page 2 of 15
Appendix D Scenario #5 Outline Form ES-D-l M(ALL)
A LBLOCA occurs 12 minutes after SBLOCA and
- power to MOV8811B (CTMT SUMP to 1B RHR Pump) will be lost.
- When RWST level reaches 32 feet, 'A' RHR pump trips on overcurrent.
6 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(CT. Makeup to the RWST and minimize RWST outflow)
When ECP-1.1 is entered and evaluation of equipment running complete, then restore power to 8811 B.
7 Terminate when transition back to ESP-1.3 or EEP-1.0 is complete, depending on RWST level (N)onnal, (R )eactivity, (I)nstrument, (C)omponent, (M)aJor Farley Oct 2008 exam Scen 5 Page 3 of 15
Appendix D Scenario 5 detailed summary sheet Form ES-D-1 Initial Conditions: Mode 3, MOL, Xe decreasing from its peak following the reactor trip, The reactor tripped 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> ago as a result of loss of both SGFPs.
Turnover:
0% RTP, MOL,917 ppm Cb, 10,000 MWD, Xe concentration is slowly decreasing (-2969).
Reactor Startup planned in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, ECC being calculated by Reactor Engineering.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia.
Currently at step 5.17 of UOP-1.3.
CTMT mini-purge running for vibration analysis Current Risk Assessment is and projected is Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event 7 Rad monitor R35A, control room radiation monitor, fails high. 3 Control room dampers fail to automatically close on BOP. Manual isolation of dampers is required. LD4 BOP annunciator.
PT-444 will fail high. AOP-100 entry to restore RCS pressure.
Initiate an entry into AOP-27 for emergency boration (SSS phone call due to SDM OOS). Boric acid pump 1A will not start. 1 B Bat pump will start.
1A StU transformer trips on fault. This results in a loss of power to 'A' train ESF busses as well as the 'A' RCP bus. The crew should enter AOP-4 for the loss of flow in the 'A' loop and AOP-5 for the loss of the train of power. Closing the A loop spray valve will be required (RO) & secure feeding the SG by closing A loop AFW FCV (BOP)
LCO 3.8.1 should be evaluated for the loss of one of the two required qualified circuits.
A SBLOCA (200 gpm over 30 seconds) occurs. Automatic SI fails to actuate. 1A RHR pump fails to automatically start; can be manually started. 1A & 1 B CTMT CRLS do not auto start.
The crew is expected to identify the fault, respond by entering EEP-O and completing the immediate operator actions - which includes Manual actuation of SI. (CT Manually actuate at least one train of SI before transitioning to E-1)
A LBLOCA occurs 12 minutes after SBLOCA and power to MOV8811 B (CTMT SUMP to 1 B RHR Pump) will be lost. When RWST level reaches 32 feet, 'A' RHR pump trips on overcurrent. 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 the foldout page of EEP-1.0 (CT. Makeup to the RWST and minimize RWST outflow.)
When ECP-1.1 is entered and evaluation of equipment running complete, then restore power to 8811 B.
Terminate when transition back to ESP-1.3 or EEP-1.0 is complete, depending on RWST level.
Farley Oct 2008 exam Seen 5 Page 11 of 15
)
Appendix D Scenario 5 detailed summary sheet CRITICAL TASK SHEET Form ES-D-1
- 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 Completion of step 9 in ESP-O.1 Manually Actuate SI
- 2.
Makeup to the RWST and minimize RWST outflow. (WOG CT ECA-1.1 - - B)
SCENARIO OBJECTIVEI OVERVIEW:
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 Mode 3 with component and instrumentation failures, LBLOCA, failure of CS systems, ECP-1.1 entry required The team should be able to:
recognize and respond to failures of various instruments and components per ARPs, AOP-27, AOP-4.0, AOP-5.0, AOP-100, & Tech Specs identify a SBLOCA, LBLOCA, initiate a manual SI, recognize that the required Containment Cooling System components are not operating and start Ctmt coolers as required per EEP-O, EEP-1.0, & ECP-1.1 Commence makeup to the RCS using AOP-27.
Farley Oct 2008 exam Scen 5 Page 13 of 15
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 1 Page 1 of29 Event
Description:
Rad monitor R35A, control room radiation monitor, fails high Cue: Start of exam.
Time Position AI plicant's Action or Behavior Annunciators:
Recognize indications ofR-3SA failing HIGH BOP/ R-3SA HI ALARM (LD4)
NONE BOP PANELS ALARM (BES)
When R-3SA fails high the only indication will be annunciators. Since R-3SA is in the plant and not in the simulator, a call to the extra operator will get a response.
Applicable ARPs need to be entered SRO Direct ARP entry for LD4 BOP Verify Computer Room AHU dampers closed.
- QSV47HV3626 COMPUTER RM HV AC SUPP OPEN BOP should close these 3 valves SRO Call to have TSC HV AC verified to be in recirc mode i
BOP Verify both control room doors closed I
I SRO Consult Technical Specifications 3.3.7 to determine the required I
alignment for the following:
- Control Room Pressurization Units
- Control Room Recirculation Units
- Control Room Utility Exhaust Fan TS 3.3.7 Table 3.3.7-1 has two Functions that need to be addressed:
- 2 Automatic actuation Logic and Actuation relays - 2 Trains Since the HV3626, 3624 and 3622 did not close, this has to be entered.
This is a mandatory LCO, Condition A to place one CREFS train in emergency recirculation mode in 7 days.
f1I/f
- 3R-35 *sINO =ADMIN ~~
sinc e uni. in mo with no movem III progr and only e rad nitor is quired in
. condition.
Erd *n C-oN O}tl (SfV It {Jue tv FI.( ",c,f/dlllJ.3 "J ;.f4,
~
~.J IH C) ttl J 'tuttI ()~ t-t;J;::'
~ e Il-VIt-I',
iLtJr CIL 2.()() ~ 10 't ~ 2..3
Allliendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 1 Page 2 of29 Event
Description:
Rad monitor R35A, control room radiation monitor, fails high SRO Submit a condition report on the failed instrument, and notifY the Work Week Coordinator (Maintenance A TL on backshifts) of the condition report SRO Inform the SM of the failure and Tech Spec entry Go to event 2 when Tech Specs have been evaluated and notifications have been made.
End Event #1
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 2 Page 3 of29 Event
Description:
PT -444 fails high Cue: By Examiner.
Time I Position Ar plicant's Action or Behavior Annunciators:
Recognize indications of PT -444 FAILING PRZR PRESSURE HI-LO (HCl)
HIGH PRZR HI-LO PRESS ALERT (HC2)
PORV-444B open PRZR PRESS REL VL V 445A OR BIU Przr pressure decreasing HTRS ON (HD 1)
All heaters OFF I
All spray valves open I
In mode 3 the actions are the same as at power. RCS pressure will be decreasing due to sprays open and PORV 444A open.
AOP-lOO Section 1.1 SRO Direct entry into AOP-lOO.
RO Verify RCS pressure is stable.
NO Take manual control of the PK-444A.
YES OR Take manual control ofthe spray valves and heaters and PORVs Close spray valves and PORV 444B and turn on heaters PORV will close on handswitch SRO Check RCS pressure stable or rising YES Set control band for RCS pressure.
2220-2250 psig SRO Refer to Tech Specs for LCO requirements that exist:
3.4.1 for DNBR limits Pressure will have dropped below 2209 psig Mandatory LCO restore pressure in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> 3.4.11 PORVs-does not apply since the PORV can be controlled from PK444A and is capable of being opened and closed manually.
- Notify the Shift Manager
- Refer to SOP-O.O, GENERAL INSTRUCTIONS TO OPERATIONS PERSONNEL, for reporting requirements
- SOP-O-
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 2 Page 4 of29 Event
Description:
PT -444 fails high 15.5 Documenting and ReQorting Safety Valve, Relief Valve, and Reactor Vessel Head Vent Valve Failures and Challenges In order to comply with NRC reporting requirements, an LCO and condition report must be filled out each time a pressurizer or steam generator power operated relief valve or safety valve becomes inoperable, OR a safety or uower ouerated relief valve lifts on either the uressurizer or a steam generators.
The condition report should contain at least the following information:
- Which safety or power operated relief lifted or was inoperable.
- Reactor power level.
- RCS temperature and pressure.
- Steam generator level and pressure.
- Approximately how long the valve was open.
SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance A TL on backshifts Go to event 3 when notifications have been made.
L End Event #2
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 3 Page 5 of29 Event
Description:
Phone call to enter AOP-27 to restore SDM Cue: By Examiner.
Time Position AI plicant's Action or Behavior Annunciators:
Recognize indications of AOP-27 entry NONE Phone call The phone call will initiate this event. lA BAT pump will not start, 1B BAT pump will start.
AOP-27 entered RO Start a BAT pump 1B BAT pump started OpenMOV 8104 Verify one chg pump started Establish adequate letdown Verify 8149A and either 8149B or Copen Establish charging flow rate of 40 gpm Verify boration flow> 30 gpm on FI-IlO Secure ZAS - Chemsitry called SRO WHEN shutdown margin greater than Technical Specification requirement, THEN proceed to step 10 and secure the emergency boration.
SRO should direct a sample and STP-29.1 done again to verify SDM obtained.
Go to event 4 when the SRO has called for a sample after borating 500 gallons.
END-Event 3
)
Alll!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 4 Page 6 of29 Event
Description:
1A StU transformer trips on fault Cue: By Examiner.
