AOPs

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heidin
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AOPs
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2012-07-10 12:53:36
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  1. Following a Loss of Off-Site power to Unit One, the operator is performing AOP·36.1.

    Plant conditions are:

    Diesel Generator 1 Running at 3640 KW load
    Diesel Generator 2 Running at 3750 KW load
    Reactor 8uilding HVAC Isolated
    The operator is directed to start Reactor 8uilding HVAC using 3 Supply Fans and 3 Exhaust Fans.

    How would starting Supply Fans 1A, 18 and 1C, and Exhaust Fans 1A, 18, and 1C affect maximum DG loading?

    A. DG1 only load limit would be exceeded.
    B. DG2 only load limit would be exceeded.
    C. DG1 and DG2 load limits would both be exceeded.
    D. DG1 and DG2 would both remain within load limits.
    C. DG1 and DG2 load limits would both be exceeded.


    Max load limit is 3850. Rx 81dg supply fans (75 KW each) 1A and 1C, and exhaust fans (45 KW each) 1A and 1C are from MCC 1XG (E1). This would add 240 KW to DG1 and bring total load to 3880 (in excess of limit). Rx B1dg supply and exhaust fans 18 are from MCC 1XH (E2) and would add 120 KW to DG2 bringing total load to 3870 (also in excess of limit).
  2. Unit Two is at rated power with the following plant conditions:

    All control rods are OPERABLE
    Rod select power is OFF
    Control rod 10-27 scrams
    ROD DRIFT alarm is received

    Which one of the following identifies the status of the ROD OUT BLOCK annunciator and also identifies the procedure that contains the action for the operator to reduce core flow to 65 Mlbs/hr?


    A. ROD OUT BLQCK Annunciator is alarming;
    2APP-A-05, 3-2 ROD DRIFT.

    B. ROD OUT BLOCK Annunciator is alarming;
    0AOP-02.0, Control Rod Malfunction/Misposition.

    C. ROD OUT BLOCK Annunciator is NOT alarming;
    2APP-A-05, 3-2 ROD DRIFT.

    D. ROD OUT BLOCK Annunciator is NOT alarming;
    0AOP-02.0, Control Rod Malfunction/Misposition.
    D. ROD OUT BLOCK Annunciator is NOT alarming; 0AOP-02.0, Control Rod Malfunction/Misposition.


    A Rod Drift alarm is generated if an odd numbered reed switch is picked up with no "rod selected and driving" signal present. An inadvertant rod scram will cause a rod drift alarm. Below the LPAP, a rod drift scram can cause a rod insert/withdraw from the RWM. This error will cause a Rod Block RWM alarm on A-5 (5-2). The given plant conditions are above the LPAP. No Rod Out Block alarm or Rod Block RWM alarm will be received. Per the direction of AOP-2.0, supplementary action 3.2.2, "IF greater than 25% RTP and the sum of scrammed and inoperable control rods is no more than eight, then REDUCE core flow to 65 mlbs/hr.
  3. Unit One is operating at power. A transient in the 230 KV switchyard results in the trip of one Reactor Recirculation Pump.

    Plant conditions are:

    Reactor power 50%
    Core flow (WTCF) 30.5 Mlbs/hr
    Feedwater temperature 370°F
    OPRMs Operable

    What action is required by 1AOP-04.0?

    A. Insert a manual reactor scram.
    B. Insert control rods to exit region B.
    C. Insert control rods to exit the scram avoidance region.
    D. Monitor for THI and minimize time spent in the OPRM enabled region.
    C. Insert control rods to exit the scram avoidance region.
  4. Unit One is operating at power. A transient in the 230 KV switchyard results in the trip of one Reactor Recirculation Pump. Plant conditions are:

    Reactor power 50%
    Core flow (WTCF) 31.5 Mlbs/hr
    Feedwater temperature 370°F
    OPRMs Inoperable

    What action is required by 1AOP-04.0?

    A. Insert a manual reactor scram.
    B. Insert control rods to exit region B.
    C. Insert control rods to exit the scram avoidance region.
    D. Monitor for THI and minimize time spent in the 5% buffer region.
    B. Insert control rods to exit region B.
  5. Following a loss of the Uninterruptible Power Supply system, a Reactor scram occurs. Indications on P603:

    APRM/IRM Recorders Indicating 100%
    APRM Downscales Lights illuminated
    SRM Recorders Indicating pre-scram count rate
    SRM Periods Indicating - 80 seconds
    Control Rods positions Unknown

    ERFIS and Process Computer are not available. What is the current status of the Reactor?

