ML023050199
| ML023050199 | |
| Person / Time | |
|---|---|
| Site: | Prairie Island  |
| Issue date: | 08/12/2002 |
| From: | Hironori Peterson NRC/RGN-III/DRS/OLB |
| To: | |
| References | |
| Download: ML023050199 (72) | |
Text
FINAL AS-ADMINISTERED SCENARIOS FOR THE PRAIRIE ISLAND INITIAL EXAMINATION - AUGUST 2002
AW~U5P W~' bA41l 4t
Appendix D Scenario Outline Appedix Scnari OutineForm ES-D-1 (R8. S1')
Facility: -Prairie Island Scenario No.: 1 Op-Test No.: 2001301 Examiners: Operators:
Initial Conditions: BOL, recovery from reactor scram 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago, currently 15% power, D2 00S, 12 AFW OOS, Place Steam Dump in Stm. Pressure mode Instrument maintenance is peforming troubleshooting on the Steam Dump Tave control mode Turnover: Recovery from Trip 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> ago. Raise power to 100% at maximum rate, MSRs are already in service.
Event Malf. Event Event No. No. Type* Description 1 R (RO) Raise reactor power 5-10%.
N RO will adjust reactivity by controlling boron concentration (BOP) BOP will increase power by increasing turbine load, Lineup 13 Feedwater Heater drains for normal operation, Start one heater drain pump per 1C28.4, Heater Drains, and Shutdown the Condenser Spray System per 1 C28.5.
2 I (RO) PT 431 (PZR press) fails high - take manual control of (BOP) pressure and trip bistables (Simulator file number 97-03) 3 C (RO) Charging pump trip-start another charging pump (Simulator file number 97-02) 4 I (BOP) PT-484 failure high - Manual control to shut steam dumps (Simulator file 99-05) 5 C 11 Condensate pump motor stator HI temp - start a different (BOP) condensate pump 6 M (All) Uncontrolled depressurization of both S/G's - steam leak on A steam header results in manual reactor trip (if not already tripped) and stuck open S/G PORV on B S/G - Gets to ECA 1 2.1 (Simulator file 97-03) 7 C SI pump fails to start on SI signal-manually start SI pump (BOP)
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Appendix D Operator Actions edx......ct sForm S--2 (R8 R1 Op-Test No.: 2002301 Scenario No.: 1 Event No.: _1 Page 1 of 2 Event
Description:
Raise Reactor Power 5-10%
Time Position Applicant's Actions or Behavior RX Power Increase SRO DIRECT Load increase at maximum allowed rate per 1C1.4.
PERFORM or delegate the performance of Steps 5.1.1 to 5.1.6 of 1 C1.4, "Power Operation."
BOP DETERMINE the Maximum Rate of Load Increase per Step 5.1.7A of 1 C1.4, "Power Operation."
RO DETERMINE the Maximum Rate of Power Increase per Step 5.1.7A of 1 C1.4, "Power Operation."
BOP START the load increase as follows:
-Select the desired load rate on the Turbine EH Control Panel.
-Verify the turbine control VALVE POS LIMIT light is OFF.
IF NOT, THEN lower the REFERENCE/SETTER until the light is OFF.
-Raise the Valve Position Limiter to 100%.
-IF ITC is negative, THEN place turbine EH control in "IMP IN."
-Set the desired turbine load on the SETTER display on the Turbine EH Control Panel using the reference control pushbuttons.
RO INITIATE an alternate dilution of the RCS per C12.5,"Boron Concentration Control," Step 5.4, as necessary.
BOP WHEN Ta shows an increase, THEN depress the turbine control GO pushbutton.
RO MAINTAIN Tave and Tre, matched by varying the alternate dilution rate or performing alternate dilutions per C12.5 as necessary.
Appendix D Operator Actions Form ES-D-2 (R8, Si)
Op-Test No.: 2002301 Scenario No.: 1 Event No.: _1 Page 2 of 2 Event
Description:
Raise Reactor Power 5-10%.
Time Position Applicant's Actions or Behavior BOP CUE: MSR's are already in service and 13 Feedwater heater drains are already aligned for normal operation.
START one heater drain pump per 1C28.4, "Unit 1 Heater Drains,"
Step 5.1.
SHUTDOWN the Condenser Spray System per 1C28.5, "Unit 1 Condenser Spray System," Step 5.2.
Appendix D Operator Actions Form Fr ES-D-2 E--
('R8.
(R8 Si
$1)
Apedi OeatrAtin Op-Test No.: 2001301 Scenario No.: 1 Event No.: _2 Page 1- of 1 Event
Description:
PT431 (PZR press) Fails High Time IPosition I Applicant's Actions or Behavior Pressurizer Pressure 1P-431 - Fails High EVALUATOR NOTE: The following annunciator will alarm when the malfunction is inserted: 47012-0408, "PRZR HI/LO Press Channel Alert" RO CRITICAL TASK: PLACE pressurizer pressure controller in MANUAL and stabilize pressure.
SELECT 2-1 (white-red) on channel selector switch.
RETURN pressure control to AUTO.
SELECT another channel on the pressurizer pressure recorder.
SRO REFER to T.S.3.5.B & Table T.S.3.5-2A FU 7,9,10 and Table TS3.5-2B FU 1d (6 hr LCO for B/S tripping), and T.S. 3.10.J.b Initiate investigation of reason for loss of Pressurizer Pressure 1 P 431 BOP TRIP and independently verify bistables lAW 1 C51.3, "Instrument Failure Guide," Rev. 17.
1TC-407-C Over Temp AT Trip 1TC-407-D Over Temp AT Rod Stop 1 PC-431-A Hi Press Trip 1 PC-431 -J LO Press Trip 1 PC-431-1 Unblock SI 1PC-431-G LO Press SI
Appendix D pOrerator Actions F.m.........
Op-Test No.: 2001301 Scenario No.: 1- -Event No.: 3 Page 1 of 1 Event
Description:
11 Charging Pump OverloadTrip Time I Position Applicant's Actions or Behavior 11 Charging Pump Trip EVALUATOR NOTE: The following annunciator will alarm when the malfunction is inserted: 47015-0103, "11 Charging Pump Overload Trip."
RO RECOGNIZE reduced charging header and seal injection flow and START a standby Charging Pump lAW 47015-0103, C12.1 AOP1, "Loss of RCP Seal Injection," and C12.1 AOP2, "Loss of Charging Flow To The Regen HX,":
CRITICAL TASK: START 12 or 13 Charging Pump.
CRITICAL TASK: INCREASE Charging Pump speed to maintain <2550# discharge pressure and seal injection flow
-8 gpm.
PLACE L/D in service JAW C12.1,"Letdown, Charging, and Seal Water Injection."
ADJUST In-service Charging Pump speed to maintain 6-10 gpm seal injection flow to each RCP while balancing total Charging and L/D flow.
PLACE In-service Charging Pump speed control in AUTO.
SRO INITIATE investigation of reason for loss of 11 Charging Pump.
Appendix D Appendix D ~~~~Ooerator Actions Fr ~f- P :i Op-Test No.: 2002301 Scenario No.: 1 Event No.: 4 Page 1 - of 1 Event
Description:
bigb PT-484 MS Header Pressure failure Time Position Applicant's Actions or Behavior I
PT-484 MS Header Pressure failure high RO Identify failure of PT-484 MS Header Pressure high.
TAKE manual control to Steam Pressure controller 484 and CLOSE steam dumps.
Monitor and control reactivity transient.
CUE: When asked Troubleshooting with Tave mode circuitry is complete and ok to go to Tave mode.
SRO DETERMINE Status of Maintenance on Tave mode circuitry and give direction to change steam dump control to Tave mode.
Appendix D Operator Actions Form ES-D-2 (R8, Si)
Op-Test No.: 2002301 Scenario No.: 1 Event No.: 5 Page 6 of 10 Event
Description:
11 Condensate Pump Motor Stator Temperature Increasing Time] Position [ Applicant's Actions or Behavior 11 Condensate Pump Motor Stator Temperature Increasing EVALUATOR NOTE: The following annunciator will alarm when the malfunction is inserted: C47009-0302, "11Condensate Pump Motor Stator HI Temp."
BOP RESPOND to Alarm C47009-0302, "11 Condensate Pump Motor Stator HI Temp."
RECOGNIZE that 11 Condensate Pump has high motor current.
MONITOR stator temperature increase.
SHIFT Condensate Pumps per 1C28.3, "Unit 1 Condensate System," Rev. 1OW, Step 5.6, as temperatures continue to increase and prior to stator temperature reaching 1400 C.
SRO Investigate reason for high stator current and temperature.
Appendix D Operator Actions Form ES-D-2 (R8, S1)
Op-Test No.: 2002301 Scenario No.: 1 -Event No.: _6&7 Page-l_ of -5 Event
Description:
Steam leak on 1A SG safety header followed by 11 FRV failure followed by 12 PORV failing open and an uncontrolled depressurization of both S/G's. SI pump does not auto start on SI signal.
Time Position Applicant's Actions or Behavior Steam Leak on A SG safety relief valve header EVALUATOR NOTE: The following annunciator will alarm when the malfunction is inserted: C47022-0611, "Fire Detection Panel FP121 Fire Alarm."
BOP RESPOND to Fire Alarm C47022-0611, "Fire Detection Panel FP121 Fire Alarm.":
-Determine affected zone
-Page Aux. Bldg. Operator
-Bypass affected zone
-Reset fire detection panel CUE: If the field operator is contacted to investigate the fire alarm in the Aux. Bldg. report that there is a large feather of steam coming from Loop A safety valve header.
EVALUATOR NOTE: The 11 FRV will fail open. The operator will attempt unsuccessful to take MANUAL control of the Feedwater Regulating Valves from the control room.
11 FRV Fails Open SRO DIRECT operators to enter C28.2 AOP1, "Unit 1 Feedwater Regulating Valve Control Failure."
BOP DISPATCH personnel to locally control at manual loading station.
CUE: If the crew requests to take local control of 11 SG FRV then report that you are unable to approach the valve because of the steam leak in the area.
Appendix D Op~erator Actions Form ES-D-2 (R8, S1 E-- (R8
$11 Apedi OeatrAtinFr Op-Test No.: 2002301 Scenario No.: 1 - Event No.: _6&7_ Page_2_ of -5 Event
Description:
Steam leak on 1A SG safety header followed by 11 FRV failure followed by 12 PORV failing open and an uncontrolled depressurization of both S/G's. SI pump does not auto start on SI signal.
Time Position Applicant's Actions or Behavior BOP REPORT to SRO that atmospheric conditions from steam leak prevent local manual control.
