LaSalle 2002 NRC - ILTandMe

#1. Given the following initial plant conditions: – An ATWS has occurred – The LGAs have been entered – SBLC pump is injecting boron into the core – Reactor power is 20% and oscillating – SRVs controlling RPV pressure at 900 psig – RPV level was lowered to -80 inchesAs required by LGAs; reactor water level is being lowered to . . .

a. concentrate the boron thus lowering the reactor power level.

b. decrease natural circulation driving head and core flow thereby increasing core voiding.

c. decrease reactor pressure which will add negative reactivity due to reduced moderator density.

d. increase reactor water temperature which will add negative reactivity due to reduced moderator density.

#2. The Unit 1 Standby Gas Treatment (SBGT) system is out of service. The Unit 2 SBGT systemis available. Which of the following events would be a concern if the Unit 2 SBGT system wouldbecome inoperable? The inability to . . .

a. monitor Refuel Floor radiation levels.

b. maintain negative pressure in Primary Containment.

c. provide a controlled release path during a refuel accident.

d. provide pressure control between clean and contaminated areas within the reactor building.

#3. Fuel handlers have informed the control room that the fuel dunking chamber is broken. As aresult; __________ evolutions will be delayed by this component” s failure.

a. core alteration

b. core verification

c. sipping fuel in spent fuel pool

d. movement of new fuel into spent fuel pool

#4. The following conditions exist on Unit 2: – Drywell pressure 2.5 psig – Undervoltage condition on Bus 242YThe 2A EDG started and loaded onto the bus. After several minutes; a local operator reportedannunciator 2DG03J-1-2; “OVERSPEED” alarmed.As NSO; you verify the 2A EDG . . .

a. shuts down engine ONLY

b. continues to power Bus 242Y

c. electrically unloads AND runs idle

d. shuts down engine AND opens output breaker to Bus 242Y

#5. Fuel Pool Radiation High-High annunciators were received. Operators found that Channels ” A” and ” B” have tripped. 1. Sufficient air flow obtained; the VG Electric Heater energizes 2. Procedure directs operator to shutdown the unaffected unit VG equipment train 3. Reactor Building ventilation trip 4. VG Cooling Fan will trip; if it was running 5. VG Cooling Fan starts 6. Initiation signal starts the VG Primary Fan; the fan start signal opens the VG inlet; then outlet isolation dampers 7. No further actionFrom the above list; the expected actions in the expected sequence will be . . .

a. 7 only

b. 3;7 only

c. 3;6;1;4;2;7 only

d. 3;6;5;2;7 only

#6. Surveillance test; LIS-RI-112; “UNIT 1 REACTOR VESSEL HIGH WATER LEVEL 8 RCICTURBINE TRIP AND MAIN TURBINE/FEEDWATER PUMP TRIP CALIBRATION;” was inprogress. While restoring from testing transmitter; 1B21-N705A; “RCIC Div 1 Level 8 trip logic;”the NSO noticed annunciator “RCIC RX VESSEL WTR LVL HI” was still lit.If the “RX WATER LVL HI C TRIP – LEVEL 8 TRIP” status light is actuated under theseconditions; the other expected actions; if any; that will occur are . . .

a. no additional actions.

b. both divisions of RCIC logic trip (only).

c. Main Turbine trip and feedwater pumps trip (only).

d. both divisions of RCIC logic trip; Main Turbine trip; and Feedwater pumps trip.

#7. The reactor is in Mode 3 with ” A” loop of RHR in SDC mode; in preparation for a refuelingoutage. Reactor pressure is 100 psig. 1. 1E12-F023; RHR Head Spray Valve indicating light on the PCIS panel is extinguished 2. A and B RHR Service Water Pumps indicate tripped 3. 1E12-F053A; SDC Return Valve closed 4. Loss of Leakage Detection PowerFrom the above list; indication of a loss of SDC possibly requiring entry into an abnormaloperating procedure would be . . .

a. 1; 3; and 4 only.

b. 2; 3; and 4 only.

c. 1 only.

d. 4 only.

#8. A ___(1)_ radiation trip in one channel of the Off-gas Post-treatment Monitoring Systemcombined with any other trip in the other channel will _(2)___.

a. (1) HIGH-HIGH; (2) CLOSE the OG system outlet valve to the stack (1N62-F057) which closes the combined drain valves and the holdup line drain valves.

b. (1) HIGH-HIGH-HIGH; (2) CLOSE the OG system outlet valve to the stack (1N62-F057) which closes the combined drain valves and the holdup line drain valves.

c. (1) HIGH-HIGH; (2) OPEN the Off Gas Charcoal Adsorber Train Inlet Stop 1(2)N62-F042.

d. (1) HIGH-HIGH-HIGH; (2) OPEN the Off Gas Charcoal Adsorber Train Inlet Stop 1(2)N62-F042.

#9. Identify how much water could be expected to be provided from the CRD system to the reactorpressure vessel under the following circumstances:No control rod motion; CRD lineup in a normal configuration: ___(1)_gpm. The reactordepressurized and CRD flow maximized: _(2)___gpm

a. (1) 120; (2) 170

b. (1) 120; (2) 300

c. (1) 60; (2) 170

d. (1) 60; (2) 300

#10. Control room operators received annunciator DIV 2 RB VENT RAD HI-HI and confirmed thatboth ” C” and ” D” radiation monitoring channels have tripped. From the list below; what automaticactions will occur? 1. U1 RB Ventilation System Inboard Isolation Dampers CLOSE. 2. U2 RB Ventilation System Inboard Isolation Dampers CLOSE. 3. BOTH trains of SBGT system START. 4. U1 RB Ventilation System Outboard Isolation Dampers CLOSE. 5. U2 RB Ventilation System Outboard Isolation Dampers CLOSE.

a. Only 3 occurs

b. Only 1; 2; and 3 occurs

c. Only 2; 3; and 5 occurs

d. Only 1; 2; 4; and 5 occurs

#11. The control room ventilation air filtration deluge system provides a(n) . . .

a. manual system for quenching charcoal fires.

b. emergency method for control room fire suppression.

c. automatic smoke quenching in case of control room fire.

d. automatic quenching of charcoal in case of charcoal fire.

#12. Maintenance personnel have removed the Instrument Air/Service Air after-filter and identifiedthat the filter has been severely damaged. With only this filter damaged; what specific type ofcontaminant would pass into the downstream distribution header?

a. resin beads

b. desiccant fines

c. excess moisture

d. oil and dust particles

#13. On a hot summer day with both units operating in Mode 1; control room operators observe anincrease in RBCCW system temperatures due to a decrease in service water flow.The most limiting RBCCW-cooled component is the . . .

a. recirculation pump bearings.

b. CRD pump bearings.

c. recirculation pump motor windings.

d. RWCU heat exchangers.

#14. With reactor power at 16%; the nuclear station operator was performing a single notchwithdrawal on a control rod. If an RMCS abnormal condition occurred because Activity ControlUnits disagree; the RMCS will ___(1)_ and the operator should _(2)___.

a. (1) generate a rod block and allow insert signals only (2) monitor rod position only

b. (1) generate a rod block and allow insert signals only (2) monitor rod position and briefly depress the Insert pushbutton

c. (1) lock out and cause a loss of Accumulator Trouble and Scram indications on the full core display (2) monitor rod position only

d. (1) lock out and cause a loss of Accumulator Trouble and Scram indications on the full core display (2) monitor rod position and briefly depress the Insert pushbutton

#15. Reactor power was stable at 100%. Short-term maintenance was being performed on areactor recirculation flow control subloop. A manual transfer to the redundant subloop wasperformed. The operator pushed the Motion Inhibit Trip (MIT) pushbutton at the 1H13-P602panel. A sudden failure of the operating controller caused controller output to go to zero.If the subloop in maintenance is still functioning; recirculation flow control will . . .

a. remain with the operating subloop because automatic transfer is inhibited by the MIT; and the flow control valve position will NOT change.

b. remain with the operating subloop because any maintenance on the backup subloop prevents automatic transfer; and the flow control valve will CLOSE.

c. transfer to the backup subloop because of a sensed rate of change fault; and the flow control valve position will NOT change.

d. transfer to the backup subloop because an AC 70 system component failure will be sensed; and the flow control valve will CLOSE.

#16. Unit 1 was operating at 100% power. Performance of A” RHR system full flow surveillance testwas in progress in accordance with LOS-RH-Q1. The ” A” RHR pump was running with anoperator in the process of raising flow to 7200 gpm using the control switch for 1E12-F024A; “”ARHR Pump Full Flow Test Isol Valve;”” in accordance with the procedure.Under these conditions; 1E12-F024A will go closed if . . .”

a. a High Drywell Pressure initiation signal is received regardless of control switch position for 1E12-F024A.

b. reactor vessel level reaches -150 inches AND then the control switch for 1E12-F024A is released.

c. the control switch for 1E12-F024A is released AND then the manual initiation pushbutton for “A” LPCI is armed and depressed.

d. a High Drywell Pressure initial signal is received AND then the control switch for 1E12-F024A is released AND reactor vessel level drops to -150 inches.

#17. The Low Pressure Core Spray system functions primarily to . . .

a. minimize H2 generation by keeping a water spray environment above the core.

b. limit maximum cladding temperature and cool it to saturation upon flooding the core.

c. provide the predominant source of steam cooling to the core.

d. minimize zirconium oxide production for small to intermediate break LOCAs.

#18. Unit 1 was in Mode 1 when a trip of the Unit 1 SAT occurred. With respect to HPCS; which ofthe following conditions is expected to exist?

a. Bus 143 will be de-energized and HPCS will NOT be available.

b. Bus 143 will fast transfer to the UAT and HPCS will be available.

c. The HPCS pump will be unavailable until Bus 143 can be cross-tied to Bus 243.

d. The HPCS pump will be unavailable until the Division 3 DG energizes Bus 143.

#19. With standby liquid control (SBLC) injecting; reactor power will decrease and the reactor willremain subcritical . . .

a. even if the normal cooldown rate is exceeded. HOWEVER; subcriticality is NOT assured if the reactor recirculation pumps are running because the SBLC boron concentration does NOT account for the volume of water in the reactor recirculation piping.

b. as long as the normal cooldown rate is NOT exceeded. HOWEVER; subcriticality is NOT assured if the reactor recirculation pumps are running because the SBLC boron concentration does NOT account for the volume of water in the reactor recirculation piping.

c. even if the normal cooldown rate is exceeded AND the reactor recirculation pumps are running because the SBLC boron concentration accounts for the volume of water in the reactor recirculation piping.

d. as long as the normal cooldown rate is NOT exceeded; even if the reactor recirculation pumps are running because the SBLC boron concentration accounts for the volume of water in the reactor recirculation piping.