    A. Reactor power cannot be determined.
    B. Reactor power can be determined to be <4% from the RTGB.
    C. Reactor power can be determined to be <4% only from the back panels.
    D. Reactor can be determined to be shutdown under all conditions without boron.
    B. Reactor power can be determined to be <4% from the RTGB.


    • Loss of the UPS power supply will require monitoring of the SRM or IRM channels from the control room back panels. Loss of the SRM or IRM System will have no effect on the UPS System. SD-09.1
    • The UPS Distribution System provides power to the IRM recorders, the combined APRM/RBM paper-less recorders, the APRM Operator Display Assemblies, and the RBM Operator Display Assemblies at Panel P603 through Panel V7A (Circuit #2). Loss of power from Panel V7A (Circuit #2) will require monitoring the APRM channels from the APRM NUMAC at P608. SD-09.6
    • A loss of Instrument Bus 1AB (Circuit #9) will result in a loss of power to the P603 apron section indicating lights and the recirculation flow recorder. SD-09.6
    • 0OI-50.5
  6. A Category 4 hurricane is making landfall near Southport. Sustained winds of 75 mph are currently present on site. The storm surge has raised intake canal level to +20 feet MSL.

    In accordance with AOP·13.0, both units should be placed in:

    A. Mode 3 within two hours due to intake canal level reaching +20 feet MSL. Entry into Mode 4 is not required.
    B. Mode 3 within two hours due to sustained winds on site in excess of 73 mph. Entry into Mode 4 is not required.
    C. Mode 4 within two hours due to intake canal level reaching +20 feet MSL. Plant conditions must be maintained to allow entry into Mode 3 during the storm.
    D. Mode 4 within two hours due to sustained winds on site in excess of 73 mph. Plant conditions must be maintained to allow entry into Mode 3 during the storm.
    C. Mode 4 within two hours due to intake canal level reaching +20 feet MSL. Plant conditions must be maintained to allow entry into Mode 3 during the storm.
  7. Determine which one of the following conditions requires a plant shutdown per 0AOP-13.0, Operation During Hurricane, Flood Conditions, Tornado, or Earthquake.

    A. A seismic event at minimum detectable levels is annunciated and confirmed.
    B. Hurricane surge level is expected to reach 20 feet above MSL.
    C. Brunswick County enters into a Tropical Storm Warning.
    D. A tornado has been observed on plant site.
    B. Hurricane surge level is expected to reach 20 feet above MSL.
  8. Hurricane Marcus will make landfall at the nouth of the Cape Fear River within the next 4 hours with the following conditions:

    Hurricane Marcus is a category 4 hurricane
    Landfall is at high tide and flood conditions are expected at the site

    Which one of the following describes actions required by AOP-13, Operations During Hurricane, Flood Conditions, Tornado, or Earthquake, in response to these conditions:


    A. Maintain plant conditions to allow unit shutdown to Mode 2 during the storm.
    B. Maintain station batteries on equalizing charges until the hurricane warning is lifted.
    C. Assign Operators to the Diesel Generator and Service Water Buildings with a supply of food.
    D. Pump the Storm Drain Basin directly to the Discharge Canal as required to maintain the Storm Drain Basin hi level alarm clear.
    C. Assign Operators to the Diesel Generator and Service Water Buildings with a supply of food.
  9. A fuel bundle was dropped in the spent fuel pool and 0AOP-5.0, Radioactive Spills, High Radiation, and Airborne Activity, has been entered.

    The following alarms are received:

    AREA RAD REFUEL FLOOR HIGH (UA-03 3-7)
    PROCESS RX BLDG VENT RAD HI (UA-03 4-5)
    RX BLDG ROOF VENT RAD HIGH (UA-03 2-3)

    Which one of the following predicts the plant response and also identifies the required procedure implementation?