Time Position Applicant's Action or Behavior i\\nnLUlciators:
li\\ S/U XFMR UV (MB 1) li\\ 4KV BUS UV (MEl)
Indications for loss of lA S/U transformer:
li\\ RCP amps decrease to zero (0) li\\ RCS loop flow decreases to zero and then increases as back-flow is established 1-2i\\ DG starts and connects to IF 4160v bus ID OR IE 4KV BUS SUPP BKR TRIPPED(MD4 )
ID OR IE 4KV BUS UV (ME4) 4160 VOLT BKR TRIPPED (MF4) li\\ RCS LOOP FLOW LO OR li\\ RCP BKR OPEN (EFl)
RCP BUS UV SINGLE INPUT i\\LERT (EF4) 1-2i\\ DG TRBL (Wi\\3)
IF, IH, OR lK 4KV BUS BKR i\\UTO TRIP (WEI) i\\mp meter II-2001B for li\\ 4160v bus decreases to zero Bus potential lights for "BUS N', "BUS D", "II", "IP", IB", "1 U", "1 W", "1 Y" li\\ 4160v BUS WILL BE DE-ENERGIZED i\\ND 1-2i\\ DG will pick up the 4160V emergency bus.
i\\OP-4 and i\\OP-5 entry required SRO I Directs i\\OP-4.0, LOSS OF REi\\CTOR COOLi\\NT FLOW, entry and directs actions per below:
(This may be directed by SRO to occur concurrently with i\\OP-5.0)
RO I Performs i\\OP-4 immediate operator actions:
RO RO Manually closes 1i\\ RCS loop spray valve PK-444C Secures feeding li\\ SG by closing MDi\\FW FCV 3227 i\\
Monitors Tavg for RCS loops::: 541°F Minimum Temp for Criticality o
(i\\ loop may be < 541°F, but this TS is not applicable in mode 3)
Maintains PRZR pressure 2200-2300 psig with heaters and B loop spray valve as required Checks normal letdown established - i\\OP-4.0 step 5
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 4 Page 7 of29 Event
Description:
1A StU transformer trips on fault 0
IF Letdown not established, restore using AOP-4.0 attachment 1 (attached)
Maintain PRZR level at ~22% level i
SRO Directs to open Reactor Trip breakers within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> RO Checks Band C RCPs running - AOP-4.0 step 8 SRO Procedure step 9 is: Go to UOP-2.1, SHUTDOWN OF UNIT FROM MINIMUM LOAD TO HOT STANDBY 0
After evaluation of this step AOP-5.0 is directed to be entered AOP-5.0, LOSS OF A OR B TRAIN ELECTRICAL POWER BOP
- Verifies at least one train of 4160V BUSSES energized:
YES-A train from 1-2A DG, B train from off-site through B SU XFMR Checks 1-2A DG Started & output breaker closed 0
Started 0
59-61 Hz 0
3740-4580 V 0
IF 4160V bus power light lit BOP
- Verifies SW supply flow in A train adequate 0
2 'A' train SW pumps running 0
SW TO/FROM DG BLDG in 'A' train OPEN: V519IV537 0
Dual indication (throttled) on SW TO TURB BLDG ISO valves V515 & V517 I
0 Opens SW TO TURB BLDG ISO B TRAIN V517 0
Closes 'A' train SW TO/FROM TURB BLDG ISO valves V515, V516, V540, & V542 i
0 Closes MOV3135 0
Directs Radside SO to secure SGBD per SOP-16.1 0
Closes MOV3149
AI!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 4 Page 8 of29 Event
Description:
1A StU transformer trips on fault o
Checks no I-2A DG lube oil temp annunciator in alarm (calls Diesel building SO to check local annunciator. Panel)
BOP I If not required, then stop any running MDAFW pump:
Momentarily place MDAFW FCV 3227 RESET A TRN OR B TRN switches to the reset position Stop lA MDAFW Pump WHEN MDAFW Pump is stopped, THEN perform the following:
o VerifY MDAFWP TO lA,lB AND lC SG QINIIHV3227A,B ANDC in MOD.
o VerifY MDAFWP TO IAIlBIlC SG B TRN FCV 3227 in MOD.
o Fully open MDAFWP to lA, lB AND I C SG FLOW CONT HIC-3227AA, BA AND CA (100% demand)
BOP I Checks SW available in 'B' train - AOP-S.O step 6 ID & IE SW pumps running
'B' train SW pressure> 60 psig RO IA CCW pump (B train) - is running 1 C charging pump - is running Secure 1 A chg pump BOP or RO I Checks 'A' train CCW operating - AOP-5.0 step 10
'c' HX FI 3043CA > 0 gpm BOP Maintains SG NR levels 61-69% with a MDAFW pump, &
controlling FCV-3227A, B, & C - AOP-5.0 step 11 Checks RHR-NOT required Maintains Mode 3 stable per UOP Verifies 4160VNON-Vital busses energized-AOP-5.0 step 15 o
IB, lC, IE 4160V busses energized.
o Reports IA & ID 4160V busses are NOT energized Performs steps for ID bus deenergized:
Establish power to IA 600 V LC emergency section loads VerifY pressurizer heater group lA - OFF VerifY open BKR EA08-1.
Verify closed BKRs ED08-I and EA09-1
AI!.I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 4 Page 9 of29 Event
Description:
1A S/U transformer trips on fault WHEN pressurizer heater group lA operation is desired, THEN place HTR GRP lA BLOCKING BYPASS SW to BYPASS IF required, THEN manually energize pressurizer heater group lA BOP Align 1 C air compressor for service Place the lC air compressor handswitch in RUN/START VerifY lC air compressor started Check INST AIR PRESS PI 4004B - GREATER THAN 85 psig VerifY instrument air aligned to containment MLB-3 1-2 NOT lit IA to PENE RM PRESS LO Annunciator KDl clear BOP Verify unaffected train Energized - AOP-5.0 step 16 I
LCs E, C, L, J, S MCCs B, G, T, V BOP
- Check 'A' train 125V DC battery loads < 250 amps RO Verifies DRPI energized - AOP-S.O step 20 SRO Check Tech Specs:
- LCO on 3.8.1 AC Sources-Operating, Mandatory LCO Condition A-
- One of the two offsite required circuits is inoperable Initiate STP-27.1, AC SOURCE VERIFICATION SRO Determines offsite power NOT available for train A and returns to step 2
- AOP-5.0 step 23 Go to event 5 when Immediate operator actions of AOP-4 complete, reactor trip breakers addressed, LCO 3.8.1 identified, actions of AOP-5.0 in progress AND discretion of NRC End event 4
AImendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 10 of29 Event
Description:
SB LOCA - 200 GPM Cue: By Examiner.
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of SB LOCA PRZR L VL DEV LO (HB2)
PRZR PRESS HI-LO (HCI)
- PRZR level indication trending to down
- PRZR pressure trending down CTMT SUMP L VL HI-HI OR TRBL (located on BOP panel P) (pG3)
Charging flow increasing CTMT sump level (LI-3282A & B) increasing Automatic SI fails to actuate. IA RHR pump fails to automatically start; can be manually started.
The crew is expected to identify the fault, respond by entering EEP-O and completing the immediate operator actions - which includes Manual actuation of SI.
SRO I Directs ARPs referenced and AOP-I.O entered.
RO I Maintain pressurizer level stable at or near programmed level by :
Control charging flow Take manual control of 122 OR Reduce letdown flow OR Isolating letdown remove 1 orifice remove all orifices If Przr level cannot be maintained stable at or near programmed level, then the reactor should be tripped.
RO Maintain VCT level greater than 20% by:
Verifing reactor makeup system -
OR Control makeup in manual lAW SOP-2.3 IN AUTOMATIC IfVCT level can not be maintained >20%, then roll the chg pump suctions to the RWST by:
QIE2lLCVl15B open Q1E2lLCVl15D open And Q1E2lLCVl15C closed QIE2lLCVl15E closed
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 11 of29 Event
Description:
SB LOCA - 200 GPM SRO I Direct RO to obtain values and calculate a flow balance.
_____ ( charging flow)
+
(seal injection flow)
_____ (letdown flow)
_____ (#1 sealleakoffflow)
= Approx 200 gpm leak rate)
NOTE: It is anticipated that examinees will determine PRZR level cannot be maintained above 15% and will manually SI any time after step 3 is performed CRITICAL TASK: WHEN SI Setpoint is exceeded, THEN Manually actuate at least one train of SI before transitioning to E-l - Verification ofImmediate operator actions SRO I~BI'f.liil!lisi-Reactor trip and safety iniection Direct the reactor trip and enter EEP-O.
RO/BOP I Immediate Operator actions of EEP-O Check reactor trip.
Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
Check turbine - TRIPPED.
TSLB2 14-1 thm 4 lit 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 SWpump.
Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[) ACTUATED status light lit
[] MLB-l I-llit YES
Awendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 12 of29 Event
Description:
[] MLB-1 11-llit SRO Directs continuing into EEP-O at step 5.
Directs the BOP to do attachment 2.
See Tab at end of scenario Attachment 2 and 4 for actions 6 [CA] Check containment pressure-HAS RO REMAINED LESS THAN 27 psig YES RO 7 Announce "Unit 1 reactor trip and safety injection".
8.1 Check secondary heat sink Available 0
Check total AFW flow> 395 gpm
[] Fl3229A
[] FI 3229B
[]FI3229C 0
Total Flow FI 3229 OR Check any SG NR level> 3 1 % {48%}
8.2 WHEN all SG narrow range levels less than 31 %{ 48%},
THEN maintain total AFW flow greater than 395 gpm.
8.3 WHEN at least two SG narrow range levels greater than 28%
AND TDAFWP NOT required, THEN stop TDAFWP.
8.4 [CAl WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
8.4.1 Control MDAFWP flow.
MDAFWP FCY 3227 RESET
[] A TRN reset
[] B TRN reset MDAFWP TO 1AIlBIlC SG BTRN
[] FCY 3227 in MOD 8.4.2 Control TDAFWP flow.
TDAFWP FCY 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted
Alli!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 13 of29 Event
Description:
SB LOCA - 200 GPM RO 9 Check RCS temperature.
IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547°F.
[] TI 412D
[] TI 4220
[] TI 432D I
RO RNO IF RCS temperature less than 547°F and falling, THEN perform the following.
9.1.1 Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET 9.1.2 Verify atmospheric reliefs closed on MCB Demand at 0 and minimum red light LIT 9.1.3 Control total AFW flow to minimize RCS cooldown, AFW FLOW TO lA(1B,lC) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFW TOTAL FLOW
[] FI 3229 9.1.4 IF MSIVs are closed THEN proceed to step 9.1.8 9.1.5 IF MSIVs are open, THEN isolate steam loads in the turbine building while continuing with RNO step 9.1.6.
Will call TBSO to accomplish this task RO 10 Check pressurizer PORVs and spray valves.
10.1 [CAl WHEN pressurizer pressure less than 2335 psig, THEN verify both PRZR PORVs closed.
10.1.1 Verify both PRZR PORV s indicate CLOSED 10.1.2 Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-471 10.2 [CAl WHEN pressurizer pressure 10.2 Stop lA AND IB RCPs
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 14 of29 Event
Description:
SB LOCA - 200 GPM RO to less than 2260 psig, stop spray flow.
THEN verify normal pressurizer spray valves closed OR in the process of closing.
[] PK 444C
[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN 11 Check RCP criteria.
11.1 Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F {45°F} SUB COOLED IN CETCMODE 11.1 IF HHSI flow greater than o gpm, THEN stop all RCPs.
RO I 12 Monitor charging pump miniflow criteria.
12.1 Control charging pump miniflow valves based on RCS pressure.
[] PI 402A
[] PI 403A Based on RCS pressure, close miniflows < 1300 and open when> 1900 psig.
Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
SRO 113 Check SGs not faulted.
o Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
SRO I 14 Check SGs not ruptured.
o Check secondary radiation indication - NORMAL.
Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D o
No SG level rising in an uncontrolled manner.
Check containment radiation -
[] R-2 CTMT 155 ft
[] R-7 SEAL TABLE
[] R-27 A CTMT HIGH RANGE (BOP)
[] R-27B CTMT HIGH RANGE (BOP)
NO.
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 15 of29 Event
Description:
SB LOCA - 200 GPM D Check containment pressure - LESS THAN 3 psig.
NO D Check containment ECCS sump level-LESS THAN 0.4 ft.
ENTER EEP-l. LB LOCA SHOULD HAVE OCCURRED BY NOW LB LOCA will occur 12 minutes after the SB LOCA End of event 5
)
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 16 of29 Event
Description:
LB LOCA Cue: 12 minutes after SB LOCA Time I Position I Applicant's Action or Behavior Annunciators:
Recognize indications of LB LOCA All CTMT PRESS annunciators in alarm Phase B actuation (EEl, EE2, EE3, EE4, EE5)
R VLIS lights tum RED Various and numerous ECCS flow increases RCS SUBCOOLING < 16°F Rapid rise in ctmt pressure EEP-O FO Qage reguirements:
I Greater than 16°F {45°F} subcooled in 1.1 IF HHSI flow greater than I
CETC mode o gpm, THEN stop ALL RCPs I
Check MINI-flow criteria and close all chg pump miniflow valves Utilize bracketed numbers in procedures - adverse containment criteria When the transition to EEP-l is made and the LB LOCA existsl FRP-P.l will have to be addressed EEP-l l LOSS OF REACTOR OR SECONDARY COOLANT.
SROIRO Recognizes CSF Red Path FRP-P.I BOP SRO Updates Team on FRP-P.I Entry SRO/RO Performs Actions ofFRP-P.l 1
Check 1I01l I'rl~ur,.. - GREATZII:
1 flow 8%$.U:.r tha:t~
TRlI.II %7!i paia! 435psi,gJ '
TEEN
':to fFf{I--ce-dllre* and LO(1]'
step in ~fff:ct:"
PRESS
}AOll)
[J rr ~In!l RIlR gPit WLQW U rr {O3!l H 60511 n (1032 RCS <435 psig RNO applied LHSI Flow> 1.5 x 103 gpm SRO Updates team and returns to procedure and step in effect EEP-I EEP-ll LOSS OF REACTOR OR SECONDARY COOLANT.
)
/
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 17 of29 Event
Description:
LB LOCA RO I Check RCP criteria.
Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F} SUBCOOLED IN CETC MODE.
IF HHSI flow greater than 0 gpm, THEN stop all RCPs.
[]1A NO
[] 1B STOP ALL RCPs
[]IC BOP I Check SGs not faulted.
Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN 50 psig.
YES BOP I Check intact SG levels.
BOP RO Check any intact SG narrow range level-GREATER THAN 31%{48%}.
YES
[CA] WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
Control MDAFWP flow.
[] A TRN reset
[] B TRN reset MDAFWP TO 1AIlB/IC SG BTRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted Check secondary radiation indication - NORMAL.
Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D Check pressurizer PORVs Check any PRZR PORV ISO - power available
[CAl WHEN pressurizer pressure less than 2335 psig, THEN verify pressurizer PORVs closed with no leakage.
Verify both PRZR PORVs - CLOSED
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 18 of29 Event
Description:
LB LOCA Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-471 Check at least one PRZR PORV ISO - OPEN SRO The following will be passed off to the Shift Manager Perform the following within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> of start of event.
0 Close recirculation valve disconnects using A TT ACHMENT 1.
Establish 1A and 1B post LOCA containment hydrogen I
0 analyzers IN SERVICE USING ATTACHMENT 2, POST LOCA CONTAINMENT HYDROGEN ANALYZER OPERATION.
0 Plot hydrogen concentration on FIGURE 1.
0 Check containment hydrogen concentration - LESS THAN 3.5%.
0 Less than 0.5%
SRO Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 16°F {45°F} SUBCOOLED IN CETC MODE.
0 Check secondary heat sink available.
>395 gpm AFW flow
> 31 %{ 48%} SGNR level 0
Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13%{43%}.
Continue to stel! 8 since a known LOCA exists RO
[CA] Check containment spray system.
8.1 Check any CS PUMP - STARTED.
YES Reset containment spray signals.
CS RESET
[] A TRN
[] B TRN RO 9 [CA] Check ifLHSI Pumps should be stopped.
Check RCS pressure - GREATER THAN 275 psig{ 435 psig}
NO PT-402 AND 403
Alli!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 19 of29 Event
Description:
LB LOCA Establish CCW flow to RHR heat exchangers.
CCW TO 1AClB) RHR HX Q1P17MOV3185A open Q1P17MOV3185B open SRO I Evaluation point -
Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER.
Check RCS pressure on PT-402/403.
This differentiates between a steam break and an ReS leak SRO should direct the team to continue in EEP-1 and NOT return to step
- 1.
BOP I Perform Attachment 4 to Verify 4160 V busses energized.
Check DF01 closed - NO Verify DF02 closed - YES Check DG 15 closed - YES Verfiy DG02 closed - YES 1.6 Verify all RCP busses -
ENERGIZED.
[] 1A 4160 V bus
[] 1B 4160 V bus
[] 1C 4160 V bus
-NO
- YES
- YES Verify energized by 1-2A DG 1.7 Check IE 4160 V bus - ENERGIZED.
1.8 Check 1D 4160 V bus - ENERGIZED.
Establish power to lA 600 V LC emergency section loads.
YES NO o
Place handswitch for pressurizer heater group lA in OFF.
o Verify open BKR EA08-1.
o Verify closed BKRs ED08-1 and EA09-1.
o WHEN pressurizer heater group lA operation is desired, THEN place HTR GRP lA BLOCKING BYPASS SW to BYPASS.
o IF required, THEN manually energize pressurizer heater group 1A.
o Verify 1 C air compressor in 1.11 Align 1A air compressor.
service.
o Check INST AIR PRESS PI 4004B-GREATER THAN 85 psig o
Verify instrument air aligned to containment. (BOP)
~)
)
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 20 of29 Event
Description:
[] N1P19HV3825 open
[] N1P19HV3885 open IA TOCTMT
[] Q1P19HV3611 open BOP Check diesel generators.
[CAl Monitor any loaded diesel generator for proper voltage, frequency and load.
[CAl Secure any unloaded diesel generators using FNP-O-SOP-38.0,DIESEL GENERATORS.
This will be accomplished by the extra operator or the BOP if time permits. This is generally not the case and the DGs will continue to run.
SRO I This is a foldout page requirement and may be used any time the conditions are met.
Begin evaluation of plant status.
Verify cold leg recirculation 14.1 IF cold leg recirculation capability - AVAILABLE.
capability can NOT be 14.1.1 Train A equipment available:
RECIRCULATION D 1ARHRPump D CTMT SUMP TO lA RHR PUMP QIE11MOV8811A D CTMT SUMP TO 1A RHR PUMP QIE11MOV8812A D 1A RHR HX TO CHG PUMP SUCT QIE11MOV8706A D CCWTO lARHRHX Q1P17MOV3185A OR 14.1.2 Train B equipment available:
D IBRHRPump D CTMT SUMP TO 1B RHR PUMP QIE11MOV8811B D CTMT SUMP TO 1B RHR PUMP QIE11MOV8812B D 1B RHR HX TO CRG PUMP SUCT QIE11MOV8706B verified, THEN go to ECP-1.1, LOSS OF EMERGENCY COOLANT
A.I!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 21 of29 Event
Description:
LB LOCA o CCW TO 1B RHR HX QIP17MOV3185B SRO I These steps will be passed to the TSC by the SRO When RWST level is < 32 feet, lA RHR pump will trip and MOV 8811A breaker will have tripped when LB LOCA occurs.
RO I Verify ECCS pumps not affected by sump blockage
- Monitor ECCS pump suction conditions -
no indication of cavitation SRO I WHEN emergency coolant recirculation capability is restored, THEN go to procedure and step in effect.
RO I Will go to RNO step 3
- Continue attempts to restore at least one train of recirc equipment and go to step 4 BOP I - Verify SI - RESET
- Check PHASE B CTMT ISO - RESET.
- Verify containment spray signals - RESET.
RO I Reset containment sump to RHR valve switches.
BOP I Verify containment fan cooler alignment. All started in slow speed, associated emergency service water outlet valves open EMERG SW FROM 1A(1 S, 1 C, 1 D) CTMT CLR
[] Q1P16MOV3024A
[] Q1P16MOV3024S
[] Q1P16MOV3024C Q1 P16MOV3024D BOP Check RWST level greater than 4.5 feet YES RO I -
Check containment spray aligned to RWST Determine number of CTMT spray pump required based on table
AJll!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 22 of29 Event
Description:
LB LOCA Establish required number of CS pumps running 10.2 Determine number of containment spray pumps required based on the Table below.
(Validation: 2.5 psig in ctmt - ALL CS pumps were secured)
Rl,~ST CONTAINHENT FAN COOLERS SPRAY PUl'lPS LEVEL PRESSURE RUNNI.NG IN REQUIRED EHERGENCY HaDE GREATER THAN 54 PSIG 2
GREATER THAN BETWJEEN 0, 1
,'}
L.
12.5 FT 27 PSIG AND 54 PSIG 2, 3 1
i it 0
LESS THAN 27 PSIG 0
GREATER THAN 54 PSIG 2
BETWEEN BETWEEN
- 1. 2 1
4.5 FT 21 PSIG and 54 PSIG and 3
l
"+/-
0 12.5 liT LESS THAN 27 PSIG 0
LESS THAN 4.5 liT 0
~
... C.C7 -rr' Makeup to the RWST and minimize RWST outflow.
e Establish the required number of CS pumps running - probably none RO check status ofCS pump - any started, check CTMT sump level> {4.6}
aligned for recirc mode if sump level met sump suctions open, RWST suction isolations closed.
SRO Make up to the RWST as necessary using FNP-l-S0P-2.3 (SRO notifies SM, SSS, or TSC staff to perform this evolution)
)
A.l!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 6 Page 23 of29 Event
Description:
LB LOCA Makeup to the RWST and minimize RWST outflow.
When the direction to 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 has been made, then put in the next event below.
At this time restore power to MOV 8811B and report to SS that power is restored to MOV8811B Transition back to EEP-l at the step to check RWST level less than 12.5 feet, or to ESP-I.3 if RWST level is <12.5 feet END OF SCENARIO
Alill.endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 24 of29 Event
Description:
Attachment 2 and 4 ofEEP-O Cue: BOP will accomplish when at step 5 of EEP-O Time Position Applicant's Action or Behavior of EEP-O AUTOMATIC ACTIONS VERIFICATION I
1 Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (lA, lB or 1 C)
[] B train (lD,lE or IC) 2 Verify each train ofCCW - STARTED.