#20. The unit is in an outage with the Reactor Mode Switch in Shutdown with the scram reset. Instrument testing has scram discharge volume (SDV) high level scram signals present. TheSDV water level bypass switch is in BYPASS. The fuel handling foreman requests the ReactorMode Switch be placed in Startup for refueling bridge interlock testing.Under these conditions; predict what would happen if the Reactor Mode Switch was taken toStartup. The reactor will ___(1)_ and you should refer to procedure _(2)___ forguidance.

a. (1) scram (2) LOP-AA-03; “Reactor Mode Changes”

b. (1) scram; (2) LFP-100-1; “Master Refueling Procedure”

c. (1) not scram; (2) LOP-AA-03; “Reactor Mode Changes”

d. (1) not scram; (2) LFP-100-1; “Master Refueling Procedure”

#21. With Unit 1 operating in Mode 3; control room operators completed LOS-LP-Q1; “LPCS SystemInservice Test.” When the LPCS Water Leg pump was restarted; the LPCS System DischargePressure Low Annunciator (H13-P601-C308) did not reset. An operator was dispatched andidentified that there was no water at the high point vent.This condition requires entry into Technical Specifications Section . . . 1) 3.3.5.1; ECCS Instrumentation 2) 3.5.1; ECCS – Operating 3) 3.5.2; ECCS – Shutdown

a. only 1)

b. only 2)

c. only 3)

d. only 1) AND 3)

#22. Given: 1. Reactor building supply and exhaust dampers will close on both units because of the interlock with Group IV. 2. The CRD Pump Cubicle Fans will trip because of low reactor building ventilation air exhaust flow. 3. A Group I MSIV isolation on Hi Steam Tunnel Differential Temperature will occur because of high temperatures following the reactor building ventilation trip. 4. Primary Containment Nitrogen Inerting and Makeup Isolation Valves will close because of the interlock with Group IV.From the above list; the functions that are expected to result from the initiation of a Group IVPrimary Containment Isolation Signal is (are) . . .

a. 3 only

b. 2 and 4 only

c. 1 and 3 only

d. 1; 2 and 4 only

#23. From the following DC load list; select those which would show abnormal operation due toPanel 112Y becoming de-energized: 1. Automatic Depressurization System Division 2 2. Standby Gas Treatment System Panel 3. Remote Shutdown System Panel 4. Low Pressure Core Spray logicThe affected loads would include . . .

a. 1; 2; and 3.

b. 1; 3; and 4.

c. 2 only.

d. 4 only.

#24. With the Unit in Mode 1; what is the MINIMUM suppression pool level that would require takingactions per Technical Specifications.

a. 1.5 inches

b. 2.5 inches

c. 3.5 inches

d. 4.5 inches

#25. The liquid radwaste effluent monitor will automatically stop a discharge to the environment if themonitor identified ___(1)_ exceeded pre-established limits measured in _(2)___.

a. (1) dose rate (2) mrem per hr

b. (1) radioactivity levels (2) cpm

c. (1) radioactivity levels (2) mrem per hr

d. (1)dose rates (2) cpm

#26. With a turbine roll in progress; the throttle pressure feedback signal for the regulator in controlof the main turbine electro- hydraulic control system failed high. The rate of turbineacceleration will . . .

a. increase as the control valves start to open.

b. remain about the same and the backup regulator NOT pick up.

c. remain about the same and the backup regulator will pick up.

d. decrease as the control valves start to close.

#27. With the unit operating at full power; the Main Generator 86 Lockout Device actuated. Theresultant feedwater temperature will . . .

a. decrease due to increased ambient heat losses.

b. increase due to increased thermal efficiencies.

c. decrease due to extraction steam isolation to feedwater heaters.

d. increase due to feedwater pumps running near dead-head conditions.

#28. The reactor was at 65% power when maintenance personnel caused the main turbine stopvalves to close inadvertently. A reactor scram resulted and reactor water level decreased; butNOT enough to cause any level-generated primary containment isolation signals to occur.Given these conditions; recirculation system flow decreased due to:

a. ATWS recirculation pump trip signal.

b. less voiding in core.

c. flow control valve runback.

d. End Of Cycle-Recirc Pump Trip signal.

#29. Unit 1 is in Mode 2 with reactor pressure at 925 psig. The RCIC system is injecting to the RPVin pressure control mode with the RCIC controller in Manual. If reactor pressure increases;RCIC turbine speed ___(1)_ and flow _(2)___.

a. (1) will not change; (2) increases

b. (1) will not change; (2) decreases

c. (1) increases; (2) increases

d. (1) decreases; (2) decreases

#30. A reactor startup was in progress with operators rejecting RWCU flow to the condenser. Control room operators then detected the following conditions: – Primary containment pressure at 10 psig and increasing – Primary containment temperature 140F and increasing – Reactor pressure vessel level drops to -60 inchesAssuming no operator intervention; ONLY RWCU valve(s) __________ CLOSE(S).

a. G33-F033; “RWCU Blowdown Header Control Valve”

b. G33-F001 AND G33-F004; “RWCU Inboard and Outboard Isolation Valves”

c. G33-F004; “RWCU Outboard Isolation Valve”

d. G33-F001; “RWCU Inboard Isolation Valve”

#31. The Unit is operating at full power. The following primary containment conditions exist: – Drywell temperature is 120F – Drywell pressure is 1.2 psig – Auxiliary Building temperature is 90F on the 786′ levelIn order to reduce drywell pressure to 0.2 psig; the shift manager directs an NSO to vent thedrywell using the VQ system IAW LOP-VQ-04; “Special Operations/Modes of the PrimaryContainment Vent and Purge System.”In order to verify that gaseous release in within the ODCM release limits; the NSO wouldmonitor the . . .

a. SBGT area radiation monitor.

b. station ventilation stack radiation monitor.

c. Auxiliary Building exhaust ventilation radiation monitor.

d. Reactor Building exhaust ventilation radiation monitor.

#32. With the unit operating at full power; HPCS inadvertently started and injected into the reactorvessel. Regarding this event; which core thermal limit would be most limiting?

a. Minimum Critical Power Ratio

b. Linear Heat Generation Rate

c. Maximum Fraction Limiting Power Distribution

d. Average Planar Linear Heat Generation Rate

#33. Unable to start either CRD pump; and with control rods drifting into the core; the UnitSupervisor directed the NSO to insert a scram. Following the scram from full power; the NSOidentified the following conditions: – neutron power decreasing on all IRMs – all rods indicate full-in on the full core display except for center control rod 30-31Center control rod 30-31 indicates full-out with the blue light extinguished and no other alarmson the on full core display. Based on these indications; the reason for control rod 30-31 notinserting is . . .

a. scram discharge instrument volume is full.

b. loss of control rod drive charging header pressure.

c. associated accumulator has a low pressure condition.

d. scram valves on the associated HCU did not reposition.

#34. The purpose of having a High Drywell Pressure reactor scram is to limit . . .

a. fuel damage AND the pressure spike in the drywell during a LOCA.

b. ONLY the pressure spike in the drywell during a LOCA.

c. the reactor pressure spike AND any core flux transient during a LOCA.

d. the amount of water volume added to the suppression pool during a LOCA.

#35. Unit 2 was operating at power when a transient caused the reactor steam dome pressure toincrease to 1150 psig. Two of the ATWS trip units for Division 2 reactor pressure failed toinitiate.Under these circumstances; the recirculation pumps will ___(1)_ and the ARI system_(2)___.

a. (1) trip; (2) will initiate automatically

b. (1) trip; (2) must be manually initiated

c. (1) remain in fast speed; (2) will initiate automatically

d. (1) remain in fast speed; (2) must be manually initiated

#36. A LOCA occurred in the drywell concurrent with a release of radioactivity which caused theReactor Building (RB) ventilation system to isolate. The following plant conditions also exist: – Reactor water level is at -60 inches; lowering – Drywell pressure is at 6.5 psig; rising – Reactor building ventilation exhaust radiation is 6 mr/hr; steady – Fuel Pool ventilation exhaust radiation is 5 mr/hr; steady – Main Steam line delta T is 25F; steady – MSIVs are closedIn accordance with LGA-002; in order to restart RB ventilation; operators must bypass… 1. Main steam line delta T. 2. High Drywell pressure. 3. Low RPV water level. 4. Reactor Building ventilation radiation. 5. Fuel Pool ventilation radiation.

a. 2 and 3 only.

b. 4 and 5 only.

c. 1; 2; and 3 only.

d. 1; 4; and 5 only.

#37. The hydrogen recombiners reduce hydrogen concentration in the primary containment toprevent . . .

a. a hydrogen burn thus ensuring drywell integrity.

b. a hydrogen-oxygen recombination which could limit acceptable containment oxygen concentrations.

c. radiolytic decomposition of water in the reactor coolant system.

d. a metal-steam reaction between the zirconium fuel rod cladding and the reactor coolant.

#38. The unit is operating at 20% power; with the ” A” train of SJAE in standby; and the ” B” train ofSJAE in operation. Personnel performing maintenance cause a loss of condensate cooling tothe ” B” train SJAE condenser and off gas condenser.With no operator action; __________ condenser vacuum.

a. efficiency of the OG system is lost resulting in reduced

b. the ” A” train of SJAE would automatically start and maintain

c. an IMMEDIATE turbine trip and reactor scram would occur due to loss of

d. the mechanical vacuum pump would automatically start after a reduction in

#39. The reason for ” load shedding” on the 4160 VAC safety buses under LOCA conditions is to . . .

a. prevent loading a faulted bus.

b. protect non-ESF equipment from damage due to increased current.

c. protect motors from damage due to prolonged operation at reduced voltage.

d. prevent an overload condition when the DG picks up the bus.

