IR 05000317/1998301
| ML20247F997 | |
| Person / Time | |
|---|---|
| Site: | Calvert Cliffs  |
| Issue date: | 05/07/1998 |
| From: | NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION I) |
| To: | |
| Shared Package | |
| ML20247F977 | List: |
| References | |
| 50-317-98-301OL, 50-318-98-301OL, NUDOCS 9805200109 | |
| Download: ML20247F997 (22) | |
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U. S. NUCLEAR REGULATORY COMMISSION REGION 1
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Docket Nos.: 50-317 and 50-318 l
l License No.: DPR-53 and DPR-69 Licensee: Baltimore Gas and Electric Facility: Calvert Cliffs Units 1 and 2 Location: Lusby, Maryland l
l Dates: April 1,1998 l Chief Examiner: J. D' Antonio, Operations Engineer / Examiner l
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l Approved By: Richard J. Conte, Chief Operator Licensirig and Human Performance Branch Division of Reactor Safety l
9905200109 990507 '
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EXECUTIVE SUMMARY Calvert Cliffs Nuclear Power Plant, Units 1 and 2 Inspection Report Nos. 50-317/98-301 (OLn and 50-318/98-301(OL)
Ooerations A retake written examination was administered to one Senior Reactor Operator (SRO)
candidate who had failed the original examination administered in October,1997. This individual passed the retake examination and was issued a licens ii
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Report Details
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l. Operations
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l 05 Operator Training and Qualifications l i l 0 Senior Reactor Operator Written Examination Scope A written retake examination was administered to one SRO instant applican Observations and Findinas The applicant passed the examination and was issued a licens The facility examination submittal was an improvement over the prior examination submittalin that far less revision was necessary for NRC approval. NRC comments resulted in changes to approximately 10% of the examination. The most common comment concerned one or more implausible distractors. No post exam comments were provided by the facilit Conclusions The facility had successfully remediated the applicant for the prior exam failur The examination submittal was an improvement over the October 1997 examination submitta V. Manaaement Meetina X1 Exit Meeting Summary An exit meeting was hald by telephone on April 29,1998. The NRC summarized the exam review comments. Participants were the NRC Chief Examiner and the facility Supervisor of Initial License Training, John Hornic Attachments: Calvert Cliffs SRO Written Exam w/ Answer Key l
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Attachment 1 CALVERT CLIFFS SRO WRITTEN EXAM W/ ANSWER KEY
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ES-401 Site-Specific Written Examination Form ES-401-7 Cover Sheet l
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U.S. Nuclear Regulatory Commission l Site-Specific Written Examination l
Applicant Information _
Name: Region: (iC/II/III/IV Date: Facility / Unit: G.Attl&cf CLlFM l$U j License level: R0 / SR0 Reactor Type: W/(Ch/BW/GE l
Start Time: Finish Time:
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Instructions Use the answer sheets provided to document your answer Staple this cover i sheet on top of the answer sheets. The passing grade requires a final !
grade of at least 80.00 percent. Examination papers will be collected four hours after the examination starts.
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Applicant Certification l
l All work done on this examination is my ow I have neither given nor received aid.
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Applicant's Signature Results Examination Value /d Points ( Applicant's Score Points l
l l Applicant's Grade Percent
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NUREG-1021 39 of 39 Interim Rev. 8, January 1997 (
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1. Given the following:
- Unit 2 has implemented AOP 7H (Loss of Plant Computer)
- DAS is not available Select the more restrictive limit which, when exceeded, requires a power reduction within the specified time interval:
A. Less than DNB limits within 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> B. pess than Linear Heat Rate limits within 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> C. Less than DNB limits within 1 hou D. Less than Linear Heat Rate limits within 1 hou . Unit 1 is in MODE 3 with Tavg at 5320 F, when one CEA is declared inoperable. How long after the detection of the inoperable CEA must the shutdown margin be verified?
A. Immediately B.1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> .
C.12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> D. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> 3. Which one of the following parameters would absolutely differentiate a steam line rupture inside containment from a LOCA inside containment?
j A. Containment Sump Leve B. Pressurizer Leve C. Containment Temperatur D. Subcooled Margi . An immediate change to an STP, that is not a change of intent, requires the approval of how many members of plant management staff, and who must one of these members be?
A. Two, Test Coordinato B. Three, General Supervisor or abov C. Two, a Senior Reactor Operator.
l D. Three, GS-NPO 5. STP M-212A-1 is in progress on Channel A RPS. Trip Units 1,2,7,8 and 10 are bypassed. Instrument Maintenance personnel discover an out of tolerance voltage for
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the high power trip unit. They suspect a bad power supply and request permission to l commence troubleshooting the problem. Who must authorize the Troubleshooting Control Form?