2.1 VerifY one CCW PUMP in each train-STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm B train HX lA or IB CCWFLOW
[] FI 3043AA > 0 gpm OR
[] FI 3043BA > 0 gpm VerifY SW flow to associated CCW HX's SW FROM lA(lB, lC) CCW HX
[] QIPI6F13009AA > 0 gpm
[] QIP16FI3009BA > 0 gpm
[] QIPI6FI3009CA > 0 gpm 3 Verify one CHG PUMP in each train - STARTED.
[] A train (lA or lB) amps> 0 BOP
[] B train (1 C or lB) amps> 0 BOP 4 Verify RHR PUMPs - STARTED.
RHRPUMP
[] lA amps> 0 Start lA RHR pump
[] lB amps> 0 BOP 5 Verify Safety Injection Flow.
5.1 Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 25 of29 Event
Description:
Attachment 2 and 4 of EEP-O BOP Check RCS pressure - LESS THAN 5.2 Proceed to Step 6.
275 psig{435 psig}.
BOP 6 Verify containment ventilation isolation.
6.1 Verify containment purge dampers - CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B 6.2 Verify containment mini purge dampers - CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D 6.3 Stop MINI PURGE SUPPIEXH FAN.
Will place HS to STOP BOP 7 Verify containment fan cooler alignment.
7.1 Verify at least one containment fan cooler per train - STARTED IN i
SLOW SPEED.
CTMT CLR FAN SLOW SPEED o A train Start 1A or 1B CTMT CLR FAN
[]IA
[]1B DB train
[]1C
[]1D 7.2 Verify associated emergency service water outlet valves -
OPEN.
EMERG SW FROM lA(1B,IC,lD) CTMT CLR
[] QIP16MOV3024A
[] QIP16MOV3024B
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 26 of29 Event
Description:
Attachment 2 and 4 ofEEP-O
[] QIP16MOV3024C
[] QIP16MOV3024D BOP 8 Verify AFW Pumps - STARTED.
8.1 VerifY both MDAFW Pumps - STARTED
[] lA MDAFW Pump amps> 0
[] IB MDAFW Pump amps> 0 AND
[] FI-3229A indicates> 0 gpm
[] FI-3229B indicates> 0 gpm
[] FI-3229C indicates> 0 gpm 8.2 Check TDAFW Pump start required.
DCondition DTSLB DSet,Roint DCoincidenceD RCPBus TSLB2 1-1 D2680 V 112 Detectors Undervoltage 1-2 1-3 on 2/3 Busses LowLowSG TSLB4 28%
2/3 Detectors I
Water Level 4-1,4-2,4-3 on 2/3 SGs In Any 5-1,5-2,5-3 213 SGs 6-1,6-2,6-3
)
BOP 8.3 Verify TDAFWP started.
[] MLB-41-3lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
8.4 VerifY TDAFW flow path to each SG.
[] QIN23HV3228A in MOD
[] QIN23HV3228B in MOD
[] QIN23HV3228C in MOD TDAFWP TO lA(lB,IC) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open BOP 9 Verify main feedwater status.
9.1 VerifY main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
Alll!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 27 of29 Event
Description:
Attachment 2 and 4 ofEEP-O
[] FCV 488
[] FCV 498 9.2 Verity both SGFPs - TRIPPED.
9.3 Verity SG blowdown - ISOLATED.
[] QIG24HV7614A closed
[] Q1G24HV7614B closed
[] QIG24HV7614C closed 9.4 Verity SG blow down sample - ISOLATED MLB lights lit.
lA(1B,IC) SGBD SAMPLE STEAM GEN ISO
[] MLBI 19-2 lit QIP15HV3328 closed
[] MLBI 19-3 lit QIP15HV3329 closed
[] MLBI 19-4 lit QIP15HV3330 closed BOP I 10 Check no main steam line isolation actuation signal present.
Signal Semoint 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 17-3,418-3,4 Lo-Lo Tavg
<543°F 2/3 TSLB2 10-1,2,3 HI-HI ctmt press> 16.2 psig 2/3 TSLB 1 2-2,3,4 11 Verify PHASE A CTMT ISO.
11.1 Verity PHASE A CTMT ISO - ACTUATED.
[] MLB-2 1-1 lit BOP I [] MLB-2 11-1 lit 11.2 Check all MLB-2 lights - LIT.
11.2 Verity PHASE A CTMT ISO alignment using ATTACH 3, PHASE A CTMT ISO BOP I 12 Check all reactor trip and 12 Perform the following.
reactor trip bypass breakers - OPEN. 12.1 Open reactor trip breaker(s) manually from MCB or locally.
Reactor trip breaker A 12.2 Record any breaker(s)
Reactor trip breaker B manually opened.
Reactor trip bypass breaker A Reactor trip bypass breaker B
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 28 of29 Event
Description:
Attachment 2 and 4 ofEEP-O BOP 13 Trip CRDM MG set supply breakers.
lA(IB) MG SET SUPP BKR
[] NICIIEOOSA
[] NICIIEOOSB BOP 14 Secure secondary components.
14.1 Stop both heater drain pumps.
HDP
[]1A
[]IB 14.2 Check any condensate pump started.
14.2.1 IF started, THEN stop all but one condensate pump.
[]1A
[]IB 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-O-SOP-O.O, APPENDIX B, TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY INJECTION.
Will call TBSO to accomplish this.
BOP 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 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KVBKR
[] 810 - OPEN
[] 914 - OPEN BOP 17 Verify two trains of ECCS equipment aligned.
17.1 Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICATION.
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 5 Event No.: 5 Page 29 of29 Event
Description:
Attachment 2 and 4 of EEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION BOP 1 Verify two trains ofECCS equipment aligned.
Check DFO 1 closed Verify DF02 closed Check DG 15 closed Verfiy DG02 closed Verify two trains of battery chargers - energized Amps> 0 I
1.6 Verify two trains of ESF equipment aligned.
Check all MLB-l lights LIT Verify charging pump suction and discharge valves - OPEN.
[] QIE21MOV8132A
[] QIE21MOV8132B
[] QIE21MOV8133A
[] QIE21MOV8133B CHG PUMP SUCTION HDR ISO
[] QIE21MOV8130A
[] QIE21MOV8130B
[] QIE21MOV8131A
[] QIE21MOV8131B 1.7 Verify all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[] lA
[] 1B
[]IC
[]ID RX CA V H2 DILUTION FAN
[] lA
[] IB 1.8 WHEN power restored to any deenergized emergency bus, THEN verify alignment of associated equipment.
BOP Call Radside SO to Verify Spent Fuel Pool Cooling in service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
End of Attachment 2 and 4
)
Scenario #6 2008 NRC exam Southern Nuclear J.M. Farley Nuclear Plant Operations Training Simulator Exam Scenario HLT-32 NRC EXAM SCENARIO #6 FA2008301 Technical Review:
GTOhmstede Date:
07-2008 Training Department Approval:
NRC approved Date:
10-2008 COMPANY to
AppendixD Scenario #6 Outline Form ES-D-l Facility: I Farley Nuclear Plant I I Scenario No.: I 6
I Op-TestNo.: I 2008-301 Examiners:
Operators:
SRO RO BOP Initial Conditions: 100% power. 855 ppm, MOL; B train on service, B Train protected Turnover:
1-2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs) 1 B EHC pump TIO for motor bearing replacement. (OOS 6 hrs, ETR 2 hrs)
- Current Risk Assessment is and projected is
!,J,
- It Train On-Service - B Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event Malf.No.
Event Type*
Event Description No.
1 C (BOP)
Load rejection 200 MW R(RO) 2 (I) (RO)
FT -122 fails high 3
C (BOP)
CST rupture - crane accident - will place SW on AFW suctions TS (SRO) 4 C(RO)
PK-444A fails high-Cnh / imf pk444a-d / 10/45 manual and auto portion will not work R(RO) 1 C SG tube leak - 15 gpm over 3 min and stabilizes 5
N(BOP)
Commence ramp off line TS (SRO) 6 M(ALL)
Loss of air - will cause a Rx trip to be called for 7
C (ALL)
Rx Trip will not work in auto or manual, and one CRDM MG set breaker will not open. FRP-S.l will be entered.
8 C(RO)
PORV fails open - can be isolated with MCB handswitch M(ALL)
Main Steam header break downstream ofMSIVs 9
C (BOP) 1 C SG MSIV s will not auto close M(ALL) 1 C SGTR 500 gpm when 1 C SG pressure drops to 600 psig or step 5 10 ofEEP-O (N)ormal, (R)eactivity, (l)nstrument, (C)omponent, (M)ajor
)
Farley Oct 2008 exam Seen 6 Page 2 of 11
Appendix D Scenario 6 detailed summary sheet Form ES-D-1 Initial Conditions: 100% power, MOL, 10,000 MWD, B Train OIS, B Train protected, RCS boron concentration is 855 ppm, and Eq. Xe (-2726 ppm)
Turnover:
1-2A DG TIO for governor work. (OOS 2 days, ETR 4 hrs) 1 B EHC pump TIO for motor"..,,~bii~~~~D
.... ~!!2!1,fJ replacement. (OOS 6 hrs, ETR 2 hrs)
Current Risk Assessment is __ and projected is
§.. Train On-Service - B Train Protected.
Thunderstorm warnings in effect for Southeast Alabama & Western Georgia Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event 7 Event 8 Event 9 Event 1Q End point Load rejection 200 MW, AOP-17 entry required.
FT-122 fails high - AOP-16 entry CST rupture - crane accident - will place SW on AFW suctions TS actions PK-444A fails high -will have to react to rising RCS pressure AOP-100 entry-manual control of RCS pressure 1 C SG tube leak - 15 gpm over 3 min and stabilizes Commence ramp off line - need to make this a high enough leak to be at 50% in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and mode 3 in 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
Loss of air - will cause a Rx trip to be called for AOP-6 entry Rx Trip will not work. Drive rods in the fastest mode possible. Establish emergency boration(CT)
PORV fails open - can be isolated with MCB handswitch (CT)
Main Steam header break - 1 C MSIVs will not auto close FRP-S.1, EEP-O.O or EEP-2.0 entered to isolate the faulted SG.
1 C SG isolated in EEP-O, EEP-2 or FRP-S.1. (CT)
SGTR 500 gpm when 1 C SG pressure decreases to 600 psig (or at step 5 of EEP-O)
EEP-3 entered and feed is isolated per EEP-3 for these conditions. (CT)
When SGs are at the desired cooldown temperature and RCS cooldown has been stopped.