#40. The following plant conditions exist: – Reactor is at full power – Suppression Pool (SP) Cooling is in operation – Average pool temperature is increasing – RCIC testing is in progressPer Technical Specifications; there is a required action to immediately stop RCIC testing if SPtemperature exceeds the temperature limit of ___(1)_F; or immediately place thereactor mode switch in SHUTDOWN if SP temperature exceeds the temperature limit of_(2)___F.

a. (1)105; (2)110

b. (1)110; (2)120

c. (1)105; (2)120

d. (1)110; (2)110

#41. To reduce containment pressure; operators are venting primary containment using standby gastreatment system (SBGT) post- accident in accordance with LGA-VQ-01; “Containment Vent.”Reactor plant conditions are stable. Other plant conditions are as follows: – Unit 1 SBGT train is in operation – Unit 2 SBGT train is in standby – Radiation levels in primary containment are elevated – Primary containment pressure is 1.5 psig; decreasing – Primary containment temperature is 145F; decreasingIf the discharge rate through the Unit 1 SBGT radiation monitor causes annunciator1PM07J-A304; “SBGT WIDE RANGE GAS MONITOR TROUBLE” to alarm due to a highradiation release condition; the operator would be required to . . .

a. continue venting; no radiation release limits are imposed.

b. secure venting to prevent exceeding offsite release limits.

c. continue venting until General Emergency radiation limits are reached.

d. verify automatic shutdown of the Unit 1 SBGT.

#42. Unit 1 is operating at full power with the Reactor Building Closed Cooling Water (RBCCW) andthe service water system in operation as follows: – ” A” RBCCW heat exchanger and pump in operation. – ” B” RBCCW heat exchanger and pump in standby – ” 0″ RBCCW heat exchanger is available – Service Water system temperature is 80FThe RBCCW system is leaking water into containment at a rate of 5 gpm. Assuming nooperator actions; what additional condition would eventually result in a loss of RBCCW cooling?

a. RBCCW heat exchanger tube leak.

b. low reactor water level (Level 3 signal).

c. loss of instrument air to flow control valve 1WS087A/B.

d. loss of instrument air to RBCCW expansion tank makeup valve 1WR091.

#43. With both units at full power; the operating station air compressors failed; resulting in reducedService Air and Instrument Air (SA/IA) pressures. Without operator intervention and as a resultof the decreasing SA/IA header pressures; . . .

a. Turbine Building ventillation will isolate.

b. feedwater temperature will increase.

c. feedwater suction pressure will decrease.

d. the standby Station Air Compressor will AUTO start.

#44. The Unit 1 reactor is shutdown with head installed and the following conditions: – Coolant temperature is 170F – ‘B’ train residual heat removal is in shutdown cooling operation at 7000 gpm – both recirculation pumps out of service – reactor water level is being maintained at +50 inches on the Shutdown RangeIf an inadvertent PCIS Group 6 isolation occurs and the isolation signal can NOT be cleared; inorder to minimize thermal stratification of the bottom reactor vessel head AND enhance RPVmoderator temperature monitoring; the operators would . . .

a. minimize RWCU blowdown flow.

b. maximize CRD flow to the vessel.

c. maximize RBCCW flow to the RWCU heat exchanger.

d. raise reactor vessel level to at least 220 inches on the shutdown range.

#45. Unit 2 was at full power operation with the “A” CRD pump in operation. The control roomoperator received annunciator “2A CRD FEED PUMP AUTO TRIP” and the 2B CRD pumpfailed to start.With no operator actions; all accumulator pressures will ___(1)_; the control rods are_(2)___.

a. (1) IMMEDIATELY depressurize; (2) still scrammable

b. (1) IMMEDIATELY depressurize; (2) NOT scrammable

c. (1) eventually depressurize; (2) NOT scrammable

d. (1) eventually depressurize; (2) still scrammable

#46. Unit 1 was operating at 100% reactor thermal power with SRV 1B21-F013U; leaking steam pastits seat. The leakage caused the suppression pool to heatup. Under these circumstances;initiating suppression pool cooling would be necessary to prevent __________ during accidentconditions.

a. SRV tailpipe damage

b. RH; LPCS; and HPCS pumps thermal damage

c. incomplete condensing of steam discharged to the suppression pool

d. possible water hammer when starting RH; LPCS or HPCS pumps

#47. After a transient; the following parameters are noted: – Drywell pressure 12 psig rising – Drywell air temperature 240F rising – Suppression chamber pressure 7 psig rising – Suppression pool water temperature 105F risingAssuming no operator action has been taken; the event describes a . . .

a. failed open SRV.

b. breached containment following a water break LOCA.

c. normally functioning containment following a high pressure discharge into the drywell.

d. normally functioning containment following a bypass path discharge into the suppression chamber airspace.

#48. The bases for the low suppression pool level LGA entry condition is to . . .

a. prevent excessive clearing loads from SRV discharges.

b. ensure sufficient volume of water to condense steam energy.

c. minimize heating the suppression pool during a LOCA.

d. prevent excessive pool swell loads during a LOCA.

#49. Main steam tunnel temperatures and pressures are increasing due to a steam leak in thetunnel. As main steam line tunnel pressure increases; the low pressure blowout panels willactuate relieving pressure to the ___(1)_ resulting in a/an _(2)___ release to theenvironment.

a. (1) turbine building; (2) monitored

b. (1) turbine building; (2) UNMONITORED

c. (1) auxiliary building roof; (2) monitored

d. (1) auxiliary building roof; (2) UNMONITORED

#50. Unit 1 was operating at 100% power; when the ” A” TDRFP tripped. Assuming no operatoraction and all other equipment operates as designed; both recirculation flow control valves areexpected to be at ___(1)_ and the recirculation pumps _(2)___.

a. (1) minimum position; (2) remain at fast speed

b. (1) minimum position; (2) downshift to slow speed

c. (1) an intermediate position; (2) downshift to slow speed

d. (1) an intermediate position; (2) remain at fast speed

#51. The following accident conditions exist: – Drywell pressure 3.5 psig increasing – RPV pressure 525 psig decreasing – RPV level -40 inches decreasingAssuming all ECCS equipment functions as designed; LPCI would inject when __________.

a. the LPCI pumps start

b. RPV level drops to -147 inches

c. RPV pressure drops below 250 psig

d. the LPCI outboard isolation valves indicate open

#52. Before actuating SBLC from Control Room Panel 1H13-P603 during a failure to scramscenario; the reactor operator observed the following conditions: – SBLC INJ SQUIB VLV ON light for 1C41-F004A is ON – SBLC INJ SQUIB VLV ON light for 1C41-F004B is OFF – SBLC SQUIB VLV CONTINUITY LOSS alarm has annunciated.Which of the following could be the cause of all of these indications?

a. SBLC NOT injecting.

b. a loss of power from Bus 136X-2.

c. a loss of power from Bus 135X-1.

d. there is less than 0.2 ma current in the 1C41-F004A continuity circuit.

#53. The reactor was operating at full power in a half-scram trip condition due to loss of an RPS bus. A subsequent loss of power to the other RPS bus resulted in a reactor scram. Reactor waterlevel is currently at 14 inches and feedwater flow approximately 30%.Assuming systems responded as designed; the loss of RPS buses caused BOTH reactorrecirculation pumps to ___(1)_ because the _(2)___ logic was activated.

a. (1) trip; (2) ATWS Recirc Pump Trip

b. (1) trip; (2) End Of Cycle-Recirc Pump Trip

c. (1) downshift to SLOW; (2) ATWS Recirc Pump Trip

d. (1) downshift to SLOW; (2) End Of Cycle-Recirc Pump Trip

#54. Unit 2 Mode switch was in STARTUP when an IRM detector spiked; causing a momentaryupscale alarm. The design feature that allows the RO to determine which detector spiked isthe . . .

a. annunciator remains lit.

b. 2H13-P603 upscale light seals in.

c. back panel alarm seals in on the drawer.

d. core monitoring computer print out.

#55. During startup of the unit; operators can retract the source range detectors from the corewithout causing a rod block when . . .

a. the Retract Permit light de-energizes.

b. neutron level on ALL IRMs is on Range 2.

c. SRM channel count rate is greater than 400 cps.

d. neutron level on ANY IRM is on Range 3 or greater.

#56. With the unit at full power operation; an operator selected the COUNT function on APRM Bcabinet and the APRM meter read 70%. If the operator bypasses an operable LPRM input tothe ” B” APRM; the __________ annunciator(s) will alarm. 1. Channel A1 Reactor Auto Scram 2. Channel B1 Reactor Auto Scram 3. Rod Out Block

a. 1 only

b. 2 only

c. 1 and 3 only

d. 2 and 3 only

#57. Unit 1 was at full power operation with RCIC operating for a quarterly surveillance test. TheUnit 1 control room NSO received a report from equipment operators that the RCIC room wasfilled with steam. The NSO observed RCIC area temperatures and noted the following: – RCIC Equipment Area ambient temperature was 195F and increasing – RCIC Area Vent Differential temperature was 103F and increasing – Annunciator 1H13-P601-D411; “Div I RCIC Equip Area Diff/Area Temp Hi;” was alarming – Division II; RCIC Primary Containment Isolation System had NOT actuatedAssuming no operator actions were initiated; the RCIC Turbine Steam Supply ___(1)_automatically close(s) AND operator actions need be taken to _(2)___.

a. (1) inboard isolation valves; (2) shutdown RCIC in accordance with LOP-RI-03; “Reactor Core Isolation Cooling System Isolation and System Shutdown”

b. (1) outboard isolation valve; (2) shutdown RCIC in accordance with LOP-RI-03; “Reactor Core Isolation Cooling System Isolation and System Shutdown”

c. (1) inboard isolation valves; (2) recover RCIC in accordance with LOP-RI-04; “Turbine Trip Recovery and Turbine Reset of RCIC”

d. (1) outboard isolation valve; (2) recover RCIC in accordance with LOP-RI-04; “Turbine Trip Recovery and Turbine Reset of RCIC”

#58. Unit 1 was operating at 100% power with Division 3 DG unavailable due to engine bearingreplacement. A loss of offsite power resulted in a reactor scram.The Unit 1 assist NSO observed the following: – Drywell pressure is 2.0 psig and steady – All RHR pumps are operating on minimum flow – LPCS can NOT be started – Division 1 RPV wide range level indicates -145 inches and is trending down at a rate of -10 inches per minute – Division 2 RPV wide range level indicates -87 inches and is trending down at a rate of -10 inches per minuteBased on the given conditions; ADS valves will open on actuation of . . .

a. Division 1 ADS at approximately 118 seconds.

b. Division 1 ADS at approximately 716 seconds.

c. Division 2 ADS at approximately 958 seconds.

d. Division 2 ADS at approximately 1076 seconds.