    A. Secondary Containment has automatically isolated;
    Execute 0AOP-5.0 and RRCP concurrently.
    B. Secondary Containment has automatically isolated;
    Execute RRCP and Exit 0AOP-5.0.
    C. Secondary Containment has NOT automatically isolated;
    Execute 0AOP-5.0 and RRCP concurrently.
    D. Secondary Containment has NOT automatically isolated;
    Execute RRCP and Exit 0AOP-5.0.
    C. Secondary Containment has NOT automatically isolated; Execute 0AOP-5.0 and RRCP concurrently.
  10. Unit Two has recently transitioned from Mode 3 to Mode 4 and placed the second RHR Loop in Shutdown Cooling per OP-17. RPS MG set 2A trips and all automatic actions occur as expected. The crew is executing AOP-15.0 to restore shutdown cooling, but is having difficulty re-opening the inboard suction isolation valve (E11-F009). Reactor water level is 215".

    What method is available to monitor reactor coolant temperature for indications of a mode change to Mode 3?

    A. Reactor vessel pressure.
    B. Reactor bottom head temperature.
    C. Reactor recirculation loop temperature.
    D. RWCU reactor water inlet temperature.
    A. Reactor vessel pressure.


    Since RHR shutdown cooling two loop mode had been established, both Recirc pumps would have to have been secured. When RPS A trips the inboard isolation valve F009 (and also loop A injection valve F015A) would close and all running RHR pumps would trip on no suction path. With no RHR or Recirc pumps running, only natural circulation flow would exist in the reactor. Per caution in AOP-15, natural circulation cannot be relied upon to provide sufficient flow through bottom head or recirc loops for temperature indication; therefore, pressure should be monitored for indications of mode change. RWCU would also isolate on the RPS power loss and there would be no flow past the temperature elements.
  11. Alternate shutdown cooling using SRV's has been established per AOP-15.0. Plant conditions are:

    RHR Loop A in suppression pool cooling
    RHR Loop B injecting to the reactor
    Reactor pressure is 115 psig
    SRV B21-F013G is open

    It becomes desired to make an adjustment to lower the cool down rate. This can be accomplished per AOP-15.0 by closing 821-F013G and opening:

    A. B21·F013A.
    B. B21·F013J.
    C. B21·F013K.
    D. B21·F013L.
    C. B21·F013K.


    Per table in AOP-15.0, SRV K is in block below SRV G in the column for RHR Pump B/D. SRV A would be picked if using the column for RHR A/C but should not be used as this is not the loop that is injecting. SRV J is below SRV G but should not be picked as the cooldown rate will be equivalent per note above table, SRV L is in block above SRV G and would increase cooldown rate.
  12. Following a loss of shutdown cooling, on Unit Two (2), Alternate Shutdown Cooling has been established per AOP-15.0. Plant conditions are:

    RHR Loop A in suppression pool cooling
    RHR Loop B injecting to the Reactor Vessel
    Reactor pressure is 115 psig
    SRV G is OPEN

    The Operator desires to make a slight adjustment to raise the cooldown rate. This is accomplished by CLOSING SRV G and OPENING the next SRV in sequence, which is SRV __________.

    A. C
    B. J
    C. K
    D. L
    D. L


    Per AOP-15.0 steps 3.2.7 and 3.2.14, “L” is next in line for RHR Loop B (injecting loop) to raise cooldown rate, “J” is correct to lower cooldown rate, “C” is not correct as this would not be a slight adjustment, “K” would be correct if Core Spray (either loop) was injecting.
  13. During alternate shutdown cooling operation per AOP-15, RHR is injecting to the RPV with one SRV open.

    An additional SRV must be opened if RPV pressure increases to >164 above suppression chamver pressure. This action will prevent:

    A. Cooldown rate in excess of limits.
    B. Damage to the open SRV’s tailpipe.
    C. Insufficient flow rate to the reactor vessel.
    D. Overpressurization of the RHR system suction piping.
    C. Insufficient flow rate to the reactor vessel.


    If reactor prssure increases to 164 psig above Suppression Pool pressure, then a secong sRV is opened. This pressure is the shutoff head of the RHR pump and if exceeded could prevent flow to the reactor.
  14. Unit Two (2) is in Alternate Shutdown Cooling per AOP-15.0, with the following plant conditions:

    - RHR Loop A injecting to the reactor vessel
    - RHR Loop B in suppression pool cooling
    - SRV B open

    Which one of the following manipulations would the crew make in order to raise the cooldown rate?