Or after step 17 when RCS depressurization is completed.
Farley Oet 2008 exam Seen 6 Page 9 of 11
Appendix 0 Scenario 6 detailed summary sheet Form ES-O-1 CRITICAL TASK SHEET 1. Rx Trip will not work.
Enter FRP-S.1 and shutdown reactor.
Drive rods in the fastest mode possible. Establish emergency boration (WOG CT E-O - - M)
- 2.
Close PORV with MCB handswitch at or before EEP-O step 10.1, "Check pressurizer PORVs and spray valves [closed]".
- 3.
Isolate the faulted steam header prior to transition out of EEP-2:
- 4.
Identify and isolate flow to/from the ruptured steam generator before a transition to ECP-3.1 occurs or prior to commencing RCS cooldown.
(PRA - NR:6)
SCENARIO OBJECTIVE!
OVERVIEW:
The team should be able to:
Respond to a failed equipment and instruments and complete the appropriate ARPs, AOP-100, AOP-16 AOP-2.0 and AOP-6.0 &
Tech Specs Respond to a loss of air and then an ATWT event when the reactor will not trip, then isolate a failed open PORV.
The crew will have to evaluate a faulted SG while in FRP-S.1 and then react to a SGTR after entering EEP-O on the same faulted SG.
Farley Oet 2008 exam Seen 6 Page 10 of 11
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 1 Page 1 of36 Event
Description:
200 MW load rejection Cue: By Examiner.
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of200 MW load rejection
- Rapid Auto Rod Insertion
- Steam Dumps armed and opened
- Rapid change in SGFP suction pressure
- TAVG TREF mismatch greater than 5°F
- SG level deviation alarms
- Rapid change in SGFP suction pressure If the BOP takes the DEH to Turb manual then the load rejection will not be as severe.
Team I Recognize load rejection and enter AOP-17 RO I Takes manual control of rods (if desired)
BOP I Verify turbine valve position stable Display the VALVE TEST page and determine valve positions RO I Stabilize TAVG by adjusting rod position and/or boron Using rod control or SOP-2.3 - manual boration Position the MKUP MODE CONT SWITCH to STOP.
Position the MKUP MODE SEL SWITCH to BOR.
Position the MKUP MODE CONT SWITCH to START.
Verify proper boration operation by observing the following:
- On service boric acid pump started.
- MKUP TO CHG PUMP SUCTION HDR FCVI13B opens.
- BORIC ACID TO BLENDER FCVI13A opens.
- Boric acid flow is displayed on PI -113 VerifY the boration automatically stops when the boric acid batch integrator reaches its setpoint as follows:
- Boric acid flow returns to zero as displayed on FI-I13
- MKUP TO CHG PUMP SUCTION HDR FCV113B closes.
- BORIC ACID TO BLENDER FCVI13A closes.
Alli!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 1 Page 2 of36 Event
Description:
200 MW load rejection BOP Check steam generator narrow range levels trending to or maintained at 65%
RO Check pressurizer level trending to or maintained on program If HIGH-then start additional heaters and verify Przr level returns to the expected level as Tavg approaches Tref Or If LOW-Adjust LK459F to obtain desired level RO Check pressurizer pressure maintained approximately equal to 2235 psig If not then start additional heaters or control spray flow using PK444C PK444D SRO Check parameters within limits for continued at power operation
- Pressurizer level greater than 15%
- Pressurizer pressure greater than 2100 psig
- SG narrow range levels 35%-75%
- TAVG 541°F - 580°F
- Control rod bank position Lo-Lo Annunciator FE2 Clear
- Delta I within limits specified in the COLR If NOT - then trip the reactor RO Restore TAVG to programmed value Maintain Delta I within limits specified in the COLR during restoration ofTAVG IF Delta I low, THEN borate RCS to allow control rods to be withdrawn.
- IF Delta I high, THEN dilute to support inward rod motion.
Adjust rod position and/or boron concentration to restore TAVG to programmed value BOP WHEN the steam dump valves have automatically closed AND plant conditions are stabilized, THEN reset the LOSS-OF-LOAD INTERLOCK C-7 A 0
Check STM DUMP DEMAND TI408 indicating 0% demand 0
Place the STM DUMP MODE SEL TRAINS A-B to RESET and spring return to T A VG
Aill!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 1 Page 3 of36 Event
Description:
200 MW load rejection SRO NotifY the Shift Radiochemist of any significant changes in plant load and to sample Res per FNP-l-STP-746 ifRx Power changes by > 15%
of rated thermal power within a 1 hr. period. (T.S. surveillance requirement SR 3.4.16.2)
SRO Address Tech specs - ReS pressure <2209 psig 3.4.1 condition A restore DNB w/I 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> (ReS pressure will recover in 1-2 minutes)
SRO 0
Submit a Condition Report and notify the Work Week Coordinator (Maintenance A TL on backshifts) 0 Notify the Shift Manager GO to event 2 when AOP-17 is complete End Event #1
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 2 Page 4 of36 Event
Description:
FT-122 fails high Cue: By Examiner.
Time Position AJ plicant's Action or Behavior Annunciators:
Recognize indications of FT -122 FAILING CHG HDR FLOW HI-LO (EA2)
HIGH REGEN HX LTDN FLOW DISCH FT -122 will indicate> 150 gpm (pegged TEMP HI (DEl) high)
SEAL WTR IN] FLTR HI DP (DC4)
VCT level will increase PRZR PRESS REL VL V 445A OR Przr level will decrease BIU HTRS ON (HD 1)
FK-122 demand will go to 0 LK-459F will increase Actual valve position will close down and cause the above indications.
SRO Determine a charging system malfunction is occurring and direct entry into AOP-16.
)
RO Monitor VCT level Observe CHG HDR PRESS and MOTOR AMPS to ensure proper charging pump operation PI -121 and ammeter for chg pump Actual amps will be lower than normal RO Check charging pump - RUNNING YES RO Check Charging flow FK-122 controlling in AUTO with flow indicated There will be flow indicated and 122 in AUTO - Seal inj flow will increase due to FCV122 going closed.
The answer to this question should be NO and 122 taken to manual control -RNO An incorrect determination here will cause the crew to place 122 on the bypass.
RO Check DE3 clear YES Check Letdown on service YES RO Determine Charging Status Check charging - AFFECTED BY MALFUNCTION NO With 122 in manual the condition is cleared
AJillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 2 Page 5 of36 Event
Description:
FT-122 fails high SRO 0
Submit a Condition Report and notify the Work Week Coordinator (Maintenance A TL on backshifts) 0 Notify the Shift Manager Go to event 3 when FCV -122 is in manual and Przr level is being controlled. The next event takes approx. 4 minutes to ramp in.
End Event #2
)
AJmendixD Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 3 Page 6 of36 Event
Description:
CST rupture Cue: By Examiner.
Time Position Ar plicant's Action or Behavior Annunciators:
Recognize indications of CST LEVEL CST L VL HI-LO (JE5)
DROPPING CST L VL LO-LO A TRN and B TRN (JD4 LI-4005 B decreasing and JE4)
Computer alarms CST level will decrease over a 5 min 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.
150,000 gallons = 12 feet SRO Direct ARP reference (JE5) and a call to the DBSO to look for problems.
BOP Direct DBSO to commence filling the tank (Unless report of rupture has come in)
SRO Make a decision to do the following:
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.
With no ramp down in progress, this will be a hard decision to make.
SRO Monitor condensate storage tank level on LI-4005B, LI-4132A and LI-4132B to verify validity of alarm Direct BOP to monitor this issue SRO Evaluate Tech Specs 3.7.6 condition A Verify by administrative means OPERABLILITY of backup water i
supply wlI 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> and restore the CST to OPERABLE status wlI 7 days.
Since there is no ramp in progress there is no urgency to place the AFW system on the service water system. However, since the CST is empty, a prudent decision to align it to the SW system should be made to protect the AFW pumps in the event of an autostart signal.
SOP-22 will be used to place SW as the suction to AFW. Section 4.7
)
Allliendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 3 Page 7 of36 Event
Description:
CST rupture If the crew decides not to place SW on the AFW suction at this time, consider going to the next event when the crew will be required to ramp and then this will be critical.
BOP I -
Obtain the required keys from the key locker SRO END-Event 3 Notify shift chemist of decision to align SW to the AFW suctions.
Verify SW is in service On the BOP open the following valves:
Open MDAFWP SW SUPP: (BOP key operated switches)
- QIN23MOV3209A
- QIN23MOV3209B Open: (BOP)
- TDAFWP SW SUPP QIN23MOV3216.
o Submit a Condition Report and notify the Work Week Coordinator (Maintenance ATL on backshifts) o Notify the Shift Manager
Alill.endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 4 Page 8 of36 Event
Description:
PK-444A fails high Cue: By Examiner.
I Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of PK -444A FAILING PRZR PRESS REL 445A OR B/U HTRS HIGH ON (HDI)
PK-444A demand rising PRZR L VL DEV LO (HB2)
All BU Htrs ON PRZR HTR CONT TRBL (HD4)
RCS pressure rising CHG HDR FLOW HI-LO (EA2)
PK-444A will go to 100% demand and all heaters will be ON. Actual pressure will increase, but the sprays and heaters and PORV444B will not respond. Ifmanual control of individual components is not taken, PORV445A will open. Manual control ofPK-444A is not possible due to the failure.
AOP-IOO Section 1.1 SRO Direct entry into AOP-100.
RO Verify RCS pressure is stable.
NO Take manual control of the PK-444A.
NO Take manual control of the spray valves and heaters and control pressure SRO Check RCS pressure stable or rising YES Set control band for RCS pressure.
2220-2250 psig SRO Notify the Shift Manager SRO Submit a Condition Report and notify the Work Week Coordinator (Maintenance A TL on backshifts End event 4
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 5 Page 9 of36 Event
Description:
SOT leak of 15 gpm Cue: By Examiner.
Time Position AI plicant's Action or Behavior Annunciators:
Recognize indications of SG TUBE LEAK SG TUBE LEAK ABOVE SETPT (FG 1)
R-15, 19 AND 23 IN ALARM RMS HI RAD (PHI)
R-70C READING> 1000 GPD SGBD PROC PNL TRBL (JB5)
FG 1 and FHl actions BOP Reference ARP and check R-70s to determine SG in alarm.
SRO Notify Chemistry of the alarm condition Direct entry into AOP-2 BOP Check ARP FHl for actions as Rad monitors come into alarm.
Do not allow personnel to enter the affected area without the approval of the Health Physics Department.