#59. The Hydrogen Recombiner System gas inlet valve may be positioned IAW station proceduresfrom . . . 1. Main Control Room 2. Auxiliary Electric Equipment Room 3. Hydrogen Recombiner Skid

a. 1 only

b. 1 OR 2 only

c. 2 OR 3 only

d. 3 only

#60. The ADS accumulators are at a higher pressure than the SRV accumulators because . . .

a. the ADS system requires 2 solenoids to open the valve.

b. the ADS valves must be able to open with an elevated drywell pressure.

c. elevated pressure ensures better seating of the SRV accumulator check valve.

d. ADS accumulator components require higher actuation pressure.

#61. Unit 1 was shutting down and dumping steam to the condenser via the turbine bypass valves.Unit 1 conditions are as follows: – All control rods are inserted – Plant pressure is 800 psig decreasing slowly – Both TDRFPs are secured – MDRFP maintaining reactor water level in normal band – 1A CD/CB in operation – Reactor water level control in automatic – Condensate and feedwater system lineups normal for given conditionsIf an electrical fault de-energizes Bus 152; reactor vessel water level will start to decreasebecause . . .

a. both the MDRFP and 1A CD/CB pump de-energize.

b. the feedwater regulating valves close on the loss of power.

c. the 1A CD/CB de-energizes and causes the MDRFP to trip on low suction pressure.

d. the MDRFP de-energizes and the 1A CD/CB pump discharge pressure is too low to feed the RPV.

#62. Unit 1 was operating at 100% power when the speed demand from the RWLCS failed.Assuming no operator action; the Unit 1 TDRFP speed could be controlled from the . . .

a. RWLC Engineering Workstation.

b. GE/Woodward 5009 Cabinet touch screen.

c. TDRFP front standard at the hydraulic assembly.

d. Manual Backup Station in the main control room.

#63. Unit 1 was in cold shutdown and Unit 2 operating at full power. The 1B DG was out of servicefor overhaul. A subsequent faulted condition on the ring bus caused a loss of all offsite powerand a Unit 2 turbine generator trip. The 1A DG failed to start on demand and a SBGT systeminitiation signal was received.Assuming no operator action; the status of the SBGT approximately 5 minutes after the ring busfault is . . .

a. Unit 1 SBGT running; Unit 2 SBGT NOT running

b. Unit 1 SBGT running; Unit 2 SBGT running

c. Unit 1 SBGT NOT running; Unit 2 SBGT NOT running

d. Unit 1 SBGT NOT running; Unit 2 SBGT running

#64. According to LOS-DG-M2; “Diesel Generator Operability Test;” the EDG speed droop switchmust be positioned to “50” prior to paralleling with AC power sources. The speed droop switchis placed in this position to . . .

a. allow the EDG to share the load.

b. prevent exceeding limits on fuel rack position.

c. ensure that the EDG picks up all loads on the bus.

d. ensure the EDG will carry the design load assumed in the safety analysis.

#65. If a failure of the Display Memory Module occurs in the RMCS; the NSO could determine controlrod position indication from observing the . . .

a. Four Rod display

b. Rod Worth Minimizer

c. Rod Select display

d. Rod Block Monitor

#66. Unit 2 is shutdown for a refuel outage. The reactor head is removed and core reload is inprogress (Mode 5). The following additional plant conditions exist: – A” RHR is in shutdown cooling mode at 6000 gpm – ” B” RHR is in standbyThe NSO inadvertently positions 2E12-F006B to open. The refuel floor supervisor observeslevel dropping in the refueling cavity. The NSO observes Suppression Pool level is increasingand identifies that both the 2E12-F004B; “”RHR Pump Suction Valve;”” and 2E12-F006B; “”RHRShutdown Cooling Suction Valve;”” are open.Actions prescribed by Abnormal Procedures must be taken to mitigate…”

a. high radiation levels on the refuel floor by closing the 2E12-F004B valve.

b. exceeding heat capacity temperature limit by closing the 2E12-F006B valve.

c. inadequate NPSH for RHR pump operation by closing either the 2E12-F004B or the 2E12-F006B valve.

d. excessive temperature stratification within the reactor vessel by closing either the 2E12-F004B or the 2E12-F006B valve.

#67. While operating at power; Unit 1 experienced an under voltage condition on all 1E busses and aplant transient that resulted in drywell pressure increasing to 5.5 psig. DG 1A sequentiallypicked up loads; however; the NSO identified that the 1B RHR pump failed to auto start. Theshift manager directed the NSO to start the 1B RHR pump in accordance with LGA-RH-103;”Unit 1 A/B RHR Operations in the LGAs/LSAMGs.”If the load on DG 1A is 1800 KW; starting the 1B RHR pump; will __________.

a. have minimal affect on the bus and the DG will continue to operate.

b. cause DG 1A engine to shutdown on underfrequency.

c. cause DG 1A output breaker to trip on overcurrent after a 0.5 sec time delay.

d. cause DG 1A engine to shutdown on overcurrent after a 10 second time delay.

#68. Control room NSOs were making preparations to start the ” B” RHR pump in the suppressionpool spray mode for a special test. Equipment operators noted that the discharge pressuredownstream of the ” B” RHR pump discharge check valve was only 15 psig. The condition iscaused by . . .

a. RHR water leg pump failure.

b. LPCS water leg pump failure.

c. CLOSED ” B” RHR pump suction valve.

d. LIFTED ” B” RHR pump suction relief valve.

#69. Unit 1 was starting up from a refuel outage with the following plant conditions: – Mode Switch in RUN – Reactor power 12% – all MSIVs OPENIf RPS Bus ” A” lost power; the IMMEDIATE MSIV response would be . . .

a. ALL MSIVs would go closed.

b. ALL MSIVs would stay open.

c. ONLY inboard MSIVs would go closed.

d. ONLY outboard MSIVs would go closed.

#70. With Unit 2 at full power; the NSO noticed that 2ES001B; “Hi Press Htr 26A/B Extrn Stm InletValve;” went closed. This condition results in . . .

a. a reactor power increase.

b. a reactor power decrease.

c. a change in pH of feedwater chemistry.

d. the inability to remove moisture from the main turbine.

#71. An internal fault on the Unit 1 SAT caused the electrical loads to fast transfer to the UnitAuxiliary Transformer. The Unit 1 SAT was isolated by opening switchyard OCBs . . .

a. 2-3 AND 3-4

b. 1-6 AND 4-6

c. 9-10 AND 10-11

d. 1-13 AND 11-13

#72. During a loss of off-site power; the Plant Computer system status is . . .

a. the Hathaway SOER and the Process Computer are all powered from AC and DC power sources available; therefore; all computer systems will remain functional.

b. the Hathaway SOER and the Process Computer are all powered from the Process Computer UPS; therefore; all computer systems will be functional.

c. the Hathaway SOER will be inoperable due to a loss of AC power; however; they will reboot when the DG re-energizes the appropriate bus.

d. the Process Computer is not safety-related; load-sheds on a loss of the Class 1E switchgear; and must be manually re- booted.

#73. During a discharge from the Rad Waste Discharge Storage Tank to the blowdown line;annunciator “RW DISCHARGE HIGH RAD/INOP OR LOW SAMPLE FLOW;” alarmed in therad waste control room. The expected automatic actions of the system include . . .

a. the operating RW discharge pump trips (ONLY).

b. the RW discharge pump discharge valve closes (ONLY).

c. the operating RW discharge pump trips AND the RW discharge valve closes.

d. the RW discharge pump discharge valve closes AND the RW discharge pump recirculation valve back to the Rad Waste Discharge Storage Tank opens.

#74. Feedwater header flows were balanced with the reactor at 100% power; when aninstrumentation problem caused the FW header flows to read about 0.5 Mlbm/hr less thanactual. This error will cause the reactor water level to __(1); and will result in_(2)___ if the error reaches 1.0 Mlbm/hr.

a. (1) increase; (2) transfer of feedwater input from feedwater header flows to the sum of the individual feed pump discharge flows.

b. (1) increase; (2) automatic transfer to single element control.

c. (1) decrease; (2) transfer of feedwater input from feedwater header flows to the sum of the individual feed pump discharge flows.

d. (1) increase; (2) automatic transfer to single element control.

#75. Service water cooling to Unit 1 Fuel Pool Cooling heat exchangers was lost and could not berestored. An acceptable method for restoring fuel pool cooling is to connect . . .

a. LPCS to the Fuel Pool Cooling system.

b. RH Loop A to the Fuel Pool Cooling system.

c. RH Loop B to the Fuel Pool Cooling system.

d. RBCCW to the Fuel Pool Cooling heat exchangers.

#76. Diesel Generators ___(1)_ be used for peaking power requirements and _(2)___be started in anticipation of loss of offsite power.

a. (1) shall; (2) should

b. (1) shall; (2) should NOT

c. (1) shall NOT; (2) should

d. (1) shall NOT; (2) should NOT

#77. Exclusive of plant transients; plant announcements are NOT REQUIRED prior to . . .

a. commencement of reactor startup.

b. stopping major plant components.

c. starting of major plant components.

d. placing Primary and Secondary containment integrity into effect during plant startup.

#78. The Reactor Mode Switch is located on the ___(1)_ of panel H13-P603. When theReactor Mode Switch is required to be LOCKED; the key shall be located _(2)___.

a. (1) apron section; (2) in the lock

b. (1) vertical section; (2) in the lock

c. (1) apron section; (2) at the switch; but NOT in the lock

d. (1) vertical section; (2) at the switch; but NOT in the lock

#79. The suppression chamber is to be re-inerted after a short duration outage. Control room NSOswill monitor AI CM063; “Suppression Chamber/DW Oxygen Monitor;” on control room panel___(1)_ during the evolution. The suppression chamber would be considered inertedwhen the MAXIMUM oxygen concentration is less than _(2)___ by volume and indicatedoxygen concentration is no longer decreasing.

a. (1) PM13J; (2) 1%

b. (1) PM13J; (2) 5%

c. (1) PM16J; (2) 1%

d. (1) PM16J; (2) 5%

#80. During approach to criticality; the NSO will DISCONTINUE Notch Out Override betweenpositions 00 and 24 when . . .

a. the generator is on line.

b. at least one bypass valve is open.

c. Group 1 has been pulled to position 48.

d. highest initial SRM count rate has increased by a factor of 4.