SRO DIRECT the reactor to be manually tripped before tripping due to high steam generator level.
EVALUATOR NOTE: When a reactor trip is initiated, immediately increase the steam rupture on Loop A safety header. When SI occurs, fail open 12 SG PORV.
RO Manually TRIP the reactor BOP VERIFY turbine tripped.
VERIFY Safeguards buses energized.
CHECK if SI is actuated.
VERIFY component alignment.
EVALUATOR NOTE: 11 SI Pump fails to start CRITICAL TASK: Manually START 11 SI pump.
EVALUATOR NOTE: SRO should direct transition to E-2 when it is recognized that there is a faulted S/G and then into ECA 2.1 when it is recognized that both S/Gs are faulted.
E-2, "Faulted Steam Generator Isolation,"
SRO DIAGNOSE faulted SG and transition to E-2.
SRO DIAGNOSE that both SGs are faulted and transition to ECA -2.1.
Appendix D Operator Actions Form ES-D-2 (R8, Appendix D Operator Actions Form ES-D-2 (RB, $1)
Si)
Op-Test No.: 2002301 Scenario No.: 1 Event No.: _6&7 Page 3 of 5 Event
Description:
Steam leak on 1A SG safety header followed by 11 FRV failure followed by 12 PORV failing open and an uncontrolled depressurization of both S/G's.
Time Position Applicant's Actions or Behavior ECA-2. 1," Uncontrolled Depressurization of Both Steam Generators."
RO/ Check secondary pressure boundary:
BOP - MSIV's, FRV's, FRV B/P's, SGBD and FW Cl valves closed.
- Close steam supply valve from one SG to TD AFW pump lAW the note at the top of page 3 of the EOP.
CUE: If field operator is dispatched to 12 SG PORV for local operation, report that Aux. Bldg. entry is unsafe based on steam conditions and you are unable to locally operate the PORV from the hot shutdown panel.
BOP Control feed flow to minimize RCS cooldown:
-CHECK cooldown rate in RCS cold legs less than 1000 F per hour.
-THROTTLE AFW flow to a minimum of 40 GPM per SG with a narrow range of less than 5%.
- ENSURE RCS temperature is stable or decreasing.
Appendix D Ouerator Actions endiFD...e.a..r.Actions.Form ES-D-2 (R8 S1, Op-Test No.: 2002301 Scenario No.: 1 - Event No.: _6&7 Page 4 of 5 Event
Description:
Steam leak on 1A SG safety header followed by 11 FRV failure followed by 12 PORV failing open and an uncontrolled depressurization of both S/G's.
Time Position Applicant's Actions or Behavior EVALUATOR NOTE: If at least one SI or RHR pump is running and RCS pressure is less than 1250 psig than secure both RCPs RO CHECK if RCPs should be stopped.
CHECK PRZR PORVs available and closed and at least one block valve open.
SRO INITIATE periodic SG samples.
VERIFY secondary radiation levels are normal.
RESET Containment Spray Signal and Stop CS pumps.
CHECK RWST level greater than 33%
RESET SI.
RESET Cl.
ESTABLISH instrument air to containment Appendix D, Operator Actions Form ES-D-2 (R8, Si)
Op-Test No.: 2002301 Scenario No.: 1 - Event No.: _6&7 Page 5 of 5 Event
Description:
Steam leak on 1A SG safety header followed by 11 FRV failure followed by 12 PORV failing open and an uncontrolled depressurization of both S/G's.
Time Position Applicant's Actions or Behavior RO CHECK for SI termination criteria:
-RCS subcooling greater than 200 F.
-RCS pressure greater than 2000 and stable or increasing.
-PZR level greater than 7%.
VERIFY SI flow is NOT required.
TERMINATE SCENARIO: The scenario should be terminated once the crew has verified that SI is no longer required and secured SI.
NOR 7-r Appendix D .£ecm* ri* Ni itlin*
Apr~~~endixr D ELIilI-OL-I ýflo, S 12 Facility: -Prairie Island Scenario No.: 2 Op-Test No.: 301-2002 Examiners: (Dperators:
Initial Conditions: Unit 1 is at 77% power. Load increase per C1.4 is in progress. Unit power was reduced to replace a bearing on 12 MFP. Equip OOS: 11TD AFW Pump, 12 EH oil pump, D5 Diesel Generator, 13 condensate pump to be used in an emerqencv only.
, m J J L Turnover: _Commence load increase per C1.4 Event Malf. Event Event No. No. Type* Description 1 R (RO) Load increase per C1.4 File 99-04 N RO will aajust reactivity by controlling boron concentration (BOP) BOP will increase power by increasing turbine load.
2 I (RO) N42 Power range failure high. Crew will respond per 1 C51.2 RO must put rods N in manual. Rods must be in auto to start the event. BOP removes N42 from (BOP) service as normal evolution.
3 C 11 Component Cooling Water pump trip, 12 CCW pump fails to start (BOP) automatically. BOP must recognize the failure of the standby pump to auto start and manually start it.
4 M Loss of MFW, 12 MFW is manually tripped on loss of lube oil 11 MFW pump (ALL) trips for unknown reason.
5 C(RO) AFW starts and then trips - loss of heat sink - BOP must cross connect Unit 2 (BOP) AFW k
r kN)ormal, (R)eactivity, I (I)nstrument, (C)omponent, (M)ajor
Appendix D C)n*rmnr Anfinn*
' 'U Ui I ll ro-u-4*: r¶O, 0 1)
Op-Test No.: 2002301 Scenario No.: 2 Event No.: 1 Page 1 of 1I -
Event
Description:
Load increase per C-1.4 RO will adjust reactivity by controlling boron concentration BOP will increase power by increasing turbine load.
Time Position Applicant's Actions or Behavior SRO DIRECT Load increase to 100% at maximum allowed rate per C1.4.
BOP Inform System Control Center of load increase.
May inform Duty Chemist of load increase.
RO DILUTE using Alternate Dilute mode. When Tave shows a increase, Then increases turbine load by setting the SETTER and depressing GO.
BOP OBSERVE turbine and generator limits Start the load increase as follows:
SELECT the desired load rate on the Turbine EH Control Panel.
VERIFY the turbine control VALVE POS LIMIT light is OFF. IF NOT, THEN lower the REFERENCE/SETTER until the light is OFF.
RAISE the Valve Position Limiter to 100%.
IF ITC is negative, THEN place turbine EH control in "IMP IN."
SET the desired turbine load on the SETTER display on the Turbine EH Control Panel using the reference control pushbuttons.
Appendix D C)n*.r*fnr Ar,finne Apenixr .D......r..i.n. Formrr rO-L-2-I1-, S II Op-Test No.: 2002301 Scenario No.: 2 Event No.: 2 Page 1 of 4 Event
Description:
N42 Power range failure high. Crew will respond per 1C51.2 RO must put rods in manual Time Position Applicant's Actions or Behavior EVALUATOR NOTE: The following annunciators will alarm when the malfunction is inserted:
47013-0101 NIS Power Range Positive Flux Rate Channel Alert 47013-0102 NIS Power Range HI Setpoint Channel Alert 47013-0103 NIS Power Range Overpower Rod Withdrawal Stop 47013-0203 NIS Power Range Channel Deviation 47013-0303 Computer Alarm Delta I Check Typer 47013-0403 Computer Alarm Flux Tilt Check Typer Rods must be in auto to start.
1C51.2 Instrument Failure Guide RO RECOGNIZES the failed Power Range Instrument by the following indications : OBSERVES control rods stepping in.
PLACE control rods in manual control and restore Tave equal to Tref.
ADIorendix D IeIx.D...erator Actions Form .S-f.-2 (R8 S I' Op-Test No.: 2002301 Scenario No.: 2 Event No.: 2 Page 2 of 4 Event
Description:
N42 Power range failure high. Crew will respond per 1C51.2 RO must put rods in manual Time Position Applicant's Actions or Behavior SRO DIRECT that N-42 be removed from service.
BOP REMOVES N-42 from service as follows:
On the MISCELLANEOUS CONTROL AND INDICATION PANEL drawer:
PLACE ROD STOP BYPASS switch in the N-42 position.
PLACE POWER MISMATCH BYPASS switch in the N-42 position.
PLACE UPPER SECTION CURRENT COMPARATOR DEFEAT switch in the N-42 position and VERIFY the Upper Section Channel Defeat Light is LIT.
PLACE LOWER SECTION CURRENT COMPARATOR DEFEAT switch in the N-42 position and VERIFY the Lower Section Channel Defeat Light is LIT.
On the COMPARATOR AND RATE drawer, PLACE COMPARATOR CHANNEL DEFEAT switch in the N-42 position and VERIFY Comparator Defeat Light is LIT.
At N-42 POWER RANGE B drawer, REMOVE, and CONCURRENTLY VERIFY removal of the instrument power fuses.
At N-42 POWER RANGE B drawer, REMOVE, and CONCURRENTLY VERIFY removal of the control power fuses.
Appendix D Operator Actions AppndxOerto.sForm ES-D-2 (R8 S1' Op-Test No.: 2002301 Scenario No.: 2 Event No.: 2 Page 3 of 4 Event
Description:
N42 Power range failure high. Crew will respond per 1C51.2 RO must put rods in manual Time I Position J Applicant's Actions or Behavior BOP/RO VERIFY the following annunciators are received:
47013-0101 NIS POWER RANGE POSITIVE FLUX RATE CHANNEL ALERT 47013-0102 NIS POWER RANGE HI SETPOINT CHANNEL ALERT 47013-0201 NIS POWER RANGE NEGATIVE FLUX RATE CHANNEL ALERT 47014-0203 N42 NUCLEAR OVERPOWER ROD STOP BYPASSED Aqua Light VERIFY the following status lights LIT:
44178-0206 PWR RNG LO Q-HI F NC42P 44178-0207 PWR RNG HI Q-HI F NC42P 44205-0204 PWR RNG HI F RATE NC42U/K SRO REFER to the following Technical Specification requirements:
TS 3.5.B & Table 3.5-2A FU 2a. 2b. 3. 4. 7. 8 TS 3.10.B.9 TS 3.10.C.4
Appendix D Operator Actions Form ES-D-2 (R8, Si)
Op-Test No.: 2002301 Scenario No.: 2 Event No.: 2 Page 4 of 4]
Event
Description:
N42 Power range failure high. Crew will respond per 1C51.2 RO must put rods in manual Time I Position I Applicant's Actions or Behavior I
SRO DESIGNATE the following bistables to be tripped:
1TC-406-A OVER POWER AT TRIP 1TC-406-B OVER POWER AT ROD STOP 1TC-406-C OVER TEMP AT TRIP 1TC-406-D OVER TEMP AT ROD STOP
Appendix D Or*p.r*tr*r Antinn* I*r*rr* I--* I-* 0 /DO *-I\
AOpertor A'tion*. icj-- 0 IDO O4-Op-Test No.: 2002301Scenario No.: 2 Event No.: 3 Page of 1 Event
Description:
11 Component Cooling Water pump trip, 12 CC pump fails to start automatically. BOP must recognize the failure of the standby pump to auto start and manually start it.