SRO IF R-15 alarms AND remains above the alarm setpoint (not a momentary spike), THEN perform the following:
IF high effluent activity is possible, THEN implement EIP-9.0, ACTIONS.
Call SM Notify the Counting Room to immediately sample the SGs per CCP-31 to determine the leak rate.
Notify the Operations Shift Manager.
IF R-19 alarms refer to SOP-4S.0 for guidance in sampling SGs with R-19 in alarm.
IF R-23A OR R-23B alarms contact the RAD man to verify SGBD secured.
SRO Direct entry and actions of AOP-2.0 RO Maintain pressurizer level stable at normal programmed value by:
Control charging FK-122 adjusted as required Reduce letdown close one or more orifice isol. Valves
A.I!I!.endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 5 Page 10 of36 Event
Description:
SGT leak of 15 gpm RO I Maintain VCT level greater than 20%. by:
VerifY RMW system in AUTO OR Manually control makeup as required by using SOP-2.3 BOP I Check that the Continuous Radiation Monitoring System is operable SRO BOP Either R OPERABLE OR R-70s-OPERABLE YES Check reactor power conditions:
Check NO power ascension in progress Check NO power reduction in progress Check reactor power greater than 20%
YES to all Monitor primary to secondary leakage Check R-70s or R-15 for increasing count rate Begin trending R-70C and R-15 using the plant computer and Data sheet 1.
YES BOP I Call TBSO to place SJAE filtration on service.
SRO I -
Direct chemistry to perform grab samples and leak rate determinations.
CCP-201 Table 55 Notify SM ofleak rate Evaluate Step 10 table to determine appropriate response:
ACTION LEVEL 4
~30 gpdlhr rate of increase AND ~75 gpd leak in any SG Step 11 actions:
Check any two of the following rad monitors trending in the same direction:
R-70sIR-15 ORR-70sIR-23A(B) OR R-15IR-23A(B) trending in the same direction with the same order of magnitude SRO I -
Direct reducing power to :'S 50% rated thermal power within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and place the Unit in Mode 3 within the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />. (3 hrs total)
IdentifY the correct leaking SG lCSG Using R-70s, R-60s and level rise in any SG
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 5 Page 11 of36 Event
Description:
SGT leak of 15 gpm BOP Commence the ramp to <50% power in the next I hour Calculates ramp speed WILL be in TURB MAN for ramp SRO Call SM to evaluate emergency classifications Evaluates Tech Specs 3.4.13 mandatory LCO RCS operational LEAKAGE shall be limited to:
- d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).
Condition B-be in mode 3 in 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
BOP Direct Chemistry to monitor the turbine building sump for activity Verify affected SG(s) atmospheric relief valve-ALIGNED Check affected SG atmospheric relief valve - CLOSED Isolate steam supply from affected SG(s) to TDAFWP from IC SG by directing ROVER to do the following:
Establish LOCAL control from HSD Panel AND Isolate TDAFWP steam supply from I C SG by taking HV3235B in LOCAL and then to STOP BOP Verify SGBD isolated from the lC SG-7614C closed Check AS supplied from Unit 2 NO Call SSS to align AS Go to next event when the ramp is sufficient or when the actions of AOP-2 complete.
END-Event 5
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 6 Page 12 of36 Event
Description:
Loss of Instrument AIR Cue: By Examiner.
Time Position Applicant's Action or Behavior Annunciators:
Recognize indications of LOSS OF IA IA PRESS LO (KD2)
PI4001 A and B dropping SA PRESS LO (KD3)
Various valve and indication erratic Eventually SGWLs will be affected lA, IB, IC SG L VL DEV (JF1I2/3) lA, lB, IC SG STM FLOW> FEED FLOW (JB 112/3)
This loss of IA is placed such that SA will isolate, and Essential air to the TB will isolate and IA to the Penetration rooms and ctmt will be unaffected. This will cause FRVs to lose air and go closed. This will prompt a reactor trip.
SRO Notice loss of air and check IA compressors running and Direct entry to AOP-6 BOP Direct TBSO to locate and isolate leaks in air header.
IF the reactor is tripped due to a loss of instrument air, THEN the actions of this procedure should be implemented in conjunction with ESP-O.l, REACTOR TRIP
RESPONSE
SRO Direct Reactor trip when the FRVs and other indications start becoming erratic.
BOP Start any available air compressor SRO Direct Reactor trip END-Event 6
)
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 13 of 36 Event
Description:
FRP-S.l entry, isolation of PORV that is failed open and MSIV closure due to steam header rupture.
Cue: Preset Time Position AT plicant's Action or Behavior Annunciators:
Recognize indications of A TWT event Various and many RTBs still closed Nis indicate full power Conditions warrant a reactor trip and one is not received When the crew tries to trip the reactor the reactor trip breaker will not open and the CRDM MG set breakers will not open. PORV 445A will stick open when it does open, MS header will be faulted when AFW flow increases and 1 C SG will rupture when 1 C SG drops to 600 psig or at step 5 ofEEP-O.
SRO Direct entry into EEP-O - IOAs RO/BOP Immediate Operator actions of EEP-O Check reactor trip.
Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
TRIP CRDM MG set supply breakers.
lA(lB) MG SET SUPP BKR
[] NlCllE005A
[] NlCllE005B Reactor is not tripped by RTBs or CRDM MG sets.
SRO Direct entry into FRP S.l and complete IOAs.
RO IF reactor still NOT tripped, THEN perform the following:
Insert control rods in manual control.
OR Verify rods insert in AUTO at greater than 48 steps per minute.
Dispatch an operator to locally trip the reactor trip and bypass breakers.
3 minutes from this phone call RTBs will be opened from BOOTH BOP Check Main Turbine tripped I
I I
I
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 14 of36 Event
Description:
FRP-S.1 entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
Place MAIN TURB EMERG TRIP switch to TRIP for at least 5 seconds.
BOP I Verify AFW pumps running Both MDAFWPs amps> 0 TDAFWP speed> 3900 rpm RO I Initiate Emergency Boration of the RCS.
Verify at least one CHG PUMP - RUNNING.
Start a BAT pump Open MOV 8104 Establish normalletdwn flow - 8149A and either 8149B or Copen Check RCS pressure less than 2335 psig Establish normal charging flow> 40 gpm Verify adequate emergency boration flow of> 30 gpm on FI-II0 BOP I Verify containment ventilation isolation.
Verify containment purge dampers - CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B Verify containment mini purge dampers - CLOSED.
CTMT PURGE DMPRS MINI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MINI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D Stop MINI PURGE SUPP/EXH FAN.
Will place HS to STOP BOP I Check SI actuated ~
complete attachment 1 See attached sheets for Attachment 1 of FRP-S.l RO I -
Check ALL RTBs open Check Main Turbine tripped
Alll!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 15 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
RO I [CA] Check if reactor still critical.
If RTBs are open or power range indication is < 5% power OR IR SUR is negative, then go to EEP-O step 1 If not continue in this procedure.
ROIBOP I Immediate Operator actions ofEEP-O Check reactor trip.
Check all reactor trip breakers and reactor trip bypass breakers - OPEN.
Check nuclear power - FALLING.
check rod bottom lights - LIT.
Check turbine - TRIPPED.
TSLB2 14-1 thru 4 lit Check power to 4160 V ESF busses.
4160 V ESF busses - AT LEAST ONE ENERGIZED 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.
Check SI Status.
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-l 1-1 lit
[] MLB-l 11-1 lit If YES will continue IN EEP-O step 5 IF NO then will go to ESP-0.1 THE SGTR will be put in at this point SRO I Directs continuing into EEP-O at step 5.
Directs the BOP to do attachment 2.
YES See Tab at end of scenario Attachment 2 and 4 for actions
)
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 16 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
6 [CAl Check containment pressure-HAS RO REMAINED LESS THAN 27 psig YES RO 7 Announce "Unit 1 reactor trip and safety injection".
8.1 Check secondary heat sink Available 0
Check total AFW flow> 395 gpm
[] FI 3229A
[] FI 3229B
[] FI 3229C 0
Total Flow FI 3229 OR Check any SG NR level> 31 % {48%}
8.2 WHEN all SG narrow range levels less than 31 %{ 48%},
THEN maintain total AFW flow greater than 395 gpm.
8.3 WHEN at least two SG narrow range levels greater than 28%
AND TDAFWP NOT required, THEN stop TDAFWP.
8.4 [CA] WHEN SG narrow range level greater than 31 %{ 48%},
THEN maintain SG narrow range level 31 %-65%{ 48%-65%}.
8.4.1 Control MDAFWP flow.
[] A TRN reset
[] B TRN reset MDAFWP TO IA/lBIlC SG BTRN
[] FCV 3227 in MOD 8.4.2 Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO 9 Check RCS temperature.
IF any RCP running, THEN check RCS average temperature - STABLE AT OR APPROACHING 547°F.
[] TI 412D
[] TI 422D
[] TI 432D I
I
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 17 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
RO I RNO RO IF RCS temperature less than 547°F and falling, THEN perform the following.
9.1.1 Verify steam dumps closed.
STM DUMP INTERLOCK
[] A TRN in OFF RESET
[] B TRN in OFF RESET Verify atmospheric reliefs closed on MCB Demand at 0 and minimum red light LIT Control total AFW flow to minimize RCS cool down, AFWFLOWTO lA(lB,IC) SG
[] FI 3229A
[] FI 3229B
[] FI 3229C AFW TOTAL FLOW
[] FI 3229 IF MSIVs are open, THEN isolate steam loads in the turbine building Call TBSO to isolate steam loads IF cooldown continues, THEN close MSIVs and MSIV bypass valves.
Verify ALL MSIVs closed IF main steam lines isolated AND gland steam supplied from Unit 1, THEN break condenser vacuum.
Call TBSO to open COND V AC BKR MAN ISO if PORV still open Close MOV8000A 10.1.2 Check PRZR PORV temperature STABLE OR FALLING.
[] PORV Temp TI-463 10.1.3 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 18 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
[] PRT TEMP TI-471 10.2 [CA] WHEN pressurizer pressure 10.2 Stop lA AND 1B RCPs less than 2260 psig, to stop spray flow.
THEN verify normal pressurizer spray valves closed OR in the process of closing.
[] PK 444C
[] PK 444D 10.3 Check any PRZR PORV ISO - OPEN RO 11 Check RCP criteria.
11.1 Check SUB COOLED MARGIN 11.1 IF HHSI flow greater than MONITOR indication - GREATER o gpm, THEN stop THAN 16°F {45°F} SUBCOOLED IN all RCPs.
CETCMODE RO 12 Monitor charging pump miniflow criteria.
12.1 Control charging pump miniflow valves based on RCS pressure.
[] PI 402A
[] PI 403A Based on RCS pressure, close miniflows < 1300 and open when> 1900 psig.