    A. Close SRV B and then open SRV D.
    B. Close SRV B and then open SRV J.
    C. open SRV D and then close SRV B.
    D. open SRV J and then close SRV B.
    B. Close SRV B and then open SRV J.
  15. Unit Two is operating at power. The following alarms and indications are observed:

    Service Air Press Low (UA·1 5-4) sealed in
    Inst Air Press Low (UA-1 4-4) sealed in
    Air Compressors 2B and 2D are both running
    Service Air IsoI Vlvs SA-PV-706-1 & 2 are closed
    Instrument air header pressure indicates 98 psig, slowly lowering

    An AO reports a leak on the interruptible instrument air header. What action is
    required?

    A. Close IA-PV·722-1 &2. This action may result in a scram due to low reactor water level.
    B. Close IA·PV-722·1 & 2. This action may result in a scram due to scram valves drifting open.
    C. Close IAN-V50 and IAN-V51. This action may result in a scram due to low reactor water level.
    D. Close IAN-V50 and IAN-V51. This action may result in a scram due to scram valves drifting open.
    A. Close IA-PV·722-1 &2. This action may result in a scram due to low reactor water level.


    AOP-20.0 should be entered. This procedure directs isolating interruptible air by closing IA-PV-722-1 & 2 if pressure is below 100 psig, there is a known leak on the interruptible header, and continued operation would be detrimental to the plant. Since pressure is lowering with both available compressors running, continued operation would be detrimental. Closing 722·1 & 2 will take air away from condensate/feedwater recirc valves, heater drain discharge valves and CDD and CFD valves resulting in potential for scram from loss of vessel level control. Scram valves are from the non-interruptible header and have an air supply since standby compressors are running. Isolating non-interruptible header (IAN·V50 & V51) will do nothing to isolate the leak.
  16. Unit Two is operating at 100% power. The following sequence of events occur:

    At 1205, Gen Under Freq Relay (UA-06 1-2) alarms
    At 1207, Generator frequency drops to 59.3 Hz
    At 1209, Generator frequency stabilizes at 58.5 Hz
    What action is required by AOP·22.0 if frequency remains at 58.5 Hz?

    A. At 1210, trip the main turbine and ensure the reactor auto scrams.
    B. At 1210, manually scram the reactor and then trip the main turbine.
    C. At 1212, trip the main turbine and ensure the reactor auto scrams.
    D. At 1212, manually scram the reactor and then trip the main turbine.
    B. At 1210, manually scram the reactor and then trip the main turbine.


    59.3 Hz starts a 5 minute maximum allowable time limit. This would require action at 212; however, when frequency drops to 58.5, this starts a one minute maximum time which requires action at 1210. Whenever a turbine trip is required (above 26%), a manual scram is inserted first per Conduct of Operations Manual (01-01.02).
  17. Unit 2 is at 85% power when the following conditions are observed:

    REACTOR WATER LEVEL HIGH/LOW (A-07, 2-2) alarming.
    C32-LI-N004 A/B/C indicate +192 inches, rising slowly.

    RFPT A SP CTL, (C32-SIC-R601A) output signal rising.
    RFPT B SP CTL, (C32-SIC-R601B) output signal lowering.

    What action should be taken?


    A. Place MSTR RFPT SP/RX LVL CTL, C32-SIC-R600, in manual and trip RFP A.
    B. Place MSTR RFPT SP/RX LVL CTL, C32-SIC-R600, in manual and trip RFP B.
    C. Place RFPT A SP CTL, C32-SIC-R601A, in manual and adjust output to stabilize RPV level.
    D. Place RFPT B SP CTL, C32-SIC-R601B, in manual and adjust output to stabilize RPV level.
    C. Place RFPT A SP CTL, C32-SIC-R601A, in manual and adjust output to stabilize RPV level.
  18. Unit 1 is operating at 90% power. RFP “A” just tripped and RPV level lowered to 175 inches before stabilizing.

    The RO observes the following indications:

    RPV Water level 178 inches rising slowly
    TOTAL CORE FLOW lowering
    RECIRC FLOW A LIMIT APP A-06 3-2 lit
    RECIRC LOOP A FLOW 52% lowering
    RECIRC LOOP B FLOW 82% steady

    Valid core flow indication is available from the process computer and no other equipment out of service.

    What action is required?