Time Position Applicant's Actions or Behavior EVALUATOR NOTE: The following annunciators will alarm when the malfunction is inserted: C47020-0101 "11 CC Pump Locked Out" REGONIZE that loss of 11CC pump did not result in an auto start BOP of the 12 CC pump.
CRITICAL TASK: START the 12 CC pump.
RO/BOP IF 47015-0408 LTDN Flow HI TEMP annunciator alarms THEN CV-31204 (1TCV-145) must be reset to demineralizer position.
SRO Enters TS 3.0.C due to both CC pumps being inoperable. The failure to auto start makes the 12 CC pump inoperable and the requirements of TS 3.3.1 cannot be met.
EVALUATOR NOTE: IF the BOP fails to diagnose the failure of the 12 CC pump to start in a timely manner and RCP bearing temperatures get above 200' F or the CC Surge Tank Level goes "off scale" THEN the reactor must be tripped per 1C14 AOP1.
Appendix D Operator Actions Form ES-D-2 ('R8. S1)
I enii DO rtoIctos or S-- (R8 51 Op-Test No.: 2002301 Scenario No.: 2 Event No.: 4 Page 1 of 3 Event
Description:
Loss of MFW, 12 MFW is manually tripped on loss of lube oil 11 MFW pump trips for unknown reason.
Time I Position - Applicant's Actions or Behavior C47010-0202 11 Feedwater Pump Aux Oil Pump LO Press BOP VERIFIES Aux Oil Pump running DISPATCH operator locally to Check for leaks.
CUE: Field operator reports there is a large amount of oil on the skid and on the floor. After this cue the Io-io pressure alarm comes in.
SRO In preparation for stopping the 11 Main FWP, DIRECT power decrease to a turbine load of 330 MWe per 1 C1.4 AOP1, "Rapid Load Reduction - Unit 1" RO BORATE the RCS as necessary to maintain control rods above the insertion limit and to control delta I within limits:
Appendix D Nn*r*fr*r A r-fi*ne
ý "oFor I EO-LJ-D itib¶, S i2 Op-Test No.: 2002301 Scenario No.: _2 Event No.: 4 Page 2 of 3 Event
Description:
Loss of MFW, 11 MFW is manually tripped on loss of lube oil 12 MFW pump trips for unknown reason.
Time Position J Applicant's Actions or Behavior BOP REDUCE turbine load in Automatic OR Manual:
-Automatic:
"* SELECT the desired load rate on the Turbine EHC panel
"*SET the desired turbine load on the "SETTER" display on the Turbine EHC Panel using the reference control pushbuttons
"*DEPRESS the turbine control "GO" pushbutton
- Manual:
"*DEPRESS the turbine control "TURBINE MANUAL" pushbutton
"*DEPRESS the "CV , "pushbutton until the desired turbine load is reached C47010-0102 11 Feedwater Pump Aux Oil Pump LO-LO Press EVALUATOR NOTE: The 11 MFW pump auto trips when this alarm comes in.
EVALUATOR NOTE: Shortly after the 11 MFW pump trips the 12 MFW pump trips for an unknown reason and the turbine will not trip due to loss of both MFW pumps as expected.
SRO Direct the reactor be manually tripped.
SRO 1E-0, "Reactor Trip or Safety Injection" RO DIRECT actions per 1 E-0, "Reactor Trip or Safety Injection" VERIFY Reactor Trip or Manually Trip the Reactor:
Appendix D ApedxDoerator Actions Form ES-f-2 IPA q' I Op-Test No.: 2002301 Scenario No.: 2 Event No.: 4 Page -3_ of 3 Event
Description:
Loss of MFW, 12 MFW is manually tripped on loss of lube oil 11 MFW IumD triDs for unknown reason-Time Position Applicant's Actions or Behavior BOP VERIFY Turbine Trip EVALUATOR NOTE: The turbine will not trip the operator must manually close control valves.
VERIFY Both Safeguards Buses Energized CHECK if SI is Actuated EVALUATOR NOTE: The operators are expected to manually actuate SI due to the lowering PZR level cause by the rapid cooldown when the reactor trips and the turbine does not.
RO/BOP Verify Safeguard Component Alignement BOP Check if Main Steam Lines are isolated.
RO Check Containment Pressure.
BOP ANNOUNCE Reactor Trip NOTIFY Station Manager and Site Emergency Coordinator ENSURE communication with NRC is established within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> BOP CLOSE CC supply to SFP heat exchangers (MV-32115)
OPEN Turbine Building HP Drains (CS-46392)
DIRECT Turbine Building operator to stop Turbine Building roof exhausters and isolate Unit 1 MSRs per ATTACHMENT J VERIFY SI Flow
Appendix D On*.rntnr Antinn* I='*rm I::Qrlo /Do 0.t \
, DOpertor Atinn r_: Q - ) 13 n Op-Test No.: 2002301 Scenario No.: 2 Event No.: 5 Page 1 of 3 Event
Description:
AFW starts and then trips - loss of heat sink - Cross Connect to U2 AFW STime Position Applicant's Actions or Behavior BOP VERIFY RHR Flow VERIFY Total AFW Flow- Greater than 200 gpm.
EVALUATOR NOTE: After the operators have verified proper AFW flow the running AFW pump will trip due to an electric fault on the pump which will preclude it being restarted. The following annunciators will alarm when the malfunction is SRO inserted: C47010 - 0107, "12 AFWP LOCKED OUT."
DIRECT transition to FR-H.1, Loss of Secondary Heat Sink.
RO FR-H.1, Loss of Secondary Heat Sink VERIFY secondary heat sink is required.
RCS pressure - GREATER THAN ANY INTACT SG PRESSURE RCS hot leg temperature - GREATER THAN 3500 F CHECK for secondary heat sink, if none stop RCPs and skip directly to bleed and feed.
Wide range level in either SG - GREATER THAN 9%
PRZR pressure - LESS THAN 2335 PSIG BOP STOP both RCPs RESTORE AFW flow:
DISPATCH operator to determine cause of the AFW pump trip and locally restore AFW.
CUE: Field operator reports that the ground fault relay is up at the 12 AFW pump breaker and he cannot restore AFW DIRECT that AFW be cross-tied to Unit 2.
Appendix D Operator Actions Form F.. -f.-2 (R* R g *.
Op-Test No.: 2002301 Scenario No.: 2 Event No.: 5 Page 2 of 3 Event
Description:
AFW starts and then trips - loss of heat sink - Cross Connect to U2 AFW Time I Position Applicant's Actions or Behavior I
BOP CROSS-CONNECT AFW from Unit 2 lAW 1C28.1, Step 5.7.
PLACE CS-46425, 12 MD AFWP control switch in "PULLOUT."
PLACE CS-46785, 21 MD AFWP selector switch in "MANUAL."
STOP 21 MD AFWP, if running using CS-46770.
REQUEST that Unit 2 operators CLOSE 21 MD AFW Pump valves to the Unit 2 S/G CUE: Unit 2 reports that MV-32383 and MV-32384 are closed.
CLOSE 12 MD AFW Pump discharge valves to the Unit 1 SG's MV-32381 using CS-46316 MV-32382 using CS-46317 DIRECT field operator to reposition the following valves:
CLOSE AF-13-4 OPEN AF-13-1 and 2AF-13-1 CUE: Field operator reports AF-13-4 closed and AF-13-1 and 2AF-13-1 open REQUEST the start of 21 MD AFW Pump CUE: Unit 2 reports that the 21 MD AFW Pump has been started.
Appendix D Cnertrtr Actinnc ccv nQ0* /DO-003
- r.--. I .JI II irO, 0 I)
Op-Test No.: 2002301 Scenario No.: 2 Event No.: 5 Page 3- of 3 Event
Description:
AFW starts and then trips - loss of heat sink - Cross Connect to U2 AFW Time Position Applicant's Actions or Behavior CRITICAL TASK: THROTTLE flow to Unit 1 SGs as necessary to maintain desired SG level using MV-32381 and MV 32382 TERMINATE SCENARIO: When AFW has been cross tied to Unit 2
Appendix D Scenario Outline.
AScenario . . . Outline
. , Do , ,oi)
'-'I)
Facility: Prairie Island Scenario No.: 3 Op-Test No.:
Examiners: Operators:
Initial Conditions: Unit 1: 100% Power, End of Cycle, Equilibrium Xenon, RCS boron = 157 ppm, Breaker 16-10 (Bus 16/Bus 26 Bustie) is 00S Steam Generetor tiih ILri cf A (Dfl ir, Ii Qr Unit 2: 100% power steady state operation Turnover: The 11 and 13 Heater Drain Pumps are presently runninq. The 13 HD Pump was iust started and the 12 HD Pump was shutdown so that preventive maintenance can be penormea on the ]2 MUD P-ump.
periormed Event Malf. Event Event No. No. Type*_ Description 1 RX07C I (RO) Loop B Tcold transmitter failure high (Rods step in and Charging Pump in "AUTO" increases to maximum speed; must place rod control and charging pump speed control in "MANUAL")
2 RC22A C(RO) Pressurizer PORV (CV-31232) leaking (requires isolation)
(5%)
3 RX14B I (BOP) 12 SG FW Reg Valve controller fails "as is" in AUTO (at 80% (will need to control 12 SG level in "MANUAL")
power) 4 1T2809A R (RO) High stator temperature on 11 Main Feedwater Pump (TRG 5) ( 81 'F to 130'F with 300 sec ramp) (requires turbine load decrease to (TRG 11) NBOP 330 MWe, since will need to shutdown pump) (TRG 5)
FW13A N ( ) 47010-0401, "11 FEEDWATER PUMP MOTOR STATOR HI TEMP" (at 70% (TRG 11) power, 11 Main Feedwater Pump trip during load reduction (TRG 6)
TRG 6) (will need to rapidly reduce turbine load).