#81. Unit 1 is at full power operations. In order for maintenance to work on the main turbine trippressure switches in the turbine EHC system at plant normal operating temperature andpressure; and without the out of service (OOS) being an Exceptional OOS; the Operationsdepartment needs ___(1)_ valve isolation since _(2)___.

a. (1) single; (2) pressure is greater than 500 psig

b. (1) double; (2) pressure is greater than 500 psig

c. (1) single; (2) temperature is greater than 200F

d. (1) double; (2) temperature is greater than 200F

#82. At 9:00 a.m. Instrument Maintenance technicians inform the NSO that the RCIC Vessel WaterLevel-Hi; Level 8″ surveillance is commencing and the channel is to be declared inoperable. The maintenance is expected to be completed in 2 hours.The required method to track the associated LCO and to ensure the RCIC TechnicalSpecification is met; is by use of . . .

a. Condition Report

b. Plan of the Day

c. Degraded Equipment Log

d. Short Duration Time Clock

#83. A condition occurs where the standby main generator stator cooling pump auto starts and statorcooling pressure remains at 40 psig.If this condition continues to exist; and stator amps remain greater than ___(1)_ for 2.0minutes; the Main Turbine will automatically _(2)___.

a. (1) 7;057 amps; (2) trip

b. (1) 7;057 amps; (2) runback

c. (1) 21;831 amps; (2) runback

d. (1) 21;831 amps; (2) trip

#84. Which of the following activities requires you to notify RP of changing radiation levels.

a. Starting ” A” RHR pump

b. Starting SBLC pump

c. Swapping RWCU pumps.

d. Starting additional condensate/condensate booster pump

#85. A male visitor with no previous exposure gets lost in the reactor building at LaSalle and heinadvertently walks into a high radiation area. Assuming no previous exposure; RP personnelread the visitor” s dosimeter and calculated that the visitor received the following radiationexposure: – Chest 4500 mrem – Hands 1060 mrem – Eye Lens 510 mrem – Internal 550 mremWhich; if any; Federal Exposure limit has the visitor exceeded?

a. LDE limit.

b. SDE limit.

c. TEDE limit.

d. No exposure limits exceeded.

#86. During fuel moves; access to the 796″ level in the drywell is . . .

a. ALWAYS prohibited.

b. allowed with permission from EITHER an RP technician or the Shift Manager.

c. controlled ONLY by the specific RWP which governs the work to be performed.

d. controlled by an RP technician in continual attendance OR by remote monitoring with continuous communication.

#87. The following conditions exist in primary containment: – Primary Containment Pressure 1.3 psig – Drywell Temperature 130F – Suppression Pool Temperature 106F – Drywell Hydrogen at 1.8%The condition requiring entry into LGA-003; “Primary Containment Control;” is . . .

a. Primary Containment Pressure.

b. Drywell Temperature.

c. Suppression Pool Temperature.

d. Drywell Hydrogen.

#88. Regulatory Guide 1.97 post-accident instruments in the control room are identified with . . .

a. blue tags.

b. white tags.

c. orange circles.

d. black dots.

#89. If ” C” APRM is bypassed; RBM Channel ” A” . . .

a. is automatically bypassed.

b. automatically receives a reference signal from another APRM.

c. generates a Downscale Failure alarm AND Rod Withdrawal Block.

d. will light an RBM Bypass light indicating another APRM may be selected.

#90. The HPCS line integrity monitor senses the differential pressure between the HPCS spraysparger and the . . .

a. differential pressure tap to confirm HPCS piping integrity between the injection check valve and the RPV.

b. SBLC above core plate pressure tap to confirm HPCS piping integrity from inside the RPV to the core shroud.

c. drywell to confirm HPCS piping integrity between the drywell wall and the RPV.

d. HPCS suction to confirm HPCS piping integrity from suction to discharge.

#91. Unit 1 was initially operating at 26% power. A main turbine trip signal was received and theNSO observed reactor pressure spike to 1100 psig.The NSO observes: – Reactor pressure controlled by BPVs; 1060 psig and steady – Reactor power 20% and steadyThe first recovery initiative that is to be implemented is . . .

a. Initiate ARI IAW LGP-3-2; “Reactor Scram.”

b. Insert manual Scram IAW LGP-3-2; “Reactor Scram.”

c. Reduce reactor power with recirculation IAW LGP-2-1; “Normal Unit Shutdown.”

d. Reduce reactor power by inserting control rods IAW LGP- 2-1; “Normal Unit Shutdown.”

#92. Unit 1 is in Mode 4 completing a 25 day refuel outage. Both recirculation pumps are operatingin slow speed. Other plant conditions are as follows: – ” B” RHR pump is in shutdown cooling mode – ” A” RHR pump is unavailable due to maintenance – Coolant temperature at 175F – Both trains of RHR service water are available – Circulating Water and feedwater and condensate systems are available – ‘A’ train of Fuel Pool Cooling in service.A fault de-energizes Bus 142Y and the bus CANNOT be re-energized. Which of the following methods of alternate heat removal are NOT available?

a. LPCS in core cooling mode.

b. RWCU removing decay heat.

c. ‘C’ RHR pump in shutdown cooling mode.

d. Main Condenser and condensate/booster pump.

#93. Given the following plant conditions: – Reactor recirculation loop B pump tripped – Power and flow in the allowable region of Technical SpecificationsThermal Limits: 1. Average Planar Linear Heat Generation Rate 2. Minimum Critical Power Ratio 3. Linear Heat Generation Rate 4. Maximum Allowable Power RatioWhich of the above thermal limits must be adjusted?

a. 1; 2; and 4.

b. 1; 2; and 3.

c. 1 and 2 only

d. 3 and 4 only

#94. Reactor power is 100 %. Unit 2 drywell temperature is currently reading 105F and has beenincreasing consistently at a rate of 25F/hr. Assuming the rate of temperature change remainsthe same; LGA-003 “Primary Containment Control” must be entered in __________ minutes.

a. 36

b. 72

c. 84

d. 108

#95. Placing a component s transfer switch to the “”EMERGENCY”” position on the Remote ShutdownPanel will allow control of the component from the Remote Shutdown Panel ___(1)_ toenable bringing the reactor to cold shutdown and the component will _(2)___ automaticprimary containment isolation features.”

a. (1) ONLY; (2) lose

b. (1) ONLY; (2) maintain

c. (1) AND the control room; (2) lose

d. (1) AND the control room; (2) maintain

#96. Unit 1 and Unit 2 reactor building (RB) ventilation systems were operating when instrument airwas lost. The RB ventilation exhaust and supply dampers fail ___(1)_ and RBmodulating dampers fail _(2)___.

a. (1) closed; (2) open

b. (1) closed; (2) closed

c. (1) open; (2) open

d. (1) open; (2) closed

#97. Both Units are operating at 100% power. An operator reported smoke in the vicinity of the 2ADG room and a RED CO2 alarm is on Panel FP04JB/JC.The CO2 system ___(1)_ actuated. If required; manual actuation requires use of leversfor the master valve located _(2)___.

a. (1) should have; (2) by the CO2 storage tank and for the header stop located in the DG corridor.

b. (1) should NOT have; (2) by the CO2 storage tank and for the header stop located in the DG corridor.

c. (1) should have; (2) in the DG corridor and slave valve located just inside the door to the DG.

d. (1) should NOT have; (2) in the DG corridor and slave valve located just inside the door to the DG.

#98. The Unit 1 NSO receives annunciator 1H13-P601-C205; “1A RHR PMP Cubicle Temp Hi” anda report of smoke in the area. What is the expected status of the diesel fire pumps?”0A” Diesel Fire Pump is ___(1)_; “0B” Diesel Fire Pump is _(2)___;

a. (1) Running; (2) In Standby

b. (1) Running; (2) Running

c. (1) In Standby; (2) Running

d. (1) In Standby; (2) In Standby

#99. If water intrusion created grounds that disabled all Division 1 and Division 2 125VDC power . . .

a. RCIC will trip if running because of an overspeed trip.

b. RCIC will remain running because 125 VDC power loss does NOT affect RCIC overspeed.

c. RCIC will trip if running because of power loss to the Steam Supply Stop Valve; 1(2)E51-F045.

d. RCIC will remain running because 125 VDC power loss does NOT affect the Steam Supply Stop Valve; 1(2)E51-F045.

#100. Given the following conditions: – Unit 2 in Operating Condition 1 – 2VG023; “SBGT VQ XTIE Valve;” is OPEN – Primary Containment Vent and Purge (VQ) isolation valves are OPENThe Unit 2 SBGT (VG) train is inoperable because the lineup may cause damage to the . . .

a. VQ system during some non-accident vent conditions.

b. VG system during some non-accident vent conditions.

c. VQ system under LOCA conditions with high drywell pressure.

d. VG system under LOCA conditions with high drywell pressure.

#101. The protective interlocks intended to prevent refueling accidents or incidents involving theoverhead crane include . . . 1. restricting hoist movement to a Critical L-Path. 2. preventing movement of the crane if operating the spent fuel cask greater than 6″ off the Refuel Floor. 3. stopping further upward movement of the Overhead Crane if a high radiation condition is sensed by an Area Radiation Monitor. 4. preventing crane or hoist movement if a DIV 1 or DIV 2 FUEL POOL RAD HI-HI condition is sensed.

a. 1; 2; and 3 only

b. 1; 3; and 4 only

c. 2; and 4 only

d. 1; and 3 only

#102. A plant event resulted in an off-site release. Possible entry conditions into the RadioactiveRelease Control Procedure are described below. The MINIMUM conditions that require theUnit Supervisor to enter the LGA-009 “Radioactive Release Control” procedure are . . .

a. 6.2×105 microcuries/sec offsite release rate AND Valid A-Model Alert classification

b. 6.2×105 microcuries/sec offsite release rate OR Valid A-Model Unusual Event classification

c. 6.2×106 microcuries/sec offsite release rate AND Valid A-Model Unusual Event classification

d. 6.2×106 microcuries/sec offsite release rate OR Valid A-Model Alert classification

#103. LGA-009 has been entered due to high offsite release. What affect; if any; does this have onpermissible radiation exposure limits?

a. There is no affect on allowable exposure limits.

b. Automatically authorized to increase allowable exposure limit by a factor of 2.

c. Automatically authorized to increase allowable exposure limit to federal limits.

d. Automatically authorized to increase allowable exposure limit to emergency limits.