    A. Insert a Manual Runback 
    B. Reduce the “B” Recirc pump speed manually to 32%.
    C. Reduce the “B” Recirc pump speed manually to 45%.
    D. Reduce the “B” Recirc pump speed manually to 48%.
    C. Reduce the “B” Recirc pump speed manually to 45%.


    • · APP-A-06 3-2: 182”; A or B > 16.4% - limiter #2 (~42%)
    • · 0AOP-23: if auto (runback) didn’t happen, manually reduce to 45%(U1), 48%(U2)
  19. Unit Two (2) plant conditions are:

    Rx power 96%
    Supp Pool Water temp 92°F
    Supp Pool heatup rate 0.25 °F/hr
    SRV C leaking

    The required action is to:

    A. Enter and execute each leg of EOP-02-PCCP concurrently.
    B. Place Suppression pool cooling in service and consider a plant shutdown.
    C. Pull fuses for this SRV and scram the reactor if the SRV continues to leak.
    D. Cycle the SRV control switch and scram the reactor if the SRV continues to leak.
    B. Place Suppression pool cooling in service and consider a plant shutdown.
  20. Unit One (1) is operating at 100% power with Digital Feedwater (DFCS) in Automatic, 3 element with a level demand of 187”.

    A Safety Relief Valve fails open. DFCS shifts to single element control. Reactor water level will initially:

    A. rise, then control level below 187”
    B. Lower, then control level below 187”
    C. rise, then control level at about 187”
    D. lower, then control level at about 187”
    C. rise, then control level at about 187”

    Initial rise due to swell associated with SRV operation, with DFCS shifting to single element level will return to about normal level controlled by level set only. 0AOP-30
  21. The SS determined that Control Room evacuation was required due to toxic gas. Prior to leaving the Control Room, a manual scram was inserted, however, no other Control Room actions were taken.What action is required after evacuating the Control Room?

    A. Open the RPS MG set supply breakers at the MCC.
    B. Open the six RPS power supply EPA breakers.
    C. Trip the main turbine at the front standard.
    D. Locally emergency start the diesel generators.
    B. Open the six RPS power supply EPA breakers.
    (this multiple choice question has been scrambled)
  22. The Shift Superintendent has determined that Control Room Evacuation is required. A manual Reactor Scram has been inserted.What is the correct SEQUENCE of immediate operator actions following the manual scram?


    A. Place the Mode Switch to shutdown, trip the turbine, verify or manually transfer auxiliary power to the SAT.
    B. Place the Mode Switch to shutdown, verify or manually transfer auxiliary power to the SAT, trip the turbine.
    C. Trip the turbine, place the Mode Switch to shutdown, verify or manually transfer auxiliary power to the SAT.
    D. Trip the turbine, verify or manually transfer auxiliary power to the SAT, place the Mode Switch to shutdown.
    A. Place the Mode Switch to shutdown, trip the turbine, verify or manually transfer auxiliary power to the SAT.
    (this multiple choice question has been scrambled)
  23. During execution of AOP-32.0, "Plant Shutdown From Outside Control Room,” the AUTO/MAN control switches for the condensate booster pumps are placed in the MAN (manual) position. Which one of the following is the reason for this action?

    A. Ensures the pumps can be manually started from the 4160 bkr in the turbine building
    B. Allows the idle booster pump(s) discharge valve(s) to open and to ensure a condensate/feedwater flowpath.
    C. Prevents injection from the condensate system when the condensate booster pumps are secured.
    D. Prevents an auto-trip from occurring on all condensate booster pumps which are already in service.
    C. Prevents injection from the condensate system when the condensate booster pumps are secured.
  24. While performing AOP-32.0, the following Reactor pressure readings were recorded at the indicated times:

    1200: 1000 psig
    1300: 425 psig1400: 100 psig1500: 25 psig
    Is the Reactor cooldown rate within Technical Specification limits?

    A. Yes, limits have not been exceeded.
    B. No, limits were exceeded between 1200 and 1300.
    C. No, limits were exceeded between 1300 and 1400.
    D. No, limits were exceeded between 1400 and 1500.
    C. No, limits were exceeded between 1300 and 1400.
  25. While performing AOP-32.0, the following Reactor pressure readings were recorded at the indicated times:

    1200: 1000 psig
    1300: 450 psig
    1400: 175 psig
    1500: 25 psig

    Is the Reactor cooldown rate within required limits?