5 FW19A M(ALL) Feedwater line break on 11 SG inside containment (TRG 7) ( 300 sec ramp to 100%) (requires entry into 1 E-0 and then 1 E-2) 6 TC06 C(BOP) Failure of turbine to AUTO trip on Reactor Trip (Time 0) (will require MANUAL turbine trip) 7 RP09A C(RO) Failure of SI to AUTO actuate RP09B (will require MANUAL actuation of SI)
(Time 0) 8 RP05 C(BOP) Failure of Containment Isolation to AUTO actuate on SI (Time 0) (will require MANUAL actuation of Containment Isolation) 9 SG02A M(ALL) SGTR on 11 SG on Actuation of Safety Injection
( 300 gpm instantaneous) (requires entry into 1E-3 and then 1ECA-3.1) klJ)ormai, kh)eactivity, (I)nstrument, (C)omponent, (M)ajor
Appendix D Operator Acfinn.£ *'nrm ICRRO (13* ql\
ApedxDOoerator Actions Pr Qn- OQ Op-Test No.: _ Scenario No.: 3 Event No.: 1 Page 1 of 15 Event
Description:
Loop B Tcold transmitter failure high (Rods step in and Charging Pump in "AUTO" increases to maximum speed; must place rod control and charging pump speed control in "MANUAL")
Time Position Applicant's Actions or Behavior EVALUATOR NOTE:
The following annunciators will alarm when the malfunction is inserted:
- 47012-0104,"REACTOR COOLANT SYSTEM HI TAVG"
- 47012-0304,"REACTOR COOLANT SYSTEM TAVG DEVIATION"
- 47012-0604,"REACTOR COOLANT SYSTEM AT DEVIATION"
- 47013-0305, "AUCTIONEERED TAVG-TREF DEVIATION" SRO/RO RECOGNIZE the failed transmitter by the following indications:
- Tavg Loop B failed high (Blue)
- AT Loop B failed low (Blue)
- Rods stepping in RO PLACE rod control in "MANUAL" RO PERFORM actions of ARP 47012-0104,"REACTOR COOLANT SYSTEM HI TAVG":
- VERIFYTavg high
- IF due to an instrument malfunction, THEN:
- PLACE rod control in "MANUAL"
- SHIFT charging pump speed control to "MANUAL" and adjust speed as necessary
- VERIFY steam dumps NOT armed
- REFER to 1 C51, "Instrument Failure Guide - Unit 1" SRO DIRECT actions per 1C51.3, "Instrument Failure Guide" for Tavg Loop 1 B 1T-403 Channel Failure High
Operator Actions OpertorActonsForm ES-fl-2(RIP -
Op-Test No.: __ Scenario No.: 3 Event No.: 1 Page 2 of 15 Event
Description:
Loop B Tcold transmitter failure high (Rods step in and Charging Pump in "AUTO" increases to maximum speed; must place rod control and charging pump speed control in "MANUAL")
Time Position Applicant's Actions or Behavior RO PERFORM actions per 1C51.3, "Instrument Failure Guide" for Tavg Loop 1B 1T-403 Channel Failure High:
- VERIFY or place rod control in "MANUAL" and maintain Tavg equal to Tref
- PLACE charging pump speed control in "MANUAL" and maintain pressurizer level
- SELECT Blue channel on the Tavg defeat switch and pull out
- RETURN rod control and charging pump speed to "AUTO" SRO REFER to the following Tech Spec requirements:
- TS 3.5.B and Table 3.5-2A Functional Units 7 and 8
- TS 3.5.8 and Table 3.5-2B Functional Units 5d and 6c EVALUATOR NOTE:
Six (6) hours are allowed before the bistables in the next step are required to be tripped.
RO DIRECT I & C to trip the following bistables:
- 1TC-407-A, "OVER POWER AT TRIP"
- 1TC-407-B, "OVER POWER AT ROD STOP"
- 1TC-407-C, "OVER TEMP AT TRIP"
- 1TC-407-D, "OVER TEMP AT ROD STOP"
- 1TC-403-A, "HI TAVG ALARM"
- 1TC-403-D, "LO TAVG MN STM ISOL"
- 1TC-403-F, "LO TAVG FW ISOL" CUE: I & C will be there in one (1) hour. The I & C Tech is out in Training.
Appendix D Onnrntnr Anfir*n* [:,,",.rr* EQ I"1 0 /DO t2,-,l\
Appendix.D.One.r.t.r Arti ,..nc, I '..i n,..-LJ- , .. )
Op-Test No.: Scenario No.: 3 Event No.: 1 Page 3 of 15 Event
Description:
Loop B Tcold transmitter failure high (Rods step in and Charging Pump in "AUTO" increases to maximum speed; must place rod control and charging pump speed control in "MANUAL")
Time Position Applicant's Actions or Behavior SRO INITIATE Work Order to repair instrument MAKE necessary log entries FOLLOWUP QUESTIONS:
After the scenario is complete, the following questions should be asked of the RO and SRO:
- 1) What instrument failed ?
ANSWER: Loop B Tcold failed high, since Loop B Tavg failed high and Loop B AT failed low.
- 2) What bistables actually tripped (if any) due to the instrument failure?
ANSWER: None
Appendix D Operator Anticnn. I:' ' Jrrn
_ L_9 '4Q-I
,eao -Fnr.. .. Acin
..... ,,,, __-nJ-o.
z Do ,cu Op-Test No.:__ Scenario No.: 3 Event No.: 2 Page 4 of 15 Event
Description:
Pressurizer PORV (CV-31232) leaking (requires isolation)
Time Position T Applicant's Actions or Behavior EVALUATOR NOTE:
The following annunciators will alarm when the malfunction is inserted:
- 47012-0506, "PRZR POWER RELIEF LINE HI TEMP"
- 47012-0606, "PRZR SAFETY VALVE A OR B HI TEMP" SRO DIRECT or maintain overview of actions for leaking PRZR PORV per ARP 47012-0506, "PRZR POWER RELIEF LINE HI TEMP" EVALUATOR NOTE:
The operator may isolate Block Valve MV-32195 OR MV-32196 FIRST at his discretion to find the leaking PRZR PORV.
PRZR PORV CV-31232 is the leaking PORV.
RO PERFORM actions per ARP 47012-0506, "PRZR POWER RELIEF LINE HI TEMP" ( ISOLATE PRZR PORVs one at a time with block valves to determine which valve is leaking):
- CLOSE Block Valve MV-32195 to isolate PORV CV-31231
"* OBSERVE relief line temperature (NO decrease observed)
"* OPEN Block Valve MV-32195
- CLOSE Block Valve MV-32196 to isolate PORV CV-31232
- OBSERVE relief line temperature (decrease observed)
SRO REFER to Tech Spec 3.1 .A.2.c(1 )(b)l (within one hour either restore the PORV to OPERABLE status or close the associated block valve with power maintained to the block valve)
DIRECT RO to close or verify closed PRZR PORV Block Valve MV-32196 to isolate leaking PORV CV-31232 and to maintain power to valve
Appendix D ppdDO erator
.. Actions Fo nrmP5-f-9*PSAL*Z1 Op-Test No.: Scenario No.: 3 Event No.: 3 Page 5 of 15 Event
Description:
12 SG FW Reg Valve controller fails "as is" in AUTO (will need to control 12 SG level in "MANUAL")
Time Position Applicant's Actions or Behavior EVALUATOR NOTES:
- This malfunction will be inserted when power has been reduced to 80% during the load reduction performed for the next malfunction for 11 Main Feedwater Pump.
- The following annunciator will alarm when the malfunction is inserted:
47011-0305, "FW CONTROL FAIL TO MANUAL" SRO DIRECT or maintain overview of actions per ARP 47011-0305, "FW CONTROL FAIL TO MANUAL" BOP PERFORM actions per ARP 47011-0305, "FW CONTROL FAIL TO MANUAL":
- CONTROL 12 SG FW Reg Valve in "MANUAL" within
+/-5%
and return level to normal
Appendix D Operator Actions Appendix D ~~~~Onerator ActionsFrmR-l2( !'
Op-Test No.: Scenario No.: 3 Event No.: 4 Page 6 of 15 Event
Description:
High stator temperature on 11 Main Feedwater Pump (requires turbine load decrease to 330 MWe, since will need to shutdown pump).
11 Main Feedwater Pump trip during load reduction (will need to rapidly reduce turbine load).
Time Position I Applicant's Actions or Behavior EVALUATOR NOTE:
The following annunciator will alarm when the malfunctioni is inserted: 47010-0401,"1 1 FEEDWATER PUMP MOTOR STATOR HI TEMP" SRO DIRECT or maintain overview of actions for high stator temperature alarm per ARP 47010-0401, "11 FEEDWATER PUMP MOTOR STATOR HI TEMP" PERFORM actions for high stator temperature alarm per ARP 47010-0401, "11 FEEDWATER PUMP MOTOR STATOR HI TEMP":
- VERIFY stator temperature high by observing the redundant stator temperatures
- DIRECT local operator to verify motor coolers in operation AND that cool air is being directed on the motor:
(Panel 130 located near the 11 Main FWP)
- 11 FW Pump 11A Cooling Fans - Panel 130, Circuit 1
- 11 FW Pump 11 B Cooling Fans - Panel 130, Circuit 2 CUE: The local operator reports that the motor coolers are working OK, but the pump is starting to get hot.
It must be something internal to motor.
EVALUATOR NOTE:
IF crew is hesitant to start reducing power right away, THEN increase stator temperature on ERCS (computer) by 100C (to 1400C) AND insert the following annunciator alarm:
- 47010-0401, "11 FEEDWATER PUMP OVERLOAD"
Appendix D Operator Actions AOrerator ... Actions
. . P "J, Op-Test No.: Scenario No.: 3 Event No.: 4 Page 7 of 15 Event
Description:
High stator temperature on 11 Main Feedwater Pump (requires turbine load decrease to 330 MWe, since will need to shutdown pump).
11 Main Feedwater Pump trip during load reduction (will need to rapidly reduce turbine load).
Time Position Applicant's Actions or Behavior SRO In preparation for stopping the 11 Main FWP, DIRECT power decrease to a turbine load of 330 MWe per 1C1.4 AOP1, "Rapid Load Reduction - Unit 1" RO BORATE the RCS as necessary to maintain control rods above the insertion limit and to control delta I within limits:
- PLACE the Makeup Mode Selector Switch to "BORATE"
- SET YIC-1 10, "Boric Acid Integrator" to the quantity desired
- SET HC-1 10, "Boric Acid Flow Controller" auto setpoint dial to the flow desired (IF desired, THEN PLACE HC-1 10 to "MANUAL" and adjust output for the desired flow)
- Momentarily PLACE the Boric Acid Makeup switch to "START" BOP REDUCE turbine load in Automatic OR Manual:
- Automatic:
"*SELECT the desired load rate on the Turbine EHC panel
"*SET the desired turbine load on the "SETTER" display on the Turbine EHC Panel using the reference control pushbuttons
"*DEPRESS the turbine control "GO" pushbutton
- Manual:
"*DEPRESS the turbine control "TURBINE MANUAL" pushbutton
"*DEPRESS the "CV ' "pushbutton until the desired turbine load is reached
Appendix D Operator Actions Appedix Oprato ActonsForm ES-D-2 (R8 Si i Op-Test No.: Scenario No.: 3 Event No.: 4 Page 8 of 15 Event
Description:
High stator temperature on 11 Main Feedwater Pump (requires turbine load decrease to 330 MWe, since will need to shutdown pump).