#104. The following conditions exist: – Station blackout has occurred – Div 1 and Div 2 EDGs failed to start – SRVs were initially used for reactor pressure controlWhich of the means below would be available to carry out pressure control three hours afterthe SBO occurred?

a. ADS valves using Div 1 keylock switches in AEER IAW LGA-001 “RPV Control.”

b. ADS valves using Div 1 keylock switches in AEER IAW LGA-004 “RPV Blowdown.”

c. Low Low Set (LLS) valves using Div 1 keylock switches in AEER IAW LGA-001; “RPV Control.”

d. Low Low Set (LLS) valves using Div 1 keylock switches in AEER IAW LGA-004; “RPV Blowdown.”

#105. Which of the following meets the criteria of a fuel handling accident?

a. Dropped fuel bundle in the cattle chute.

b. Dropped double blade guide in the cattle chute.

c. Fuel misplaced in the reactor vessel.

d. Fuel misplaced in the spent fuel pool.

#106. The plant was operating at full power. A loss of feedwater followed by a reactor scramoccurred. Plant conditions are as follows: – Reactor pressure is 900 psig; and MSIVs have failed open. – HPCS and RCIC are inoperable – Condensate/Feedwater cannot be restored – Both CRD pumps are running – RPV level is -75 inches on WR; decreasing at a rate of about 15 inches/min. – Drywell Pressure is 1.6 psig.The Shift Supervisor has executed LGP 3-2. The appropriate action per LGA-001 is to . . .

a. maintain RPV pressure less than 1059 psig using BPVs and SRVs; increase CRD injection rate to restore RPV level 11 to 59.5 inches.

b. maintain RPV pressure less than 1059 psig using BPVs ONLY; and inject with SBLC from the test tank to maintain RPV level above -150 inches.

c. reduce RPV pressure rapidly (greater than 100 deg F/hr) and maintain less than 440 psig with BPVs ONLY; and inject with LPCS to restore RPV level 11 to 59.5 inches.

d. reduce and maintain RPV pressure between 50 and 150 psig with the BPVs and SRVs; and inject with Clean Condensate to maintain RPV level above -150 inches WR.

#107. A condition related to unknown reactor vessel water level where Adequate Core Cooling existsis described by . . .

a. LGA-001 directed LGA-005 entry; 6 SRVs open; RPV pressure is 25 psig.

b. LGA-001 directed LGA-005 entry; 5 SRVs open; RHR Head Spray established.

c. LGA-010 directed LGA-005 entry; 6 SRVs are open; RPV pressure is 340 psig.

d. LGA-010 directed LGA-005 entry; 7 SRVs are open; RPV pressure is 200 psig.

#108. The LGA-010 Failure to Scram procedure level leg directs operators to lower reactor water levelrapidly to at least -60 inches if reactor power is above 3% or unknown. This lower water leveldecreases power . . .

a. and ensures feedwater sparger nozzles are uncovered to help minimize power oscillations.

b. while allowing margin for feedwater sparger nozzles to remain covered to prevent thermal shock.

c. and ensures core spray inlet lines are uncovered to minimize inlet subcooling if injection is needed.

d. sufficiently while allowing margin for core spray inlet lines to remain covered to prevent thermal shock if injection is needed.

#109. Unit 1 was in Mode 1 at 100% reactor power. During a daily surveillance at 9:00 am on April 1;SP water levels were reported to be +3.5 inches on one instrument; and +3.2 inches on anotherinstrument. Instrument technicians were called in to perform a calibration check on bothinstruments; and preliminarily indicated that there were no problems with the instrumentoperation.At 9:30 am; the Unit Supervisor directed actions to lower SP water level concurrent with theinstrument technicians performing their calibration check.The Unit Supervisor identified that on March 31; at 9:00 pm; the SP level was last verified by TSsurveillance SR 3.6.2.2.1 at +2 inches.The applicable required actions and associated completion times are: restore SP level by 11:00am on April 1; or be in Mode 3 by ___(1)_ on April 1; or be in Mode 4 by_(2)___.

a. (1) 11:00 pm; (2) 11:00 pm on April 2

b. (1) 11:00 pm; (2) 11:00 am on April 3

c. (1) 9:00 pm; (2) 9:00 pm on April 2

d. (1) 9:00 pm; (2) 9:00 am on April 3

#110. A small primary system leak that CANNOT be isolated developed on Unit 1 in the vicinity of theReactor Sample Station. Reactor Building Ventilation (VR) exhaust radiation levels were 40mrem/hr and constant prior to VR isolating. Radiation levels in the vicinity of the ReactorSample Station are 1100 mrem/hr and rising slowly.The corrective actions to be taken and bases for those actions include:

a. starting VR per LGA-VR-01 because VR will do a better job of maintaining area temperatures and differential pressure than VG.

b. shutting down the reactor per LGP-2-1 to reduce decay heat levels and energy discharged to containment without introducing an unnecessary transient on plant systems.

c. scramming the reactor and entering LGA-001 to reduce energy that the RPV may be discharging to the Secondary Containment because adequate core cooling; containment integrity; and/or the continued operability of equipment necessary to perform a safe shutdown may not be assured.

d. scramming the reactor and entering LGA-001; followed by LGA-004; “RPV Blowdown;” to preclude further temperature increases by rejecting the heat to the SP instead of outside the Primary Containment because the problem is widespread.

#111. (QUESTION DELETED) Unit 1 was operating at 100% power with no equipment abnormalities noted. A surveillance testidentified one low pressure injection line permissive pressure switch; 1E21-N413; for LPCS;with a setpoint of 480 psig. The applicable TS required action(s) is (are) . . .

a. TS 3.5.1; RA A.1 only

b. TS 3.3.5.1; RA D.1 AND D.3 only

c. TS 3.3.5.1; RA D.1; D.2; AND TS 3.5.1; RA A.1

d. TS 3.3.5.1; RA D.1 AND RA D.2

#112. The Technical Specification bases for the Main Steam Line Pressure-Low Primary ContainmentIsolation is . . .

a. protection from RPV cooldown greater than 100F/hour.

b. ensuring that offsite dose limits of 10CFR 100 are not exceeded.

c. providing diversity to the high steam line flow isolation.

d. providing detection and prevention of a leak in any Main Steam Line.

#113. Unit 1 is operating at 100% power. The SAT was providing power to bus 141Y. Bus 141YVoltage decreased to 3800 Volts for ONE MINUTE. ACB 1412 ___(1)_ AND operatorsshould respond IAW LOA-AP-101; “Unit 1; AC Power System Abnormal;” _(2)___section.

a. (1) will trip (2) Degraded voltage

b. (1) will trip (2) Loss of Bus 141Y

c. (1) will remain closed (2) Degraded voltage

d. (1) will remain closed (2) Loss of Bus 141Y

#114. Operators trying to exit the reactor building reported that only one door at the DG corridorairlock can be opened and annunciator “RB 3 DOOR AIRLOCK F21 UNDERVOLTAGE”alarmed. The Unit Supervisor dispatched operators to the reactor building to complete requiredactions.In accordance with LOA-AP-101 Attachment L; since power is lost to ___(1)_; the UnitSupervisor should direct the operators to _(2)___.

a. (1) both doors at the DG corridor airlock; (2) close the door to reset the interlock; then open the next door

b. (1) both doors at the DG corridor airlock; (2) bypass the interlock with jumpers located in the DG corridor to simultaneously open both doors

c. (1) an interlock relay; (2) open breakers to de-energize the interlock relays to simultaneously open both doors

d. (1) an interlock relay; (2) reset the undervoltage relay logic for the airlock doors in the control room to open both doors

#115. On July 5; both Units were at 100% power. During a review of surveillance packagescompleted on July 4 for performances of SR 3.8.6.2 for all batteries; the following conditionswere noted: – one 250V battery cell has an electrolyte level below the top of the plates – one Div 1 125V battery cell had a corrected specific gravity reading of 1.186 when average reading of cells was 1.206 – Div 2 125V battery was on a float charge of one ampere following discharge on June 30 with no specific gravity readings taken – Div 3 125V battery was discharged to 108V on June 22 and temperature readings revealed that some cells were 60F – no other abnormal conditions were noted. – the last surveillance on these batteries was successfully completed on April 5.The surveillance procedure requires review of results to determine if equipment is operable inaccordance with Technical Specifications. The OPERABLE battery(s) and required action(s) ineffect is (are) the . . .

a. 250V battery with RA A.1 AND A.2 in effect.

b. Div 1 125V battery with RA A.1; A.2 AND A.3 in effect.

c. Div 2 125V battery with RA A.1; A.2 AND A.3 in effect.

d. Div 3 125V battery was operable for June; inoperable on July 3; but currently operable.

#116. During a surveillance test involving calibration of the four wide range reactor vessel levelindication instrument loops; an Instrument Technician inadvertently left the instrument rootvalves to the reference legs for the instruments closed. The reference side of the instrumentwas pressurized to 1000 psig.If a rapid depressurization event with lowering reactor vessel level below Level 2 occurred; andthe Unit Supervisor entered LGA-001; “RPV Control;” indicated wide range level would be___(1)_; and _(2)___would be the most reliable.

a. (1) higher than actual; (2) fuel zone level instruments

b. (1) higher than actual; (2) a shutdown range indication

c. (1) below actual level; (2) fuel zone level instrument

d. (1) below actual level; (2) shutdown range indication

#117. Unit 1 was initially at full power with no TIP surveillances in progress. The ARM for the “RB TipDrive Units Area” alarmed with a constant reading of 10 R/hr. Subsequently; a plant operatorreported the RB HCU South ARM was in alarm and reading 30 mr/hr. Other plant operatorsreport no observable leakage in the HCU or TIP room areas and no other indications ofabnormal leakage.The expected reactor control actions; if any; to be directed by the Unit Supervisor wouldbe ___(1)_; and the expected condition of SBGT and RB Ventilation systems wouldbe _(2)___.

a. (1) no action because max safe value criteria not exceeded; (2) SBGT stopped; RB Ventilation running

b. (1) shutdown the reactor because max safe value criteria exceeded; (2) SBGT stopped; RB Ventilation running

c. (1) scram the reactor because max safe value approached or exceeded; (2) SBGT running; RB Ventilation stopped

d. (1) scram the reactor and blowdown per LGA-004 or LGA-006 because max safe value approached or exceeded; (2) SBGT running; RB Ventilation stopped

#118. Assume an abnormal increase in Off Gas Post-Treatment Monitoring System radiation levels. 1. decrease in steam jet air ejector flow 2. closure of the Off Gas Charcoal Adsorber Train Bypass Stop Valve; 1N62-F043 3. mechanical vacuum pump start 4. closure of the OG system Outlet Valve; 1N62-F057The above actions that will result in reducing offsite radioactive release rates resulting fromradio-nuclides in the off-gas (OG) system are . . .

a. 1 only

b. 2 and 3 only

c. 3 and 4 only

d. 1; 2; and 4 only

#119. LGA-009; “Radioactive Release Control” can . . .

a. ONLY be initially entered if entry conditions are satisfied.

b. ONLY be entered as an action from LGA-003; Primary Containment Control.

c. ONLY be entered as an action from LGA-002; Secondary Containment Control.

d. be entered as an action from ANY LGA.