    A. Yes, limits have not been exceeded.
    B. No, limits were exceeded between 1200 and 1300.
    C. No, limits were exceeded between 1300 and 1400.
    D. No, limits were exceeded between 1400 and 1500.
    D. No, limits were exceeded between 1400 and 1500.


    Using reactor saturation curve from AOP·32, @ 1000 psig, temperature is 550°F. @ 450 psig, temperature is 460°F (90°F between 1200-1300). @ 175 psig, temperature is 380°F (80°F between 1300 and 1400), and @ 25 psig, temperature is 270°F (110°F between 1400 and 1500), which violates procedurally required and Tech Spec limit of 100°F/hr.
  26. While reducing reactor pressure to place Shutdown Cooling in service in accordance with 0AOP-32.0, Plant Shutdown from Outside Control Room, the following reactor pressure readings were recorded at the indicated times:

    1200 1000 psig
    1300 425 psig
    1400 100 psig
    1500 25 psig

    Which one of the following choices completes the following statement?

    The reactor cooldown rate specified in OAOP-32.0:

    A. has not been exceeded
    B. was exceeded between 1200 and 1300
    C. was exceeded between 1300 and 1400
    D. was exceeded between 1400 and 1500
    C. was exceeded between 1300 and 1400
  27. A line break on Unit Two caused a scram on high drywell pressure. Off-site power was then lost. DG4 is tripped and E2-E4 are being cross-tied per AOP-36.1. The following sequence of events occurs:

    1200 Reactor water level drops below LL2
    1202 Bus E2 cross-tie breaker is placed to Maint
    1204 Reactor water level drops below LL3
    1206 Bus E4 cross-tie breaker is placed to Maint

    What is the earliest time that E4 can be energized?

    A. 1206.
    B. 1212.
    C. 1214.
    D. 1216.
    D. 1216.


    In the Maint position, there is a 10 minute trip on LOCA signal from either unit. The 10 minute timer cannot start until the breaker is placed to Maint since there is no DC control power with the switch in Norm. The bus E2 breaker 10 minute timer will not start when the switch is placed to maint since there is not yet a LOCA signal. the LOCA signal is received at 1204 which starts the 10 minute timer for the E2 breaker (which can be closed at 1214). The timer for the E4 breaker starts at 1206 so that breaker cannot be closed until 1216. 1206 would be correct if no LOCA signal or SSO position was used.
  28. Following a dual unit loss of off-site power, electrical status is as follows:

    DG1 is tied to El
    DG2 is tripped/unavailable
    DG3 is under clearance
    DG4 is tied to E4

    A line break in the Unit One drywell requires EOP actions that depend on power from E2/E6. Which of the following is correct per AOP-36.1?


    A. E2-E4 should not be cross-tied because DG2 tripped. Proceed with crosstie of E5-E6.
    B. Verify there is no fault indication on E2 per Attachment 5, then proceed with cross-tie of E2-E4.
    C. Verify there is no fault indication on E4 per Attachment 5, then proceed with cross-tie of E2-E4.
    D. E2-E4 should not be cross-tied due to limited power availability. Proceed with crosstie of E5-E6.
    D. E2-E4 should not be cross-tied due to limited power availability. Proceed with crosstie of E5-E6.


    For crosstie of 4KV Buses, the procedure requires verification of no indication of fault on the de-energized bus (E2). If DG2 tripped due to electrical lockout, crosstie is not permitted, but DG2 tripping does not necessarily prohibit crosstie since the engine may have a trip without generator lockout. The procedure also requires the Unit supplying power through the crosstie have ample power availability either from off-site power or from both DGs. Since DG3 is under clearance, this requirement is not met, and crosstie can only be performed at the 480V level.
  29. During a Unit 2 shutdown while transferring BOP buses from the UAT to the SAT, BOP Bus 2C is lost due to a breaker failure.