11 Main Feedwater Pump trip during load reduction (will need to rapidly reduce turbine load).
Time Position Applicant's Actions or Behavior EVALUATOR NOTE:
The 11 Main Feedwater Pump trip will be inserted at 70%
power during the ramp down. The following annunciator will alarm when the 11 Main Feedwater Pump is tripped:
- 47010-0101, "11 FEEDWATER PUMP LOCKED OUT" SRO DIRECT actions to reduce turbine load to less than 330 MWe per ARP 47010-0101, "11 FEEDWATER PUMP LOCKED OUT" and 1C1 .4, "Rapid Power Reduction - Unit 1" BOP REDUCE turbine load in Automatic OR Manual to less than 330 MWe:
- Automatic:
"*SELECT the desired load rate on the Turbine EHC panel
"*SET the desired turbine load on the "SETTER" display on the Turbine EHC Panel using the reference control pushbuttons
"*DEPRESS the turbine control "GO" pushbutton
- Manual:
"*DEPRESS the turbine control "TURBINE MANUAL" pushbutton
"*DEPRESS the "CV "pushbutton until the desired turbine load is reached BOP CONTROL 12 SG level with its FW Reg Valve controller in "MANUAL" RO BORATE the RCS as necessary to maintain control rods above the insertion limit and control delta I within limits:
- PLACE the Makeup Mode Selector Switch to 'BORATE"
- SET YIC-1 10, "Boric Acid Integrator" to the quantity desired
- SET HC-1 10, "Boric Acid Flow Controller" auto setpoint dial to the flow desired (IF desired, THEN PLACE HC-1 10 to "MANUAL" and adjust output for the desired flow)
- Momentarily PLACE the Boric Acid Makeup switch to "START" SRO IF the reactor trips, THEN go to 1 E-0, "Reactor Trip or Safety Iniection"
Appendix D Operator Actions Form ES-D-2 (R8, $1)
Op-Test No.: Scenario No.: Event No.: 5,6 Page 9 of 15 Event
Description:
(5) Feedwater line break on 11 SG inside containment.
(requires entry into 1 E-0 and then 1 E-2)
(6) Failure of turbine to AUTO trip on Reactor Trip (will require MANUAL turbine trip)
Time Position Applicant's Actions or Behavior SRO/BOP DIAGNOSE the secondary line break:
- Containment pressure increasing
- Alarm 47011-0301, " 11 STM GEN LVL DEVIATION"
- Feedwater flow to 11 SG increasing (IF reactor is NOT already tripped)
DIRECT RO to manually trip the reactor SRO (IF reactor is NOT already tripped)
RO Manually TRIP the Reactor SRO TRANSITION to 1 E-0, "Reactor Trip or Safety Injection" 1E-0, "Reactor Trip or Safety Injection" SRO DIRECT actions per 1 E-0, "Reactor Trip or Safety Injection" RO VERIFY Reactor Trip or Manually Trip the Reactor:
- Reactor trip and bypass breakers are open
- Neutron flux is decreasing
- Rod Position indicators are at ZERO
- Rod Bottom lights are LIT BOP VERIFY Turbine Trip (failure of turbine to AUTO trip)
- VERIFY both turbine stop valves are closed CRITICAL TASK: Manually trip the turbine before a severe challenge (ORANGE path) develops to the INTEGRITY critical safety function status tree VERIFY Both Safeguards Buses Energized
Appendix D Operator Actions Form or ES-D-2 S--
(R8, (R8 S S1)
AIndxD Irao Aton Op-Test No.: __ Scenario No.: 3 Event No.: 5,7,8- Page 10 of 15 Event
Description:
(5) Feedwater line break on 11 SG inside containment.
(requires entry into 1 E-0 and then 1 E-2)
(7) Failure of SI to AUTO actuate (will require MANUAL actuation of SI)
(8) Failure of Containment Isolation to AUTO actuate on SI (will require MANUAL actuation of Containment Isolation)
Time Position I Applicant's Actions or Behavior 1 E-0, "Reactor Trip or Safety Iniection" RO CHECK if SI is Actuated (failure of SI to AUTO actuate)
CRITICAL TASK: Manually actuate Safety Injection BOP VERIFY Safeguards Component Alignment:
- "SI NOT READY" lights - NOT LIT
- "SI ACTIVE" lights - LIT
"- "CONTAINMENT ISOLATION" lights - LIT (failure of Containment Isolation to AUTO actuate on SI)
CRITICAL TASK: Manually actuate Containment Isolation
- Category I doors - CLOSED
- CHECK Operations Log for any ventilation openings that must be closed within 6 minutes
- CHECK Cooling Water Pressure (Loop A and B) > 65 psig CHECK if MSIVs are Closed (MSIVs should remain open, since containment pressure should be < 17 psig)
CHECK if Containment Instrument Air Valves are Closed (CV-31740 and CV-31741) (valves should remain open, since containment pressure should be < 17 psig)
SRO ANNOUNCE Reactor Trip and SI NOTIFY Station Manager and Site Emergency Coordinator BOP CLOSE CC Supply to SFP Cooling HXs (MV-32115)
SRO ENSURE communication with NRC is established within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />
Appendix D Operator Actions ApednDOerator Actions Form FS-fl-2 (R8 Rql' Op-Test No.: Scenario No.: 3 Event No.: 5,78 Page 11 of 15 Event
Description:
(5) Feedwater line break on 11 SG inside containment.
(requires entry into 1 E-0 and then 1 E-2)
(7) Failure of Si to AUTO actuate (will require MANUAL actuation of SI)
(8) Failure of Containment Isolation to AUTO actuate on SI (will require MANUAL actuation of Containment Isolation)
Time Position Applicant's Actions or Behavior 1 E-0, "Reactor Trip or Safety Injection" BOP OPEN Turbine HP Drains (CS-46392)
DIRECT Turbine Building Operator to stop the TB roof exhausters and isolate the MSRs per Attachment J VERIFY SI Fow VERIFY RHR Flow (have NO RHR flow due to high RCS pressure)
VERIFY > 200 gpm total AFW flow VERIFY > 900 psig on AFW Pumps Discharge VERIFY Status of Equipment in Auto Action Guide (Table EO-1)
PLACE Steam Dump in "STEAM PRESSURE" Mode EVALUATOR NOTE:
RCS temperature will be < 5470F and decreasing in the next step RO CHECK RCS temperature is stable at or trending to 547 0 F:
BOP - CONTROL AFW flow, but NOT < 200 gpm until level restored to > 50% Wide Range in 12 SG
- VERIFY SG blowdown valves closed
- IF cooldown continues and RCS temperature is < 535 0 F, THEN close MSIVs CHECK RCP Cooling:
- VERIFY CC flow to each RCP > 150 gpm
- VERIFY thermal barrier outlet valves open (CV-31245 and CV-31246)
- VERIFY seal injection flow to RCPs is normal
Appendix D Onerator Actions ES-D-2 (R8- S' AtForm Op-Test No.: __ Scenario No.: 3 Event No.: 5 Page 12 of 15 Event
Description:
Feedwater line break on 11 SG inside containment.
(requires entry into 1 E-0 and then 1 E-2)
Time Position! Applicant's Actions or Behavior 1 E-O, "Reactor Trip or Safety Injection" RO CHECK PRZR PORVs and Spray Valves:
- VERIFY PRZR PORVs are closed
- VERIFY PRZR Spray Valves are closed CHECK if RCPs Should Be Stopped (RCPs should be kept running)
SRO TRANSITION to 1 E-2, "Faulted Steam Generator Isolation"
Appendix D Op~erator Actions Apedx....sForm ES-D-2 (R8 S)
Op-Test No.: __ Scenario No.: 3 Event No.: 5 Page 13 of 15 Event
Description:
(5) Feedwater line break on 11 SG inside containment.
(requires entry into 1 E-0 and then 1 E-2)
(9) SGTR on 11 SG on Actuation of Safety Injection
( 300 gpm instantaneous) (requires entry into 1E-3 and then 1ECA-3.1)
Time Position Applicant's Actions or Behavior 1E-2, "Faulted Steam Generator Isolation" SRO DIRECT actions per 1 E-2, "Faulted Steam Generator Isolation" BOP VERIFY MSIVs and Bypass Valves are Closed CHECK if Either SG Not Faulted:
- VERIFY 12 SG is NOT Faulted IDENTIFY Faulted SG:
- VERIFY 11 SG is Faulted ISOLATE the Faulted 11 SG:
- ISOLATE Main FW line
- ISOLATE AFW flow
- CLOSE steam supply valve from 11 SG to TD AFW Pump
- VERIFY SG blowdown isolation valves are closed CRITICAL TASK: Isolate the 11 SG before transition out of 1E-2 SRO CHECK CST Level > 10,000 gallons CHECK Secondary Radiation:
- INITIATE periodic activity samples of both SGs
- VERIFY secondary radiation is NOT normal
- TRANSITION to 1 E-3, "Steam Generator Tube Rupture"
________ ______________ I ___________________________________________________________________
Appendix D ApedxDO erator
.. Actions F 2 (PR Iirm 5
Op-Test No.: __ Scenario No.: 3 Event No.: 9 Page 14 of 15 Event
Description:
SGTR on 11 SG on Actuation of Safety Injection (300 gpm instantaneous) (requires entry into 1 E-3 and then 1 ECA-3. 1)
Time Position Applicant's Actions or Behavior 1E-3, "Steam Generator Tube Rupture" SRO DIRECT actions per 1 E-3, "Steam Generator Tube Rupture" RO CHECK if RCPs Should Be Stopped (RCPs should be kept running)
SRO IDENTIFY that 11 SG is Ruptured BOP ISOLATE Flow from Ruptured 11 SG:
- VERIFY 11 SG PORV controller set in Auto at 1050 psig
- CLOSE steam supply valve from 11 SG to TD AFW Pump (already closed in E-2)
- VERIFY 11 SG blowdown valves closed (already closed in E-2)
- CLOSE 11 SG MSIV and bypass valve SRO VERIFY 11 SG Should Remain Isolated (since 11 SG is also faulted)
RO CHECK PRZR PORVs and Block Valves:
- VERIFY PRZR PORVs are closed
- VERIFY at least one PRZR PORV block valve is open BOP VERIFY 11 SG is Faulted and Isolated CONTROL AFW flow to maintain 12 SG Narrow Range Level between 5% and 50% (Wide Range Level between 50% and 59%
for Adverse Containment)
RESET SI RESET Containment Isolation ESTABLISH Instrument Air to the Containment
Appendix D Operator Actions lFnrm P-q-r)9 IPA Ql A- i.D . . Actions
.. I Ierator Op-Test No.:__ Scenario No.: 3 Event No.: 9 Page 15 of 15 Event
Description:
SGTR on 11 SG on Actuation of Safety Injection
( 300 gpm instantaneous) (requires entry into 1 E-3 and then 1 ECA-3. 1)
Time Position Applicant's Actions or Behavior 1E-3, "Steam Generator Tube Rupture" BOP VERIFY Safeguards Buses are Energized by Offsite Power CHECK if RHR Pumps Should Be Stopped:
- STOP RHR Pumps VERIFY 11 SG Pressure is < 210 psig SRO TRANSITION to 1 ECA-3.1, "SGTR with Loss of Reactor Coolant:
Subcooled Recovery" 1 ECA-3.1, "SGTR with Loss of Reactor Coolant: Subcooled Recovery" SRO DIRECT actions per 1 ECA-3.1, "SGTR with Loss of Reactor Coolant: Subcooled Recovery" TERMINATE SCENARIO when transition to 1 ECA-3.1 is made.