I I I
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 19 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
Diagnostics The SRO will direct the parameters to be reviewed and will determine appropriate procedure to transition to.
SRO I 13 Check SGs not faulted.
o Check no SG pressure - FALLING IN AN UNCONTROLLED MANNER OR LESS THAN SO psig.
SRO I 14 Check SGs not ruptured.
o Check secondary radiation indication - NORMAL.
Checks rad monitors R-lS, 19, 23A and B, lSB and C, and 60 A, B, C, D o
No SG level rising in an uncontrolled manner.
If IC MSIV is stili open here then EEP-2 would be the procedure to transition to.
BOP EEP-2 below Verify aU main steam isolation and bypass valves - CLOSED.
Place handswitches for all MSIVs to the CLOSED position (6 total)
SRO I Check if any SG not faulted.
2.1 Check pressure in at least one SG - STABLE OR RISING.
Only 1D SG will be blowing down Identify the faulted SG IBSG BOP I Isolate all faulted SGs.
o Verify ALL ARVs closed-PC3371A, D, C minimum demand o
Verify ALL Feed stop valves closed MOV3232A, D, C o
Verify blowdown from all faulted SGs - ISOLATED.
HV 7614A, D, C o
Isolate TDAFWP steam supply from 1B SG.
The TDAFW pump should not be required.
This will be called to the booth to be completed by the extra operator 4.S.1 IF TDAFWP NOT required, THEN isolate TDAFWP steam supply from IB SG at HSD panel.
[] QIN12HV323SA/26 in LOCAL (HSDP-F)
)
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 20 of36 Event
Description:
FRP-S.l entry, isolation ofPORV that is failed open and MSIV closure due to steam header rupture.
[] Q1N12HV3235A/26 to STOP (HSDP-D)
BOP 4.6 Verify SG blowdown sample ISOLATED MLB lights lit.
[] MLBI 19-2 lit Q1P15HV3328 closed
[] MLB1 19-3 lit Q1P15HV3329 closed
[] MLB1 19-4 lit Q1P15HV3330 closed BOP 5 Isolate AFW flow to all faulted SGs.
5.1 Close MDAFWP isolation valves to all faulted SGs. (BOP)
Closes MOV3764D and B on the BOP RO Close TDAFWP flow control valves to all faulted SGs.
TDAFWP FCV 3228
[] RESET reset Close HV3228B pot to 0 SRO Call to SSS-P or TSC to have Q1N23V017B closed in the MSVR BOP Check CST level greater than 5.3 feet Check secondary radiation indication - NORMAL.
NO Checks rad monitors R-15, 19, 23A and B, 15B and C, and 60 A, B, C, D 1 C SGWL will be rising SRO Direct transition to EEP-3, STEAM GENERATOR TUBE RUPTURE.
End of event 7/8/9
)
Al!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 21 of36 Event
Description:
1 C SGTR 500 gpm Cue:preset or at step 5 ofEEP 0 Time Position I Aoolicant's Action or Behavior Annunciators:
II Recognize indications of SGTR Rad monitors in alarm Przr level falling rapidly RCS pressure dropping rapidly EEP-3, SGTR.
BOP SROIRO Check SUB COOLED MARGIN MONITOR indication - GREATER THAN 16°F{45°F} SUB COOLED INCETC MODE.
YES
[CA] Identify ruptured SG(s).
Check any SG level - RISING IN AN UNCONTROLLED MANNER YES-lC
[CA] WHEN ruptured SG(s) identified, THEN isolate flow from ruptured SG(s).
Verify ruptured SG(s) atmospheric relief valve - ALIGNED.
PC3371C set 8.25 and in auto Verify 3371C is closed YES Isolate steam supply from ruptured SG(s) to TDAFWP:
- Direct counting room to performCCP-645, MAIN STEAM ABNORMAL ENVIRONMENTAL RELEASE.
- Check at least one MDAFWP running AND no TDAFWP auto start signals present.
YES one MDAFWP running and no auto start signals in
- Stop the TDAFWP from the main control board.
TDAFWP STM SUPP FROM 1B(1 C) SG
[] QIN12HV3235A/26 stopped
[] QIN12HV3235B stopped TDAFW SPEED CONT rl SIC 3405 at 0%
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 22 of36 Event
Description:
1 C SGTR 500 gpm Check TDAFWP steam supply valves closed.
TDAFWP STM SUPP FROM IB(1C) SG
[] MLB-4 1-3 not lit
[] MLB-4 2-3 not lit
[] MLB-4 3-3 not lit VerifY blowdown from ruptured SG(s) - ISOLATED.
Closes 7614C VerifY at least one SG MSIV on IC SG closed Verifies MSIV 3369C or 3370C closed and bypass valves closed BOP rCA] WHEN ruptured SG(s) NR level greater than 31 % THEN perform the following:
[CA] Isolate AFW flow to ruptured SG(s) using FCVs.
FCV 3227C in MOD, and closed YES HV 3328C in MOD and closed YES SRO Check ruptured SG(s) pressure GREATER THAN 250 psig.
YES SRO Evaluate performing an RCS cool down.
Determine required CETCs for cool down based on ruptured SG pressure.
AJll!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 23 of36 Event
Description:
1 C SOTR 500 gpm REQUIRED TEMPERATURE 1
- 1 1
1
- 1050 1
850 751 -
251 -
250 (522°F)
{51 F}
{50°F]
lFI I
F}
{
iF}
(484° F)
I F}
(
F)
FJ SRO I Direct the ST A to Display the hottest CETC page 1 TC 1 on plant computer.
This is normally selected by the ST A and put on the control board display.
SRO I Will direct these steps:
The Steam Dumps are not available so the following applies:
Dump steam to atmosphere.
Direct counting room to perform CCP-645.
Dump steam at the maximum attainable rate from INTACT SGs lA(1B,lC) MS ATMOS REL VLV
[] PC 3371A adjusted
[] PC 337lB adjusted StoD the cooldown when the hottest CETC temDerature is less than the
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 24 of36 Event
Description:
1 C SGTR 500 gpm required temperature and then maintain CETCs at the required Temp.
Check any intact SG narrow range level -
YES 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.
[] A TRN reset
[] B TRN reset MDAFWP TO lA/IBIl C SG BTRN
[] FCV 3227 in MOD Control TDAFWP flow.
TDAFWP FCV 3228
[] RESET reset TDAFWP SPEED CONT
[] SIC 3405 adjusted RO 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 TI-463 Check PRT parameters STABLE or FALLING.
[] PRT LVL LI-470
[] PRT TEMP TI-47l Check at least one PRZR POR V ISO - OPEN
AI!l!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page2S of36 Event
Description:
1 C SGTR 500 gpm NOTE: The purpose of the above step is to establish an available PORV flowpath for SGTR mitigation. A failed open PORV must not be unisolated. A leaking PORV which is isolated with power available to the isolation valve should remain isolated until needed for RCS pressure reduction. Any leaking PORV should be re-isolated when not in use.
MLB-l 1-1 not lit (A TRN) and MLB-l 11-1 not lit (B TRN)
Verify PHASE A CTMT ISO - RESET.
MLB-2 1-1 not lit and MLB-2 11-1 not lit BOP I Check PHASE B CTMT ISO - RESET. - NO ctmt pressure increase RO I IF instrument air available, THEN establish instrument air to containment.
VerifY at least one air compressor started.
AIR COMPRESSOR
[JIA
[JIB
[]IC Check INST AIR PRESS PI 4004B greater than 85 psig.
Check instrument air to containment.
IA TOCTMT
[J MLB-3 1-2 NOT lit IA TO PENE RM PRESS LO
[J Annunciator KD 1 clear RO I [9 [CA] Check if LHSI Pumps should be stopped.
YES Check RCS pressure - GREATER THAN 275 psig{435 psig}
YES PT -402 AND 403 Check RCS pressure - STABLE OR RISING YES VerifY the SI reset Secure any running RHR pumps Take HS to stop.
SRO I Check if Cooldown should be stopped.
Check hottest core exit TICs - LESS THAN REQUIRED Temperature.
Stop RCS cool down Maintain core exit TICs - LESS THAN REQUIRED TEMPERATURE.
RNO
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 26 of36 Event
Description:
Ie SGTR 500 gpm Do NOT proceed until hottest core exit TICs - LESS THAN REQUIRED TEMPERA TURE.
SRO 0
Check ruptured SG(s) pressure - STABLE OR RISING.
o Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 36°F{65°F} SUBCOOLED IN CETC MODE.
YES for BOTH NOTE: Normal pressurizer spray may become ineffective during pressure reduction. This situation justifies using a PRZR PORV per step 18.
RO I Reduce RCS pressure to minimize break flow and refill pressurizer.
Open all available normal pressurizer spray valves.
[] PK 444C
[] PK 444D Reduce RCS pressure using ONE pressurizer POR V to minimize break flow and refill pressurizer.
DO NOT USE PORV-445A TO DO THE DE-PRESSURIZATION PER NOTE IN EEP-3.
One PORV may be used to increase the pressure reduction and will probably be the case.
SRO I Reduce RCS pressure until one of the following three conditions occurs, then stop RCS pressure reduction.
RCS pressure less than ruptured SO pressure AND pressurizer level greater than 13%{ 43%}
OR Pressurizer level greater than 73%{ 66%}
OR SCMM indication less than 16°F{45°F} subcooled in CETC mode.
Then verify the sprays and PORVs are closed.
SRO I Check RCS pressure - RISING.
PI-402 and 403 rising
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 10 Page 27 of36 Event
Description:
1 C SGTR 500 gpm Evaluate SI termination criteria 0
Check SUB COOLED MARGIN MONITOR indication -
GREATER THAN 16°F {45°F} SUBCOOLED IN CETC MODE.
0 Check secondary heat sink available.
>395 gpm AFW flow
> 31 %{ 48%} SGNR level 0
Check RCS pressure - STABLE OR RISING 0
Check pressurizer level GREATER THAN 13%{ 43%}.
Suggested END OF SCENARIO This scenario can be terminated any time the NRC examiner deems enough actions have been taken.
AIillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 28 of36 Event
Description:
Attachment 1 ofFRP-S.l Cue:as directed by procedure Time Position Applicant's Action or Behavior of FRP-S.l AUTOMATIC SAFETY INJECTION VERIFICATION BOP 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 SWpump.
Check SI Status.
NO
)
Check any SI actuated indication.
BYP & PERMISSIVE SAFETY INJECTION
[] ACTUATED status light lit
[] MLB-l 1-1 lit
[] MLB-l 11-1 lit BOP Verify MFW status Verify main FRVs and bypass valves - valves CLOSED.