    0AOP-36.1 automatic actions requiring verification include auto start of Diesel Generator #:


    A. 3, energization of Bus E3 and a full Groups 2, 3, 6, 8 and 10 isolation.
    B. 4, energization of Bus E4 and a full Groups 2, 3, 6, 8 and 10 isolation.
    C. 3, energization of Bus E3 and a full Group 3 isolation with a partial Groups 2, 3, 6, 8 and 10 isolation.
    D. 4, energization of Bus E4 and a full Group 3 isolation with a partial Groups 2, 3, 6, 8 and 10 isolation.
    D. 4, energization of Bus E4 and a full Group 3 isolation with a partial Groups 2, 3, 6, 8 and 10 isolation.
  30. Unit One is operating at full power with the following plant conditions:

    Suppression Pool 96° F due to HPCI Surveillance
    RHR B Loop in SPC (B/D pumps running)
    RHRSW B Loop in service (B/D pumps running)

    A Loss of Offsite Power (LOOP) occurs on both Units and DG2 fails to start.

    Which one of the following identifies the impact of the LOOP on the 1-E11-F024B and the 1D RHR Pump and also identifies the required action in accordance with 0AOP-36.1, Loss of any 4160V Buses or 480V E-Buses, to support EOP actions?

    A. 1-E11-F024B Valve only has lost power.
    Crosstie E2 to E4.
    B. 1-E11-F024B Valve only has lost power.
    Crosstie E1 to E2.
    C. 1-E11-F024B Valve and the 1D RHR pump have lost power.
    Crosstie E2 to E4.
    D. 1-E11-F024B Valve and the 1D RHR pump have lost power.
    Crosstie E1 to E2.
    • C. 1-E11-F024B Valve and the 1D RHR pump have lost power.
    • Crosstie E2 to E4.

    With DG2 under clearance it will de-energize on the loss of offsite power; both RHR and RHR SW pumps D lose power. B NSW pump loses power and the A pump will auto start. CSW pumps lose power due to the LOOP. The RHR Loop B (F024) valve loses power.
  31. Following a loss of off-site power to both units, plant conditions are:

    DG1 is running tied to E1
    DG2 is running tied to E2
    DG3 is tripped on differential overcurrent (B6DP tripped)
    DG4 is tripped on low lube oil pressure (engine lockout tripped)

    What action is required by AOP-36.2?

    A. Cross-tie E1 to E3. and cross-tie E2 to E4 .
    B. Cross-tie E1 to E3, do not cross-tie E2 to E4.
    C. Cross-tie E2 to E4. do not cross-tie E1 to E3.
    D. Do not cross-tie E1 to E3, do not cross-tie E2 to E4.
    C. Cross-tie E2 to E4. do not cross-tie E1 to E3.
  32. During a Station Blackout, RPV cooldown is in progress on the Blacked Out Unit with the following RPV pressures recorded at the indicated times:

    0130 960 psig
    0145 730 psig
    0200 630 psig
    0215 460 psig
    0230 330 psig

    Per AOP-36.2, the cooldown rate over the last hour is:

    A. <100°F. The cooldown should be stopped.
    B. >100°F. The cooldown should be stopped.
    C. <100°F. The cooldown should be continued.
    D. >100°F. The cooldown should be continued.
    D. >100°F. The cooldown should be continued.


    Cooldown is 110°F over the last hour (per attachments in AOP-36.2 and/or steam tables). This is in excess of the normal Tech Spec limit of 100°F/hr, but a cooldown of >100°F/hr is directed by AOP-36.2 due to loss of drywell cooling. this cooldown is required until reactor pressure is <300 psig; therefore, the cooldown should be continued.
  33. Unit Two is in a Station Blackout. E Buses are being cross-tied. The Reactor is being
    cooled down at 105°F/Hr. The following Drywell Temperature readings are reported from the Remote Shutdown Panel:

    CAC·TR-778, Point 1 315°F
    CAC-TR-778, Point 3 303°F
    CAC-TR-778. Point 4 285°F

    Average Drywell Temperature is:

    A. below 300°F. Lower cooldown rate to S1OO°F.
    B. above 300°F. Maintain cooldown rate >100°F.
    C. below 300°F. Maintain cooldown rate>100°F.
    D. above 300°F. Perform emergency depressurization.
    C. below 300°F. Maintain cooldown rate>100°F.
  34. Following a dual unit Loss of Offsite Power, which one of the following is the first makeup source to be used for filling the fuel pool in accordance with 0AOP-38.0, Loss of Fuel Pool Cooling?