____ ____ ___I
SCENARIO #3 Initial Conditions:
Unit 1:
- 100% Power, End of Cycle, Equilibrium Xenon, RCS boron = 157 ppm
- Breaker 16-10 (Bus 16/Bus 26 Bustie) is OOS
- Steam Generator tube leakage of 4 GPD in 11 SG Unit 2:
- 100% power steady state operation Turnover:
- The 11 and 13 Heater Drain Pumps are presently running
- The 13 HD Pump was just started and the 12 HD Pump was shutdown so that preventive maintenance can be performed on the 12 HD Pump
CC~INAoAO -A--
Appendix D ADScenario Outline Form ES-fl-I R q' Facility: Prairie Island Scenario No.: 4 Op-Test No.:
Examiners: Operators:
Initial Conditions: Unit 1: 50% power, Beginning of Cycle, Equilibrium Xenon, 11 SI Pump is OOS (on hour 16 of a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> clock, expected back in 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />).
12 Charging Pump is OOS for overhaul. Breaker 16-10 (Bus 16/Bus 26 Bustie) is OOS.
Sm Unit 2: 100% nower steadvstat onrnrtinn Turnover: Perform power increase on Unit 1 to 100%. Are presently at Step 5.21.E of 101.4. "Unit 1 Power Operation" at the step to start the second feedwater pump per 1C28.2, "Unit 1 Feedwater System". Steps 5.5.1 through 5.5.8 of Section 5.5 of 1C28.2 have been completed in preparation for starting the 12 FW Pump. A local operator is available by the 12 FW Pump to perform any required actions during the pump startuD.
Event Malf. Event Event No. No. Type* Description 1 N(BOP) Start 12 Main Feedwater Pump 2 R(RO) Reactor power increase 3 RX213 I(BOP) 11 SG pressure channel 1 PT-468 failure high (TRG 3) (11 SG PORV opens, must manually close PORV) 4 RX206 I(RO) Pressurizer level channel 1 L-428 failure low (TRG 4) (letdown isolates, PRZR heaters deenergize, and Charging Pump in "AUTO" increases to maximum speed) 5 RC14 C(RO) RCS leak (2 steps) 1 ( 2 steps for RCS leak) 0 -6% (BOP) 0 to 30 gpm with ramp of 120 sec (TRG 5) 30 to 150 gpm with ramp of 300 sec 6-30% 1 6 RP07 C(RO) ATWS (reactor trip will work from AMSAC / DSS switch)
(Time 0) 1 7 RC14 M(ALL) Small break LOCA (500 gpm) on Reactor Trip (100%) (requires use of E-0, E-1, and ES-1.1) 8 D146924T C(BOP) Bus 16 deenergizes due to breaker failure from CT-i 1 (TRG 7) transformer, with a concurrent sequencer failure.
DG02B Diesel Generator D2 trips during start.
(Time 0) (will need to reenergize Bus 16 from 1 RY transformer per 1C20.5 AOP2, since have NO SI flow, since have NO SI pumps or PD charging pumps)
"(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
ADDITIONAL NOTES FOR SIMULATOR OPERATOR INITIAL SETUP 12 Main Feedwater Pump
- 1T2826A set at 320°F (CPO) - clear after pump start
- 1T2827A set at 320°F (CPO) - clear after pump start Volume Control Have 2 letdown orifices in service 11 and 13 Charging Pumps running in AUTO Flush through charging line Reactor Coolant All PRZR heaters are ON Turbine VPL set at 105%
Diesel Generator
- DI-46922A- AUTO OFF
Appendix D AediDOoerator Actions Form ES-D-2 (R8 S1 I Op-Test No.: Scenario No.: 4 Event No.: 1 Page 1 of 18 Event
Description:
Start 12 Main Feedwater Pump Time I Position I Applicant's Actions or Behavior SRO DIRECT BOP to start the 12 Main Feedwater Pump and maintain overview of plant operations BOP Start the 12 FWP per 1C28.2, Section 5.5, "Starting a Second Feedwater Pump" starting at step 5.5.9:
- PLACE control switch CS-46419 to the "START" position AND HOLD until CV-31875, "12 FWP RECIRC VLV" is FULL OPEN
- DIRECT local operator to close the second FWP warm-up valve F-22-4, "12 FWP PMP WARMUP LINE" CUE: The local operator reports that warm-up valve F-22-4 is closed.
- DIRECT local operator to check the following indications for the 12 FWP:
"* VERIFY seal water temperature is increasing to or being maintained at = 150'F
"* OBSERVE no evidence of steaming or external leakage AND OBSERVE seal water leakage is on automatic control (no bypass flow)
"* VERIFY lube oil pressure > 15 psig
- VERIFY the auxiliary lube oil pump stops
- THROTTLE the lube oil cooler cooling water outlet valve or outlet bypass valve to control lube oil outlet temperature at 100-1250F
- VERIFY 12 FWP discharge pressure is z 1200 psig
- CHECK vibration on the local Reliance vibration panel for the 12 FWP, step-up gear, and motor (Vibrations should feel steady to the fingertips)
CUE: The local operator reports that all indications are normal for the 12 FWP
Appendix D Operator Actions Form ES-D-2 (R8, $1)
Apeni DOerto ctos or S-- ( . Si-Op-Test No.: Scenario No.: 4 Event No.: 2 Page 2 of 18 Event
Description:
Reactor power increase Time I Position! Applicant's Actions or Behavior SRO DIRECT actions per 1C1.4, "Unit 1 Power Operation" and maintain overview of plant operations BOP INCREASE turbine load:
- SELECT the desired load rate on the Turbine EHC panel
- SET the desired turbine load on the "SETTER" display on the Turbine EHC Panel using the reference control pushbuttons RO INITIATE an alternate dilution of the RCS per C12.5 as necessary:
- PLACE the Makeup Mode Selector Switch to "ALTERNATE DILUTE"
- SET YIC-1 11, "Reactor Makeup Water Batch Integrator" to the quantity desired
- IF desired, THEN CLOSE Boric Acid Blender to VCT Valve CV-31201
- Momentarily PLACE the Boric Acid Makeup switch to "START" BOP WHEN Tavg shows an increase, THEN DEPRESS the turbine control "GO" pushbutton RO MAINTAIN Tavg within the desired +/- 1.5°F band BOP As power is increased, ADJUST the following as necessary:
- HD Pump speed
- SG blowdown
Op-Test No.:__ Scenario No.: 4 Event No.: 3 Page 3 of 18 Event
Description:
11 SG pressure channel 1 PT-468 failure high (11 SG PORV opens, must manually close PORV)
Time Position Applicant's Actions or Behavior SRO/BOP RECOGNIZE the failed transmitter by the following indications:
- 11 SG pressure channel 1 PT-468 failure high
- Steam Flow indicator 1 FI-464 failure high
- 11 SG PORV opens PLACE 11 SG PORV controller in "MANUAL" and CLOSE valve SRO DIRECT actions per 1C51.1, "Instrument Failure Guide" for 11 SG pressure channel 1 PT-468 failure high BOP PERFORM actions per 1C51.1, "Instrument Failure Guide" for 11 SG Pressure Channel 1 PT-468 Failure High:
- VERIFY or place 11 SG PORV controller in "MANUAL" and CLOSE valve
- VERIFY 11 SG level control operating properly in automatic SRO REFER to the following Tech Spec requirements:
- TS 3.5.B and Table 3.5-2B Functional Unit 1c EVALUATOR NOTE:
Six (6) hours are allowed in the next step before the bistables are required to be tripped.
BOP DIRECT I & C to trip the following bistables:
- 1 PC-468-A, "LO/LO PRESS SI"
- 1 PC-468-B, "LO PRESS ALARM" CUE: I & C is available to trip the bistables.
Appendix D Op~erator Actions Appedix O~rato ActonsForm ES-D-2 (R8 Sl)
Op-Test No.: __ Scenario No.: 4 Event No.: 3 Page 4 of 18 Event
Description:
11 SG pressure channel 1 PT-468 failure high (11 SG PORV opens, must manually close PORV)
Time Position Applicant's Actions or Behavior SRO IF the Thermal Power Monitor is selected to Calorimetric input, THEN perform the following:
- CHECK TPM power unaffected by the steam pressure channel failure
- IF affected, THEN CHANGE TPM constant K202 from "0" (Calorimetric input) to "1" (NIS input) per C41.4, "ERCS NSSS Applications Program" AND NOTIFY ERCS computer group INITIATE Work Order to repair instrument MAKE necessary log entries
Appendix D Aoerator Actions
. . P -II -9 U l"I p$7= I..