A. RMGS and CR B. RMGS, GS-Instrument Maintenance, and CR C. RMGS, CRS, and S D. RMGS, SS, and GS-NP NRCFINAL.TST Version: 0 Page: 1
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6. Tt.o satpoint for the normal liquid efflu:nt monitor is b s:d on assumptions in tha l
. Offsite Dose Calculation Manual (ODCM). .
l Which one of the following would require the Plant Computer activity setpoint to be decreased?
A. Decrease in actual release rate from 120 gpm to 90 gp B. Decrease in operating circ water pumps from 6 to C., Decrease in nionitor background radiation leve D. Decrease in Bay leve . An operator is assigned a task to monitor a resin transfer line for blockage. The operator's current dose for the year is 850 mrem. The task is expected to result in a dose of 100 mre Describe the procedure, if required, for extending the administrative dose limit:
A. No administrative dose limit extension is neede B. Dosimeter record review, Shift Supervisor and GS-NO approval C. Dosimeter record review, GS-NO and GS-RS approval D. EPD functional review, RadCon S/S and Shift Supervisor approval _
8.11 and 12 Heater Drain Pump Chiller Units are scheduled to be taken out of service for scheduled maintenance. The chiller units will be out of service for 23 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br />. The maintenance order describes only the inspection that the shop will be performing. You have directed the Principal Plant Operator (PPO) to place two " heat killer" fans in l operation at the Heater Drain Pump motors. What additional controls, if any, are required by plant procedures?
A. Initiate a Troubleshooting Control For !
B. Have the Shift Supervisor perform an evaluation and initiate a Temporary Alteratio C. Place the temporary fans in service, no additional action is require D. Initiate a Procedure Controlled Temporary Plant Configuration Chang . Unit 1 reactor startup following a refueling outage is in progress. The Shift Supervisor has assigned you as the Dedicated SRO for physics testing that NFM has just commenced. Prior to the start of the physics test you had been assigned as the Operations Work Control Center Coordinator (OWC). Which of the following functions may be performed by the Dedicated SRO?
A. Direct the immediate actions necesscry to place the unit in a safe conditio B. Make recommendations to the Shift Supervisor concerning the physics test data reduction activity.
! C. Review and approve Maintenance Orders.
l D. Approve emergent risk significant maintenance contingencie ..
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10. Unit 1 cors offloid is scheduled to begin within the nnxt week. Th3 Unit 1 Rsfu: ling Machine shall be demonstrated operable by performing the required surveillance within i
hours prior to the start of fuel movement, including demonstrating that the automatic overload cutoff functions when main hoist load exceeds pounds.
l A.72,3000 B. 72,1550
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11. given the following conditions for Unit-1:
1) PA912 = 2475
2) Th = 590.5 F
2) Tc = 546.5 F 3) ASI = +0.015 4) PZR pressure = 2250 PSIA
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Using appropriate Tech Specs, calculate actual Pvar and the resultant Ptrip value:
A. Pvar 1797, Ptrip 1875 B. Pvar 1875, Ptrip 1797 C. Pvar 1875, Ptrip 1875 D. Pvar 1811, Ptrip 1797 12. Refer to the attached Unit 1 Technical Specifications Core Operating Limits Report (COLR).
Unit 1 reactor power is 70% when a continuous CEA withdrawal occurs. When the withdrawal is stopped, indicated Axial Shape Index (ASI) is -0.29 and reactor power peaks at 79%. Unit 1 is using Excore Monitoring for LHR and DNB surveillance monitorin Which, if any, axial flux offset control limit (s) is(are) being exceeded?
A. Linear Heat Rate onl B. DNB onl C. Both Linear Heat Rate and DN D. Neither Linear Heat Rate nor DN . Which condition would require notification of the NRC within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of occurrence?
A. Performance of an STP that does not result in discharge to the RC B. SIAS actuation resulting from shundown of ESFAS cabinets per 01-3 C. Operator initiated manual reactor trip as part of a preplanned physics tes D. Pressurizer spray valve opening cue to high RCS pressur NRCFINAL.TST Version: O Page: 3
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14. A Unit 1 st:rtup is in prograss following e 7 d;y forced outago to replace en RCP sta You are performing the functions of the Dedicated SRO for the plant startup. Tha following conditions exist:
RPS Delta-T power 14%
Plant computer thermal power 17%
STA reports that RCS loop Th-Tc is consistent with a power level of ~18%.