#120. With Unit 2 at beginning of core life; an event resulted in an automatic scram. The NSOpositioned the Mode Switch to SHUTDOWN. Plant conditions are as follows: – reactor water level dropped to -25 inches – 3 control rods remain at notch 08; all other control rods are full in – all other reactor and containment parameters are normalThe Unit Supervisor” s first directed action would be . . .

a. Initiate ADS

b. Bypass MSIVs

c. Trip Reactor Recirc Pumps

d. Terminate and prevent injection from HPCS; LPCS; & LPCI

#121. In accordance with EP-AA-113 “Protective Actions; ” ___(1)_ are to be considered foractions protecting onsite personnel; and _(2)___ are (is) to be considered for actionsprotecting offsite personnel. 1. Radiological Controls 2. Emergency Dose Limits (in excess of 10 CFR 20 limits) 3. Thyroid Blocking Agents (Potassium Iodide) 4. Evacuation 5. Site Assembly

a. (1) 1; 2; 3; 4; and 5; (2) 4 only

b. (1) 1; 2; 3; 4; and 5; (2) 3 and 4 only

c. (1) 1; 2; 4; and 5 only; (2) 4 only

d. (1) 1; 2; 4; and 5 only; (2) 3 and 4 only

#122. With Unit 1 at 50% power; a malfunction in the feedwater level control system causes reactorwater level to decrease to +5 inches. After the transient subsides; the following conditionsexist: – reactor pressure 1050 psig decreasing – reactor water level 18 inches steady – main turbine tripped – power range indicators unavailable – IRMs fully insertedThe reactor operator reports that neutron level is steady and reading 100 on Range 10 of theIRMs. Reactor power is ___(1)_and LGA 010; “Failure to Scram” requires thatRecirculation pumps _(2)___.

a. (1) 40%; (2) be tripped

b. (1) 4%; (2) be tripped

c. (1) 40%; (2) remain operating

d. (1) 4%; (2) remain operating

#123. An operator on rounds reports that his digital dosimetry is alarming on dose rate while touringthe RT pump room. The indicated dose rate is greater than that allowed by the RWP. TheSRO should direct the rounds operator to . . .

a. leave the radiologically controlled area and report to RP.

b. obtain new dosimetry at the WEC.

c. wait in the area for an RP to arrive.

d. initiate a Condition Report and continue with rounds.

#124. The Reactor Mode Switch is in the SHUTDOWN position with no reactor recirculation pumpsrunning. – ” A” train of RHR shutdown cooling (SDC) has been inoperable for the last 24 hours due to pump problems. – ” B” train of SDC was taken out of service and declared inoperable due to surveillance testing starting at 2 p.m. Average reactor coolant temperature was 180F. – average reactor coolant heatup rate since the B train was taken out of service has been constant at about +10F/hr.If the surveillance testing was still in progress at 5:30 pm; no changes had been reported for the’A’ loop; and average coolant temperature progressed according to the above information; thenaccording to the SDC portion of Technical Specifications; the required actions and completiontimes in effect are . . .

a. verify alternate decay heat removal method within 1 hour and every subsequent 24 hours.

b. verify alternate method of coolant circulation within 1 hour of discovery and every 12 hours thereafter; and monitor reactor coolant temperature and pressure once per hour.

c. initiate action to restore each inoperable SDC loop immediately; and verify two alternate decay heat removal methods are available (one for the A and one for the B loop) within 1 hour; and be in mode 4 within 24 hours.

d. initiate action to restore one SDC loop or one recirculation pump immediately; and verify alternate method of reactor coolant circulation within 1 hour of discovery of no reactor coolant circulation and every 12 hours thereafter; and monitor reactor coolant temperature and pressure once per hour.

#125. In order to move fuel; the fuel handling SRO must be . . .

a. within phone contact

b. on the refuel bridge

c. at the refuel floor managers desk

d. within 10 minutes of the refuel floor

Results

#2. The Unit 1 Standby Gas Treatment (SBGT) system is out of service. The Unit 2 SBGT systemis available. Which of the following events would be a concern if the Unit 2 SBGT system wouldbecome inoperable? The inability to . . .

#3. Fuel handlers have informed the control room that the fuel dunking chamber is broken. As aresult; __________ evolutions will be delayed by this component” s failure.

#4. The following conditions exist on Unit 2: – Drywell pressure 2.5 psig – Undervoltage condition on Bus 242YThe 2A EDG started and loaded onto the bus. After several minutes; a local operator reportedannunciator 2DG03J-1-2; “OVERSPEED” alarmed.As NSO; you verify the 2A EDG . . .

#8. A _____(1)_____ radiation trip in one channel of the Off-gas Post-treatment Monitoring Systemcombined with any other trip in the other channel will _____(2)_____.

#9. Identify how much water could be expected to be provided from the CRD system to the reactorpressure vessel under the following circumstances:No control rod motion; CRD lineup in a normal configuration: _____(1)_____gpm. The reactordepressurized and CRD flow maximized: _____(2)_____gpm

#11. The control room ventilation air filtration deluge system provides a(n) . . .

#12. Maintenance personnel have removed the Instrument Air/Service Air after-filter and identifiedthat the filter has been severely damaged. With only this filter damaged; what specific type ofcontaminant would pass into the downstream distribution header?

#13. On a hot summer day with both units operating in Mode 1; control room operators observe anincrease in RBCCW system temperatures due to a decrease in service water flow.The most limiting RBCCW-cooled component is the . . .

#14. With reactor power at 16%; the nuclear station operator was performing a single notchwithdrawal on a control rod. If an RMCS abnormal condition occurred because Activity ControlUnits disagree; the RMCS will _____(1)_____ and the operator should _____(2)_____.

#17. The Low Pressure Core Spray system functions primarily to . . .

#18. Unit 1 was in Mode 1 when a trip of the Unit 1 SAT occurred. With respect to HPCS; which ofthe following conditions is expected to exist?

#19. With standby liquid control (SBLC) injecting; reactor power will decrease and the reactor willremain subcritical . . .

#24. With the Unit in Mode 1; what is the MINIMUM suppression pool level that would require takingactions per Technical Specifications.

#25. The liquid radwaste effluent monitor will automatically stop a discharge to the environment if themonitor identified _____(1)_____ exceeded pre-established limits measured in _____(2)_____.

#26. With a turbine roll in progress; the throttle pressure feedback signal for the regulator in controlof the main turbine electro- hydraulic control system failed high. The rate of turbineacceleration will . . .

#27. With the unit operating at full power; the Main Generator 86 Lockout Device actuated. Theresultant feedwater temperature will . . .

#29. Unit 1 is in Mode 2 with reactor pressure at 925 psig. The RCIC system is injecting to the RPVin pressure control mode with the RCIC controller in Manual. If reactor pressure increases;RCIC turbine speed _____(1)_____ and flow _____(2)_____.

#32. With the unit operating at full power; HPCS inadvertently started and injected into the reactorvessel. Regarding this event; which core thermal limit would be most limiting?

#34. The purpose of having a High Drywell Pressure reactor scram is to limit . . .

#35. Unit 2 was operating at power when a transient caused the reactor steam dome pressure toincrease to 1150 psig. Two of the ATWS trip units for Division 2 reactor pressure failed toinitiate.Under these circumstances; the recirculation pumps will _____(1)_____ and the ARI system_____(2)_____.

#37. The hydrogen recombiners reduce hydrogen concentration in the primary containment toprevent . . .

#39. The reason for ” load shedding” on the 4160 VAC safety buses under LOCA conditions is to . . .

#43. With both units at full power; the operating station air compressors failed; resulting in reducedService Air and Instrument Air (SA/IA) pressures. Without operator intervention and as a resultof the decreasing SA/IA header pressures; . . .

#46. Unit 1 was operating at 100% reactor thermal power with SRV 1B21-F013U; leaking steam pastits seat. The leakage caused the suppression pool to heatup. Under these circumstances;initiating suppression pool cooling would be necessary to prevent __________ during accidentconditions.

#48. The bases for the low suppression pool level LGA entry condition is to . . .

#49. Main steam tunnel temperatures and pressures are increasing due to a steam leak in thetunnel. As main steam line tunnel pressure increases; the low pressure blowout panels willactuate relieving pressure to the _____(1)_____ resulting in a/an _____(2)_____ release to theenvironment.

#50. Unit 1 was operating at 100% power; when the ” A” TDRFP tripped. Assuming no operatoraction and all other equipment operates as designed; both recirculation flow control valves areexpected to be at _____(1)_____ and the recirculation pumps _____(2)_____.

#51. The following accident conditions exist: – Drywell pressure 3.5 psig increasing – RPV pressure 525 psig decreasing – RPV level -40 inches decreasingAssuming all ECCS equipment functions as designed; LPCI would inject when __________.

#54. Unit 2 Mode switch was in STARTUP when an IRM detector spiked; causing a momentaryupscale alarm. The design feature that allows the RO to determine which detector spiked isthe . . .

#55. During startup of the unit; operators can retract the source range detectors from the corewithout causing a rod block when . . .