Op-Test No.: _ Scenario No.: 4 Event No.: 4 Page 5 of 18 Event
Description:
Pressurizer level channel 1 L-428 failure low (letdown isolates, PRZR heaters deenergize, and Charging Pump in "AUTO" increases to maximum speed)
Time Position Applicant's Actions or Behavior EVALUATOR NOTE:
The following annunciators will alarm when the malfunction is inserted:
- 47012-0507, "PRZR LVL DEVIATION"
- 47012-0607, "PRZR LO-LO LVL HEATERS OFF AND LETDOWN SECURED"
- 47015-0203, "CHARGING PUMP IN AUTO HI/LO SPEED" SRO/RO RECOGNIZE the failed transmitter by the following indications:
- Pressurizer level channel 1 L-428 failure low
- Letdown isolation / PRZR heater cutoff
- Charging Pump in "AUTO" increases to maximum speed SRO DIRECT actions per 1C51.3, "Instrument Failure Guide" for Pressurizer level channel 1 L-428 failure low RO PERFORM actions per 1C51.3, "Instrument Failure Guide" for Pressurizer level channel 1L-428 failure low:
- PLACE charging pump speed control in "MANUAL" AND ADJUST pressurizer level to setpoint
- SELECT position "2-1" (WHITE-RED) on the PRZR Level Control Selector Switch
- RESTORE pressurizer heaters (must be placed in OFF for about 10 seconds in order for breaker to be closed)
Apprendix AOoerator D Actions FormIE...
. . (R8----
Op-Test No.: Scenario No.: 4 Event No.: 4 Page 6 of 18 Event
Description:
Pressurizer level channel 1 L-428 failure low (letdown isolates, PRZR heaters deenergize, and Charging Pump in "AUTO" increases to maximum speed)
Time Position Applicant's Actions or Behavior RO - RESTORE letdown per C12.1, "CVCS Letdown, Charging and Seal Water Injection":
"* PLACE 1 HC-1 30, "LTDN TEMP CONT" in "MANUAL" AND OPEN to 50%
"* PLACE 1 HC-1 35A, "LTDN PRESS CONT" in "MANUAL" AND OPEN to 50%
"* ESTABLISH charging to Regen HX by adjusting charging line flow control valve 1 HC-142 and the inservice charging pump speed
"* OPEN letdown isolation valves:
- CV-31226, "LETDOWN LINE ISOL"
- CV-31255, "LETDOWN LINE ISOL"
"* OPEN letdown orifice isolation valve CV-31325, CV-31326, or CV-31327 while adjusting 1HC-135A, "LTDN PRESS CONT" so the 600 psig relief does NOT lift
"* RETURN 1HC-135A, "LTDN PRESS CONT" controller to "AUTO"
"* RETURN 1HC-1 30, "LTDN TEMP CONT" controller to "AUTO" RESTORE one charging pump speed control to "AUTO"
- ENSURE pressurizer level recorder NOT selected to Blue channel SRO - REFER to the following Tech Spec requirements:
- TS 3.5.B and Table 3.5-2A Functional Unit 11 EVALUATOR NOTE:
Six (6) hours are allowed before the bistables in the next step are required to be tripped.
RO DIRECT I & C to trip bistable 1 LC-428-A, "HI LEVEL TRIP" CUE: I & C will be there in one (1) hour. The I & C Tech is out in Training.
SRO INITIATE Work Order to repair instrument ft AA IC n anaeon n , Ian an*m. ,e
__________________i vlrI,[\l.- i It;~*b:. V IUUL fil EIl It:*
Appendix D dOoerator Actions FormI....
. . (" S1-"
Op-Test No.:__ Scenario No.: 4 Event No.: 5 Page 7 of 18 Event
Description:
RCS leak ( 2 steps for RCS leak) 0 to 30 gpm with ramp of 120 sec 30 to 150 gpm with ramp of 300 sec Time Position Applicant's Actions or Behavior RO DIAGNOSE the RCS leak:
- Annunciator 47022-0108, "HI RADIATION TRAIN B PANEL ALARM" (due to 1R12 containment rad monitor)
- Decreasing pressurizer level
- Charging flow increase
- Decreasing VCT level
- VCT automatic makeup
- Annunciator 47012-0507, "PRZR LVL DEVIATION"
- Annunciator 47015-0203, "CHARGING PUMP IN AUTO HI/LO SPEED" SRO DIRECT actions per 1 C4 AOP1, "Reactor Coolant Leak" IF at any time RCS inventory can NOT be maintained by available charging flow, THEN DIRECT manual trip of the reactor AND go to 1 E-0, "Reactor Trip or Safety Injection" RO START additional charging pumps as needed to control pressurizer level IF VCT level can NOT be maintained by the make-up system, THEN align charging pump suction to the RWST USE Computer Screen to determine approximate RCS leak rate EVALUATOR NOTE: The initial size of the RCS leak is 30 gpm with a ramp of 120 seconds.
DETERMINE the location of the leak EVALUATOR NOTE: The leak should be identified as being in containment based on:
- Increasing radiation levels on IR-11, 12, 2, or 7
- Increasing containment temperature, pressure, humidity
- Sump A or C level alarms
Aoorendix D AredxDOoerator Actions Form ES-D-2 (R8. S1 ý Op-Test No.: __ Scenario No.: 4 Event No.: 5 Page 8 of 18 Event
Description:
RCS leak ( 2 steps for RCS leak) 0 to 30 gpm with ramp of 120 sec 30 to 150 gpm with ramp of 300 sec Time Position I Applicant's Actions or Behavior SRO COMPLY with Tech Spec 3.1.C.2 which states:
"If the total leakage, other than leakage from controlled sources, exceeds 10 gpm, within one hour initiate action to place the unit in HOT SHUTDOWN and be in at least HOT SHUTDOWN within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />."
EVALUATOR NOTE:
At discretion of Chief Examiner, increase size of RCS leak from 30 gpm to 150 gpm with 300 sec ramp.
SRO DIRECT actions to reduce turbine load per 1C1.4, "Unit 1 Power Reduction" REDUCE turbine load per 1C1.4, "Unit 1 Power Reduction":
RO - IF desired, THEN place rod control in "MANUAL" BOP - SELECT the desired load rate on the Turbine EHC panel
- SET the desired turbine load on the "SETTER" display on the Turbine EHC Panel using the reference control pushbuttons RO - INITIATE a negative reactivity addition using control rods OR a boration of the RCS per the following:
"* PLACE the Makeup Mode Selector Switch to "BORATE"
"* SET YIC-1 10, "Boric Acid Integrator" to the quantity desired
"* SET HC-1 10, "Boric Acid Flow Controller" auto setpoint dial to the flow desired (IF desired, THEN PLACE HC-1 10 to "MANUAL" and adjust output for the desired flow)
"* Momentarily PLACE Boric Acid Makeup switch to "START" -o
- WHEN Tave shows a decrease, THEN DEPRESS the turbine control "GO" pushbutton
- Maintain Tave and Tref within 1.5°F
Appendix D ApedxDOierator Actions Form ES-D-2 (R8. S1)
Op-Test No.: Scenario No.: 4 Event No.: 6 Page 9 of 18 Event
Description:
(6) ATWS (reactor trip will work from AMSAC / DSS switch)
(7) Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time Position. Applicant's Actions or Behavior RO DIAGNOSE the small break LOCA:
- Decreasing pressurizer level beyond the capability of available charging flow SRO DIRECT RO to manually trip the reactor RO Manually TRIP the Reactor (failure of Reactor to trip from BOTH of the Reactor Trip switches)
CRITICAL TASK: Manually trip the reactor using the AMSAC / DSS Control Switch SRO TRANSITION to 1 E-0, "Reactor Trip or Safety Injection"
_______ _____________ A _____________________________________________________________
Appendix D Operator Actions Form ES-D-2 (R8, S1)
Op-Test No.: _ Scenario No.: 4 Event No.: 78 Page 10 of 18 Event
Description:
(7) Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
(8) Bus 16 deenergizes due to breaker failure from CT-1 1 transformer, with a concurrent sequencer failure. Diesel Generator D2 trips during start (will need to reenergize Bus 16 from 1 RY transformer per 1 C20.5 AOP2, since have NO SI flow, since have NO SI pumps or PD charging pumps)
Time I Position Applicant's Actions or Behavior 1 E-0, "Reactor Trip or Safety Injection" SRO DIRECT actions per 1 E-0, "Reactor Trip or Safety Injection" RO VERIFY Reactor Trip:
- Reactor trip and bypass breakers are open
- Neutron flux is decreasing
- Rod Position indicators are at ZERO
- Rod Bottom lights are LIT BOP VERIFY Turbine Trip:
- VERIFY both turbine stop valves are closed EVALUATOR NOTE:
Bus 16 is deenergized due to breaker failure from CT-11 transformer, with a concurrent sequencer failure. Diesel Generator D2 trips during start.
VERIFY Both Safeguards Buses Energized:
- INITITIATE action to restore Bus 16 (which is deenergized) per 1C20.5 AOP2, "Reenergizing 4.16 KV Bus 16" CRITICAL TASK: Reenergize Bus 16 from 1 RY transformer EVALUATOR NOTE:
See Page 17 for actions to reenergize Bus 16 per 1C20.5 AOP2 RO CHECK if SI is Actuated:
- Manually ACTUATE Safety Injection (IF NOT already actuated)
Appendix D Operator Actions Form ES-D-2 (R8, S1)
Op-Test No.: __ Scenario No.: 4 Event No.: 7 Page 11 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time Position Applicant's Actions or Behavior 1 E-0, "Reactor Trip or Safety Injection" BOP VERIFY Safeguards Component Alignment:
"- "SI NOT READY" lights - NOT LIT
"- "SI ACTIVE" lights - LIT
"- "CONTAINMENT ISOLATION" lights - LIT
- Category I doors - CLOSED
- CHECK Operations Log for any ventilation openings that must be closed within 6 minutes
- CHECK Cooling Water Pressure (Loop A and B) > 65 psig CHECK if MSIVs are Closed (MSIVs should remain open, since containment pressure will be < 17 psig)
CHECK if Containment Instrument Air Valves are Closed (CV-31740 and CV-31741) (valves should remain open, since containment pressure will be < 17 psig)
SRO ANNOUNCE Reactor Trip and SI NOTIFY Station Manager and Site Emergency Coordinator BOP CLOSE CC Supply to SFP Cooling HXs (MV-32115)
OPEN Turbine HP Drains (CS-46392)
DIRECT Turbine Building Operator to stop the TB roof exhausters and isolate the MSRs per Attachment J CUE: The TB roof exhausters are stopped and the MSRs are isolated per Attachment J VERIFY SI Fow (have NO SI flow due to NO SI pumps running)
VERIFY RHR Flow (have NO RHR flow due to high RCS pressure)
Armendix D Op~erator Actions Form or ES-D-2 SD-(R8, R,
$1) 51)
AIedi oIaorAton Op-Test No.: Scenario No.: 4 Event No.: 7 Page 12 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time I Position Applicant's Actions or Behavior 1E-0, "Reactor Trip or Safety Injection" BOP VERIFY > 200 gpm total AFW flow VERIFY > 900 psig on AFW Pumps Discharge VERIFY Status of Equipment in Auto Action Guide (Table EQ-1)
PLACE Steam Dump in "STEAM PRESSURE" Mode RO CHECK RCS temperature is stable at or trending to 547 0 F BOP CHECK RCP Cooling:
- VERIFY CC flow to each RCP > 150 gpm
- VERIFY thermal barrier outlet valves open (CV-31245 and CV-31246)
- VERIFY seal injection flow to RCPs is normal RO CHECK PRZR PORVs and Spray Valves:
- VERIFY PRZR PORVs are closed
- VERIFY PRZR Spray Valves are closed CHECK if RCPs Should Be Stopped (RCPs should be kept running, since have NO SI Pumps running)
BOP VERIFY SGs are NOT Faulted VERIFY SG tubes are NOT Ruptured SRO VERIFY RCS is NOT intact:
- TRANSITION to 1 E-1, "Loss of Reactor or Secondary Coolant"
Annp.ndix D Form ES-D-2 (R8, S1)
Appendix D O.e.rator ActionsForm....D.., 1 Op-Test No.:__ Scenario No.: 4 Event No.: 7 Page 13 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-I.1)
Time Position Applicant's Actions or Behavior 1 E-1, "Loss of Reactor or Secondary Coolant" SRO DIRECT actions per 1 E-1, "Loss of Reactor or Secondary Coolant" BOP VERIFY Steam Dump in "STEAM PRESSURE" Mode RO CHECK if RCPs Should Be Stopped:
- IF an SI Pump is running with flow indicated AND RCS pressure is < 1250 psig (1575 psig for Adverse Containment),
THEN STOP both RCPs BOP VERIFY SGs are NOT Faulted CONTROL AFW flow to maintain SG Narrow Range Levels between 5% and 50% (Wide Range Level between 50% and 59%
for Adverse Containment)
SRO VERIFY Secondary Side Radiation is Normal RO CHECK PRZR PORVs and Block Valves:
- VERIFY PRZR PORVs are closed
- VERIFY at least one PRZR PORV block valve is open
_ _ _I __ _ _ _ , __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Appendix D Op~erator Actions Form Appendix D Operator Actions Form ES-D-2 ES-D-2 ('R8.