    A. Demin water header stations
    B. Fire Protection Hose Stations
    C. Condensate transfer pumps
    D. Emergency Diesel Makeup Pump via hoses
    B. Fire Protection Hose Stations


    The preferred order of the makeup sources is from the normal fill, Demin water hose stations, Fire protection hose stations, and then other sources that are not service water. With a LOOP the demin pumps have no power, so Fire protection must be used.
  35. During a Station Blackout on Unit Two (2), HPCI and RCIC are not available. Plant conditions are:

    RPV level is -65 inches
    RPV pressure is 900 psig
    EDG #2 is the only operating DG
    EDG #4 is tripped on overcurrent
    Drywell ref leg area temp is 255°F

    An AO has dispatched to align Fire Protection for injection.

    The reactor should be emergency depressurized:


    A. Immediately
    B. only after RPV level drops below -70 inches
    C. only after RPV level drops below -75 inches
    D. only after RPV level drops below -85 inches
    C. only after RPV level drops below -75 inches


    RPV level <LL4, E11-F015B has power from DG2 and will open when RPV press < 400 psig.
  36. During a Station Blackout on Unit 2, HPCI and RCIC are not available. Plant conditions are:
    RPV level is -70 inches
    RPV pressure is 800 psig
    EDG #2 is the only operating DG
    EDG #4 is tripped on overcurrent
    Drywell ref leg area temp is 295°F

    Fire protection is reported to be aligned with the exception of the LPCI injection valve (E11-F015B).

    The reactor should be emergency depressurized:

    A. Immediately
    B. Only after RPV water level drops below -75 inches
    C. Only after RPV water level drops below -85 inches
    D. Only after E11-F015B has been opened
    A. Immediately
  37. Unit Two is operating at 19% power with the turbine on the turning gear when the following indications are observed:

    SJAE Trains Both in half load
    AOG System Outlet Flow 80 scfm and slowly rising
    Condenser Vacuum Slowly lowering
    Steam Seal header pressure 0 psig

    Which one of the following identifies the required operator action in acordance with 0AOP-37, Low Condenser Vacuum?


    A. Place B SJAE in full load
    B. Start the mechanical vacuum pump
    C. Throttle open MVD-S2, Steam Seal Bypass Valve
    D. Throttle open the SJAE Condensate Recirculation Valve, CO-FV-49
    C. Throttle open MVD-S2, Steam Seal Bypass Valve


    Increase in off gas flow is an indication of a loss of vacuum condition. Normal pressure of the steam seal header is 1.5 to 4 psig. Increased flow is in through the seals so by opening the steam seal bypas valve more steam would be applied to the seals inorder to provide sealing steam.
  38. Unit Two (2) was at 20% power during plant startup when a sudden rise in off gas flow is accompanied by a lowering condenser vacuum. The reactor was manually scrammed. Plant conditions:

    Condenser vacuum 15” Hg, slowly lowering
    Mode Switch Shutdown
    Main Turbine Tripped
    Reactor pressure 945 psig, steady
    Bypass valves One partially open

    The Low Condenser Vacuum Bypass switches have been placed to Bypass. When will automatic pressure be lost?

    A. When MSIVs auto close at 7” Hg.
    B. When MSIVs auto close at 10” Hg.
    C. When Bypass Valves auto close at 7” Hg.
    D. When Bypass Valves auto close at 10” Hg.
    C. When Bypass Valves auto close at 7” Hg.


    MSIVs remain open at 10 inches since all bypass conditons are met. BPVs close at 7” and this closure is not bypassed.0AOP-37.0
  39. Unit One (1) has entered AOP-38, Loss of Fuel Pool Cooling. What are the sources of make-up water to the Spent Fuel Pool, in the PREFFERRED order?


    A. Demineralized Water Header Stations, Demineralized water via the skimmer surge tanks, Fire Protecton Hose Stations, Alternate sources that are not Service Water.

    B. Demineralized water via the skimmer surge tanks, Demineralized Water Header Stations, Fire Protecton Hose Stations, Alternate sources that are not Service Water.

    C. Demineralized water via the skimmer surge tanks, Fire Protecton Hose Stations, Alternate sources that are not Service Water, Demineralized Water Header Stations.

    D. Demineralized Water Header Stations, Fire Protecton Hose Stations, Demineralized water via the skimmer surge tanks, Alternate sources that are not Service Water.
    B. Demineralized water via the skimmer surge tanks, Demineralized Water Header Stations, Fire Protecton Hose Stations, Alternate sources that are not Service Water.

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