[] FCV 478
[] FCV 488
[] FCV 498 Verify both SGFPs - TRIPPED.
Verify SGBD isolated - HV 7614A, B C - closed Verify SGBD sample valves closed by MLB-4 6-4, 7-4 and 8-4 LIT Verify Phase A actuated-MLB-2 1-1 and 11-1 Lit all MLB-2lights LIT BOP Verify one CHG PUMP in each train - STARTED.
[] A train (lA or lB) amps> 0
[] B train (IC or IB) amps> 0 BOP Verify RHR PUMPs - STARTED.
RHRPUMP
AJill.endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Page 29 of36 Event
Description:
Attachment 1 ofFRP-S.l
[J IA amps> 0
[J 1B amps> 0 Verify each train ofCCW - STARTED.
BOP Verify one CCW PUMP in each train-STARTED.
[J FI 3043CA > 0 gpm OR
[J FI 3043BA > 0 gpm B train HX IA or 1B CCWFLOW
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's SW FROM IA(lB, IC) CCW HX
[J QIPI6FI3009AA > 0 gpm
[] QIPI6FI3009BA > 0 gpm
[] QIPI6FI3009CA > 0 gpm Verify each SW train - HAS TWO SW PUMPs STARTED.
[] A train (lA,IB or IC)
BOP Verify containment fan cooler alignment.
Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED D A train
[]IA
[J1B DB train
[JIC
[]ID Verify associated emergency service water outlet valves - OPEN.
EMERG SW FROM IA(lB,IC,ID) CTMT CLR
[] QIPI6MOV3024A
[] QIPI6MOV3024B
[] QIPI6MOV3024C
[J QIPI6MOV3024D
)
Aill!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 7/8/9 Event
Description:
Attachment 1 ofFRP-S.l Page 30 of36 BOP Check no main steam line isolation actuation signal present.
if Steam header fault still in and this attachment is being done If a MSLI signal is present then close ALL MSIV s BOP Check containment pressure -HAS REMAINED LESS THAN 27 psig.
End of attachment 1 of FRP-S.1
Alillendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 31 of36 Event
Description:
Attachment 2 and 4 ofEEP-O Cue: BOP will accomplish when at step 5 of EEP-O Time Position Applicant's Action or Behavior of EEP-O AUTOMATIC ACTIONS VERIFICATION 1 Verity each SW train - HAS TWO SW PUMPs STARTED.
[] A train (lA,lB or IC)
[] B train (lD,lE or IC) 2 Verity each train ofCCW - STARTED.
2.1 Verify one CCW PUMP in each train-STARTED.
[] FI 3043CA > 0 gpm OR
[] FI 3043BA > 0 gpm I
[] FI 3043AA > 0 gpm I
[] FI 3043BA > 0 gpm Verify SW flow to associated CCW HX's i
[] QIPI6FI3009AA > 0 gpm
[] QIPI6FI3009BA > 0 gpm
[] QIPI6FI3009CA > 0 gpm Verity one CRG PUMP in each train - STARTED.
[] A train (lA or IB) amps> 0 Start 1A or 1B CRG pump
[] B train (IC or lB) amps> 0 Start 1C Chg pump BOP Verity RHR PUMPs - STARTED.
RHRPUMP
[] IA amps> 0
[] IB amps> 0 BOP Verity Safety Injection Flow.
Check HHSI flow - GREATER THAN 0 gpm.
[] FI 943
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 32 of36 Event
Description:
Attachment 2 and 4 ofEEP-O BOP Check RCS pressure - LESS THAN 5.2 Proceed to Step 6.
275 psig{435 psig}.
BOP 6 Verify containment ventilation isolation.
6.1 Verify containment purge dampers - CLOSED.
[] 3197
[] 3198D
[] 3198C
[] 3196
[] 3198A
[] 3198B 6.2 Verify containment mini purge dampers - CLOSED.
CTMT PURGE DMPRS MlNI-2866C & 2867C FULL-3198A & 3198D
[] 2866C
[] 2867C CTMT PURGE DMPRS MlNI-2866D & 2867D FULL-3196 & 3197 BOTH-3198B & 3198C
[] 2866D
[] 2867D 6.3 Stop MINI PURGE SUPPIEXH FAN.
Will place HS to STOP BOP 7 Verify containment fan cooler alignment.
7.1 Verify at least one containment fan cooler per train - STARTED IN SLOW SPEED.
CTMT CLR FAN SLOW SPEED D A train
[]IA
[]IB DB train
[]IC
[] ID 7.2 Verify associated emergency service water outlet valves -
OPEN.
EMERG SW FROM lA(IB,IC,ID) CTMT CLR
[] QIP16MOV3024A
[] QIP16MOV3024B
[] QIP16MOV3024C
[] QIP16MOV3024D
Allliendix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 33 of36 Event
Description:
Attachment 2 and 4 of EEP-O BOP 8 Verify AFW Pumps - STARTED.
8.1 Verity both MDAFW Pumps - STARTED
[] 1A MDAFW Pump amps> 0
[] 1B MDAFW Pump amps> 0 AND
[] FI-3229A indicates> 0 gpm
[] FI-3229B indicates> 0 gpm
[] FI-3229C indicates> 0 gpm 8.2 Check TDAFW Pump start required.
o Condition OTSLB OSetl2oint o Coincidence 0 RCPBus TSLB21-1 02680 V 112 Detectors I
Undervoltage 1-2 1-3 on 2/3 Busses LowLowSG 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 8.3 Verity TDAFWP started.
[] MLB-4 1-3 lit
[] MLB-4 2-3 lit
[] MLB-4 3-3 lit TDAFWP SPEED
[] SI 3411A > 3900 rpm TDAFWP SPEED CONT
[] SIC 3405 adjusted to 100%
8.4 Verity TDAFW flow path to each SG.
TDAFWP TO 1A(1B,1C) SG
[] Q1N23HV3228A in MOD
[] Q1N23HV3228B in MOD
[] Q1N23HV3228C in MOD TDAFWP TO 1A(1B,1C) SG FLOW CONT
[] HIC 3228AA open
[] HIC 3228BA open
[] HIC 3228CA open BOP 9 Verify main feedwater status.
9.1 Verity main feedwater flow control and bypass valves - CLOSED.
[] FCV 478
)
[] FCV 488
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 34 of36 Event
Description:
Attachment 2 and 4 of EEP-O
[] FCV 498 9.2 Verify both SGFPs - TRIPPED.
9.3 Verify SG blowdown - ISOLATED.
[] QIG24HV7614A closed
[] QIG24HV7614B closed
[] QIG24HV7614C closed 9.4 Verify SG blowdown sample - ISOLA TED MLB lights lit.
lA(lB,IC) SGBD SAMPLE STEAM GEN ISO
[] MLBI 19-2 lit QIP15HV3328 closed
[] MLBI 19-3 lit QIP15HV3329 closed
[] MLBI 19-4 lit QIP15HV3330 closed BOP I 10 Check no main steam line isolation actuation signal present.
Signal Set120int coincidence TSLB LO SG PRESS < 585 psig 2/3 TSLB4 19-2,3,4 Hi stm flow
>40%
Yz on 2/3 TSLB416-3,4 and and 17-3,4 18-3,4 Lo-Lo Tavg
<543°F 2/3 TSLB2 10-1,2,3 HI -HI ctmt press > 16.2 psig 2/3 TSLBI2-2,3,4 11 Verify PHASE A CTMT ISO.
11.1 Verify PHASE A CTMT ISO - ACTUATED.
[] MLB-2 1-1 lit BOP I [] MLB-2 11-1 lit 11.2 Check all MLB-2lights - LIT.
11.2 Verify PHASE A CTMT ISO alignment using ATTACH 3, PHASE A CTMT ISO BOP I 12 Check all reactor trip and 12 Perform the following.
reactor trip bypass breakers - OPEN. 12.1 Open reactor trip breaker(s) manually from MCB or locally.
Reactor trip breaker A 12.2 Record any breaker(s)
Reactor trip breaker B manually opened.
Reactor trip bypass breaker A Reactor trip bypass breaker B BOP I 13 Trip CRDM MG set supply breakers.
lA(lB) MG SET SUPP BKR
Al!I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 35 of36 Event
Description:
Attachment 2 and 4 ofEEP-O
[J NICIIE005A
[J NICIIE005B BOP 14 Secure secondary components.
14.1 Stop both heater drain pumps.
HDP
[] lA
[JIB 14.2 Check any condensate pump started.
14.2.1 IF started, THEN stop all but one condensate pump.
[] lA
[JIB 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 SOP-O.O, APPENDIX B, TB SO ACTIONS FOLLOWING A REACTOR TRIP OR SAFETY
)
INJECTION.
Will call TBSO to accomplish this.
BOP 15 Verify both CRACS mode selector switches in the ON position.
CRACS Mode Selector Switch
[J A TRAIN
[J B TRAIN Will call BOOTH to have this accomplished since this is not in the simulator BOP 16 WHEN at least 30 seconds have passed since turbine trip, THEN check main generator tripped.
230 KVBKR
[J 810 - OPEN
[J 914 - OPEN BOP 17 Verify two trains of ECCS equipment aligned.
17.1 Perform ATTACHMENT 4, TWO TRAIN ECCS ALIGNMENT VERIFICA TION.
End of Attachment 2
AI!.I!endix D Required Operator Actions Form ES-D-2 Op-Test No.: Farley 2008-301 Scenario No.: 6 Event No.: 9 Page 36 of36 Event
Description:
Attachment 2 and 4 ofEEP-O TWO TRAIN ECCS ALIGNMENT VERIFICATION BOP 1 Verify two trains ofECCS equipment aligned.
Check DFOI closed Verify DF02 closed Check DG 15 closed Verfiy DG02 closed Verity two trains of battery chargers - energized Amps>O 1.6 Verity two trains of ESF equipment aligned.
Check all MLB-l lights LIT Verify charging pump suction and discharge valves - OPEN.
[J QIE21MOV8132A
[] QIE21MOV8132B
[J Q1E21MOV8133A
[] QIE2IMOV8133B CHG PUMP SUCTION HDR ISO
)
[] Q1E21MOV8130A
[J QIE21MOV8130B
[] QIE21MOV8131A
[J Q1E21MOV8131B 1.7 Verity all post accident containment air mixing system fans - STARTED. (BOP)
POST ACCIDENT MIXING FAN
[JIA
[JIB
[] lC
[]1D RX CA V H2 DILUTION FAN
[] lA
[JIB BOP
~all Radside SO to Verity Spent Fuel Pool Cooling in service per SOP-54.0, SPENT FUEL PIT COOLING AND PURIFICATION SYSTEM.
End of Attachment 4
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