(R8. S1)
Si)
Op-Test No.: __ Scenario No.: 4 Event No.: 7 Page 14 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time Position I Applicant's Actions or Behavior 1 E-1, "Loss of Reactor or Secondary Coolant" BOP RESET SI RESET Containment Isolation ESTABLISH Instrument Air to the Containment EVALUATOR NOTE:
IF Bus 16 power is NOT restored, THEN NO Charging Pump will have power. The crew should be attempting to restore offsite power to Bus 16 from IRY transformer per 1 C20.5 AOP2.
CHECK power supply to Charging Pumps is energized by offsite power (there is NO power until Bus 16 is restored)
- ATTEMPT to restore offsite power to Charging Pumps RO - WHEN at least one charging pump is running, THEN ESTABLISH charging flow CHECK if SI Can Be Terminated (can NOT terminate SI, since do NOT have RCS subcooling)
BOP VERIFY Containment Spray Pumps are Stopped EVALUATOR NOTE:
Will NOT be able to stop RHR Pumps in the next step until Bus 16 is restored and an SI Pump is running.
CHECK if RHR Pumps Should Be Stopped:
- IF RCS pressure is > 250 psig (550 psig for Adverse Containment) AND RCS pressure is stable or increasing, THEN STOP both RHR pumps
Appendix D Operator Actions Form or ES-D-2 S--
('R8, (R8 S S1)
Apeni DOertoIctos Op-Test No.: Scenario No.: 4 Event No.: 7 Page 15 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time Position I Applicant's Actions or Behavior 1 E-1, "Loss of Reactor or Secondary Coolant" RO/BOP CHECK RCS and SG Pressures BOP CHECK if DGs Should Be Stopped CHECK if Safeguards Cooling Water Pumps Should Be Stopped CHECK if Outside Air Can Be Supplied to Control Room VERIFY Containment Dome Recirculation Fans are Running SRO CHECK Auxiliary Building Radiation is Normal SRO DIRECT local operator to align Containment FCU Cooling Water Outlet Radiation Monitors R-1 6 and R-38:
- DIRECT local operator to open valves RD-6 and 2RD-4-2 CUE: Valves RD-6 and 2RD-4-2 are open BOP - VERIFY solenoid isolation valves SV-33384 and SV-33907 are open BOP CHECK if Containment Hydrogen Recombiners Should Be Placed in Service SRO CHECK if RCS Cooldown and Depressurization is Required:
- TRANSITION to 1 ES-1.1, "Post LOCA Cooldown and Depressurization"
Appendix D Orperator Actions Appedix Oprato ActonsForm ES-D-2 (R8. S-1)
Op-Test No.: __ Scenario No.: 4 Event No.: 7 Page 16 of 18 Event
Description:
Small break LOCA (500 gpm) on Reactor Trip (requires use of E-0, E-1, and ES-1.1)
Time Position Applicant's Actions or Behavior 1ES-1.1, "Post LOCA Cooldown and Depressurization" BOP VERIFY all AC Buses Energized by Offsite Power EVALUATOR NOTE:
Will NOT be able to stop RHR Pumps in the next step until Bus 16 is restored and an SI Pump is running.
CHECK if RHR Pumps Should Be Stopped:
- IF RCS pressure is > 250 psig (550 psig for Adverse Containment) AND RCS pressure is stable or increasing, THEN STOP both RHR pumps RO CHECK Charging Pump Status:
- ALIGN charging pump suction to RWST (OPEN MV-32060)
- WHEN at least one charging pump is running, THEN ESTABLISH maximum charging flow BOP CHECK Intact SG Levels:
- CONTROL AFW flow to maintain Narrow Range Level between 5% and 50% (Wide Range between 50% and 59% for Adverse Containment)
INITIATE RCS Cooldown to Cold Shutdown:
- MAINTAIN cooldown rate in RCS cold legs < 100°F/HR
- DUMP steam to condenser TERMINATE SCENARIO when RCS cooldown is established
Appendix D Operator Actions Form ES-D-2 (R8, S1)
Op-Test No.: __ Scenario No.: 4 Event No.: 8 Page 17 of 18 Event
Description:
Bus 16 deenergizes due to breaker failure from CT-1 1 transformer, with a concurrent sequencer failure. Diesel Generator D2 trips during start.
(will need to reenergize Bus 16 from 1 RY transformer per 1C20.5 AOP2, since have NO SI flow, since have NO SI pumps or PD Char qinq pumps)
Time I Position Applicant's Actions or Behavior Reenergizing Bus 16 from 1RY Transformer per 1C20.5 AOP2 CRITICAL TASK: Reenergize Bus 16 from 1 RY transformer EVALUATOR NOTE:
The following annunciators will alarm when Bus 16 is lost and Diesel Generator D2 fails to start:
- 47024-0204, "BUS 16 4.16 KV UNDERVOLTAGE"
- 47024-0304, "BUS 16 4.16 KV DEGRADED VOLTAGE"
- 47024-0504, "BUS 16 BKR 8 SOURCE FROM BUS CT 11 TRIPPED"
- 47024-0805, "D2 EMERGENCY GENERATOR FAILURE TO START" BOP RECOGNIZE the loss of bus 16, the failure of the Load Sequencer, and the trip of Diesel Generator D2 SRO DIRECT actions to restore Bus 16 per the Alarm Response Procedures and 1C20.5 AOP2, "Reenergizing 4.16KV Bus 16" RECORD Control Room alarms associated with Bus 16 deenergization DIRECT local operator to determine bus protective relay targets and status of bus and breakers CUES:
- Local operator reports:
"* There are NO relay flags present on Bus 16 (except for the UV relays in the sequencer cabinet)
"° There is NO apparent reason why the CT-1 1 breaker opened
- IF Engineer contacted, THEN recommend reenergizing Bus 16 using 1RY transformer until the cause of the CT-11 breaker malfunction is determined EVALUATOR NOTE:
IF the crew decides to try to energize Bus 16 from CT-1 1, THEN the CT-i1 breaker will trip when trying to close in
Appendix D Operator Actions Form ES-D-2 (R8, $1)
Op-Test No.: Scenario No.: 4 Event No.: 8 Page 18 of 18 Event
Description:
Bus 16 deenergizes due to breaker failure from CT-1 1 transformer, with a concurrent sequencer failure. Diesel Generator D2 trips during start.
(will need to reenergize Bus 16 from 1 RY transformer per 1C20.5 AOP2, since have NO SI flow, since have NO SI pumps or PD Charging pumps)
Time Position Applicant's Actions or Behavior Reenergizing Bus 16 from IRY Transformer per 1C20.5 AOP2 SRO DETERMINE that CT-1 1 feeder breaker to Bus 16 opened BOP PLACE Bus 16 Voltage Restoration Switch in "MANUAL" PLACE the three(3) Bus 16 feeder breaker closure selector switches in "MANUAL" PLACE Bus 16 loads in "PULLOUT" PLACE Bus 16 Synchroscope Selector Switch to "1RY" CLOSE Breaker 16-2 (Bus 16 Source from 1 RY Transformer) to reenergize Bus 16 VERIFY Bus 16 between 4000-4400 volts PLACE Bus 16 Synchroscope Selector Switch to "OFF" RESTORE power to 480V Buses 121 and 122:
- VERIFY Breakers 121A and 122A are open
- VERIFY Breakers 121M and 122M are closed
- CLOSE Breaker 16-4 (Bus 16 feed to 121 M Transformer) to reenergize Bus 121
- CLOSE Breaker 16-11 (Bus 16 feed to 122M Transformer) to reenergize Bus 122 RESTORE Bus 16 loads:
- START 12 SI Pump CRITICAL TASK: START 12 Sl Pump
SCENARIO #4 Initial Conditions:
Unit 1:
- 50% power, Beginning of Cycle, Equilibrium Xenon
- 11 SI Pump is OOS (on hour 16 of a 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> clock, expected back in 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br />)
- 12 Charging Pump is OOS for overhaul
- Breaker 16-10 (Bus 16/Bus 26 Bustie) is OOS Unit 2:
- 100% power steady state operation Turnover:
- Perform power increase on Unit 1 to 100%
- Are presently at Step 5.21 .E of 1C1.4, "Unit 1 Power Operation" at the step to start the second feedwater pump per 1C28.2, "Unit 1 Feedwater System"
- Steps 5.5.1 through 5.5.8 of Section 5.5 of 1C28.2 have been completed in preparation for starting the 12 FW Pump
- A local operator is available by the 12 FW Pump to perform any required actions during the pump startup