#59. The Hydrogen Recombiner System gas inlet valve may be positioned IAW station proceduresfrom . . . 1. Main Control Room 2. Auxiliary Electric Equipment Room 3. Hydrogen Recombiner Skid

#60. The ADS accumulators are at a higher pressure than the SRV accumulators because . . .

#62. Unit 1 was operating at 100% power when the speed demand from the RWLCS failed.Assuming no operator action; the Unit 1 TDRFP speed could be controlled from the . . .

#64. According to LOS-DG-M2; “Diesel Generator Operability Test;” the EDG speed droop switchmust be positioned to “50” prior to paralleling with AC power sources. The speed droop switchis placed in this position to . . .

#65. If a failure of the Display Memory Module occurs in the RMCS; the NSO could determine controlrod position indication from observing the . . .

#68. Control room NSOs were making preparations to start the ” B” RHR pump in the suppressionpool spray mode for a special test. Equipment operators noted that the discharge pressuredownstream of the ” B” RHR pump discharge check valve was only 15 psig. The condition iscaused by . . .

#69. Unit 1 was starting up from a refuel outage with the following plant conditions: – Mode Switch in RUN – Reactor power 12% – all MSIVs OPENIf RPS Bus ” A” lost power; the IMMEDIATE MSIV response would be . . .

#70. With Unit 2 at full power; the NSO noticed that 2ES001B; “Hi Press Htr 26A/B Extrn Stm InletValve;” went closed. This condition results in . . .

#71. An internal fault on the Unit 1 SAT caused the electrical loads to fast transfer to the UnitAuxiliary Transformer. The Unit 1 SAT was isolated by opening switchyard OCBs . . .

#72. During a loss of off-site power; the Plant Computer system status is . . .

#73. During a discharge from the Rad Waste Discharge Storage Tank to the blowdown line;annunciator “RW DISCHARGE HIGH RAD/INOP OR LOW SAMPLE FLOW;” alarmed in therad waste control room. The expected automatic actions of the system include . . .

#75. Service water cooling to Unit 1 Fuel Pool Cooling heat exchangers was lost and could not berestored. An acceptable method for restoring fuel pool cooling is to connect . . .

#76. Diesel Generators _____(1)_____ be used for peaking power requirements and _____(2)_____be started in anticipation of loss of offsite power.

#77. Exclusive of plant transients; plant announcements are NOT REQUIRED prior to . . .

#78. The Reactor Mode Switch is located on the _____(1)_____ of panel H13-P603. When theReactor Mode Switch is required to be LOCKED; the key shall be located _____(2)_____.

#80. During approach to criticality; the NSO will DISCONTINUE Notch Out Override betweenpositions 00 and 24 when . . .

#83. A condition occurs where the standby main generator stator cooling pump auto starts and statorcooling pressure remains at 40 psig.If this condition continues to exist; and stator amps remain greater than _____(1)_____ for 2.0minutes; the Main Turbine will automatically _____(2)_____.

#84. Which of the following activities requires you to notify RP of changing radiation levels.

#86. During fuel moves; access to the 796″ level in the drywell is . . .

#87. The following conditions exist in primary containment: – Primary Containment Pressure 1.3 psig – Drywell Temperature 130F – Suppression Pool Temperature 106F – Drywell Hydrogen at 1.8%The condition requiring entry into LGA-003; “Primary Containment Control;” is . . .

#88. Regulatory Guide 1.97 post-accident instruments in the control room are identified with . . .

#89. If ” C” APRM is bypassed; RBM Channel ” A” . . .

#90. The HPCS line integrity monitor senses the differential pressure between the HPCS spraysparger and the . . .

#94. Reactor power is 100 %. Unit 2 drywell temperature is currently reading 105F and has beenincreasing consistently at a rate of 25F/hr. Assuming the rate of temperature change remainsthe same; LGA-003 “Primary Containment Control” must be entered in __________ minutes.

#96. Unit 1 and Unit 2 reactor building (RB) ventilation systems were operating when instrument airwas lost. The RB ventilation exhaust and supply dampers fail _____(1)_____ and RBmodulating dampers fail _____(2)_____.

#97. Both Units are operating at 100% power. An operator reported smoke in the vicinity of the 2ADG room and a RED CO2 alarm is on Panel FP04JB/JC.The CO2 system _____(1)_____ actuated. If required; manual actuation requires use of leversfor the master valve located _____(2)_____.

#98. The Unit 1 NSO receives annunciator 1H13-P601-C205; “1A RHR PMP Cubicle Temp Hi” anda report of smoke in the area. What is the expected status of the diesel fire pumps?”0A” Diesel Fire Pump is _____(1)_____; “0B” Diesel Fire Pump is _____(2)_____;

#99. If water intrusion created grounds that disabled all Division 1 and Division 2 125VDC power . . .

#100. Given the following conditions: – Unit 2 in Operating Condition 1 – 2VG023; “SBGT VQ XTIE Valve;” is OPEN – Primary Containment Vent and Purge (VQ) isolation valves are OPENThe Unit 2 SBGT (VG) train is inoperable because the lineup may cause damage to the . . .

#102. A plant event resulted in an off-site release. Possible entry conditions into the RadioactiveRelease Control Procedure are described below. The MINIMUM conditions that require theUnit Supervisor to enter the LGA-009 “Radioactive Release Control” procedure are . . .

#103. LGA-009 has been entered due to high offsite release. What affect; if any; does this have onpermissible radiation exposure limits?

#104. The following conditions exist: – Station blackout has occurred – Div 1 and Div 2 EDGs failed to start – SRVs were initially used for reactor pressure controlWhich of the means below would be available to carry out pressure control three hours afterthe SBO occurred?

#105. Which of the following meets the criteria of a fuel handling accident?

#107. A condition related to unknown reactor vessel water level where Adequate Core Cooling existsis described by . . .

#108. The LGA-010 Failure to Scram procedure level leg directs operators to lower reactor water levelrapidly to at least -60 inches if reactor power is above 3% or unknown. This lower water leveldecreases power . . .

#111. (QUESTION DELETED) Unit 1 was operating at 100% power with no equipment abnormalities noted. A surveillance testidentified one low pressure injection line permissive pressure switch; 1E21-N413; for LPCS;with a setpoint of 480 psig. The applicable TS required action(s) is (are) . . .

#112. The Technical Specification bases for the Main Steam Line Pressure-Low Primary ContainmentIsolation is . . .

#113. Unit 1 is operating at 100% power. The SAT was providing power to bus 141Y. Bus 141YVoltage decreased to 3800 Volts for ONE MINUTE. ACB 1412 _____(1)_____ AND operatorsshould respond IAW LOA-AP-101; “Unit 1; AC Power System Abnormal;” _____(2)_____section.

#119. LGA-009; “Radioactive Release Control” can . . .

#123. An operator on rounds reports that his digital dosimetry is alarming on dose rate while touringthe RT pump room. The indicated dose rate is greater than that allowed by the RWP. TheSRO should direct the rounds operator to . . .

#125. In order to move fuel; the fuel handling SRO must be . . .

#8. A ___(1)_ radiation trip in one channel of the Off-gas Post-treatment Monitoring Systemcombined with any other trip in the other channel will _(2)___.

#9. Identify how much water could be expected to be provided from the CRD system to the reactorpressure vessel under the following circumstances:No control rod motion; CRD lineup in a normal configuration: ___(1)_gpm. The reactordepressurized and CRD flow maximized: _(2)___gpm

#14. With reactor power at 16%; the nuclear station operator was performing a single notchwithdrawal on a control rod. If an RMCS abnormal condition occurred because Activity ControlUnits disagree; the RMCS will ___(1)_ and the operator should _(2)___.

#25. The liquid radwaste effluent monitor will automatically stop a discharge to the environment if themonitor identified ___(1)_ exceeded pre-established limits measured in _(2)___.

#29. Unit 1 is in Mode 2 with reactor pressure at 925 psig. The RCIC system is injecting to the RPVin pressure control mode with the RCIC controller in Manual. If reactor pressure increases;RCIC turbine speed ___(1)_ and flow _(2)___.

#35. Unit 2 was operating at power when a transient caused the reactor steam dome pressure toincrease to 1150 psig. Two of the ATWS trip units for Division 2 reactor pressure failed toinitiate.Under these circumstances; the recirculation pumps will ___(1)_ and the ARI system_(2)___.

#49. Main steam tunnel temperatures and pressures are increasing due to a steam leak in thetunnel. As main steam line tunnel pressure increases; the low pressure blowout panels willactuate relieving pressure to the ___(1)_ resulting in a/an _(2)___ release to theenvironment.

#50. Unit 1 was operating at 100% power; when the ” A” TDRFP tripped. Assuming no operatoraction and all other equipment operates as designed; both recirculation flow control valves areexpected to be at ___(1)_ and the recirculation pumps _(2)___.

#76. Diesel Generators ___(1)_ be used for peaking power requirements and _(2)___be started in anticipation of loss of offsite power.

#78. The Reactor Mode Switch is located on the ___(1)_ of panel H13-P603. When theReactor Mode Switch is required to be LOCKED; the key shall be located _(2)___.

#83. A condition occurs where the standby main generator stator cooling pump auto starts and statorcooling pressure remains at 40 psig.If this condition continues to exist; and stator amps remain greater than ___(1)_ for 2.0minutes; the Main Turbine will automatically _(2)___.

#96. Unit 1 and Unit 2 reactor building (RB) ventilation systems were operating when instrument airwas lost. The RB ventilation exhaust and supply dampers fail ___(1)_ and RBmodulating dampers fail _(2)___.

#97. Both Units are operating at 100% power. An operator reported smoke in the vicinity of the 2ADG room and a RED CO2 alarm is on Panel FP04JB/JC.The CO2 system ___(1)_ actuated. If required; manual actuation requires use of leversfor the master valve located _(2)___.

#98. The Unit 1 NSO receives annunciator 1H13-P601-C205; “1A RHR PMP Cubicle Temp Hi” anda report of smoke in the area. What is the expected status of the diesel fire pumps?”0A” Diesel Fire Pump is ___(1)_; “0B” Diesel Fire Pump is _(2)___;

#113. Unit 1 is operating at 100% power. The SAT was providing power to bus 141Y. Bus 141YVoltage decreased to 3800 Volts for ONE MINUTE. ACB 1412 ___(1)_ AND operatorsshould respond IAW LOA-AP-101; “Unit 1; AC Power System Abnormal;” _(2)___section.