Yo,u notice that the " LOSS OF LOAD CH TRIP BYP" alarm is still in alarm at 1C0 When should this alarm clear, when is the trip required to be ensbled, and what is the design basis of the trip? l A.12%, t 14%, helps avoid lifting the main steam line safety valve B.13%,214%, protects the RCS from overpressurizatio '
C.14%, t 15%, helps avoid lifting the main steam line safety valve D.13%,215%, protects the RCS from overpressurizatio . You are performing the function of the Operations Work Control Center Coordinator (OWC) when the Outside Operator reports that the 2A DG Standby Lube Oil Pump is making an unusual noise. The System Engineer and Mechanical Maintainence Supervisor recommend that the pump be replaced immediately as Priority 2 maintenance. What action, if any, should the OWC initiate per plant procedures? l A. Ensure completion of an Operational Risk Assessmen B. Authorize the Maintenanc C. Direct the Outside Operator to secure the lube oil pum j D. Direct the CRO to perform a breaker line-up verification J l
l 16. You are the Unit 2 CRS and you have directed the CRO to shift EHC Pumps to allow the System Engineer to observe pump perfom,ance. The' Unit 2 Turbine Building Operator, System Engineer, and Mechanical Maintenance Supervisor are standing by i at the EHC Unit. What additional actions, if any, are required by Operation's l procedures?
A. Shift EHC Pumps as requested, no additional action require B. Announce start of the EHC Pump over the plant page prior to EHC Pump star C. Have TBO evacuate unnecessary personnel from the area around the EHC Pumps.
l D. Announce start of the EHC Pump and evacuate unnecessary personnel from the l EHC Pump ,
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17. Given ths following:
- Due to a loss of all AC power, EOP 7 (Station Blackout) was implemented ~20 minutes ago
- Unit 1 is meeting the intermediate SFSC but Unit 2 is not meeting the intermediate SFSC for Core and RCS heat removal as a result of sabatoge
- The interim RAD estimates that a release of 2E6 uCi/sec is occurring and will continue for at least 2.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br />
- Wind direction from the DRDT screen is from the North Whpt Prompt Protective Action Recommendation should be made?
A. Shelter 10 mile EPZ B. Evacuate 10 mile EPZ C. Evacuate zone 1 and 3 and shelter the remainder of 10 mile EPZ D. Shelter zone 1 and evacuate remainder of 10 mile EPZ 18. Which of the following components under expected conditions will have Salt Water isolated to it during a SIAS? ~
A. SRW heat exchange B CCW heat exchange C. Circ water pump seat D. ECCS pump room cooler . The Miscellaneous Waste System receives liquid waste from which of the following major sources?
A. Containment tendon gallerie B. Containment normal sump and pumped sump C. Waste Gas Decay Tank condensst D. Evaporator distillat . The Containment Spray System is designed to limit containment pressure to less than its design value during a design basis accident. The system is also expected to be effective for which of the following:
A. Collecting and processing containment penetration leakag B. Preventing fuel and cladding damag C. Maintaining hydrogen concentration below 4%.
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21. What happens on a transfer from High Power to Low Power Mode if SG level rises to greater than +20" during the transfer?
A. The transfer continues at the same rat B. The transfer continues at 1/2 the original rat C. The transfer is suspended, the MFV returns SG level to normal in Auto, and the l BFV is held at current positio D. The transfer is suspended, the BFV returns SG level to normal in Auto, and the MFV is held at current positio .
22. Instrument Maintenance Shop plans to perform troubleshooting activities on Reactor Regulating System (RRS) Channel X & Y per MN-1-110. RRS Channel Y is selecte Trouble-shooting activities will begin on Channel X first. Which of the following actions may also be necessary?
A. Calculate and set the Power Ratio Calculator potentiometers per AOP-7 B. Fail the temperature instrument input to RR C. Remove Reactor hegulating NI inputs to the Digital Feedwater Syste D. Calibrate RRS Nls per 01-3 . Whicn one of the following annunciator alarms also indicates the presence of an t interlock which will prevent the start of 22A RCP?
A. " OIL RESVR LEVEL LO" B. " OIL LIFT PP PRESS LO" C. "CC TEMP H1'
D. "RCP BLDOFF FLOW Hl/LO" 24. Given the following:
- Unit 1 is 9t 100% power
- various alarms annunciate
- CRO reports that 12120 VAC Vital Bus (1YO2) indicates 0 volts at 1C24A Select the indication that is effected :
A. Channel B WRNI at 2C43 B. Channel B LRNI at 1C15 C. Channel A WRNI at 1C43 D. RRS Channel X LRNI at 1C05 NRCFINAL.TST Version: 0 Page: 6
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25. During troubinshooting efforts on ths Unit 2 Auxiliary Feedw: iter Actu; tion Syst:m, en
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inadvertent "AFAS A"is actuated. The "AFAS A ACTUATED" alarm is received in the Control Room. Which of the below listed combinations of component actuations should be expected to occur?
A. CV 4070a and 4071a OPEN to supply steam to the aligned steam driven pum B. CV 4070a and 4070 OPEN to supply steam to the aligned steam driven pump and 23 AFW pump START ~
C. CV 4071a and 4071 OPEN'to supply steam to the aligned steam driven pum D. CV 4070 and 4071 OPEN to supply steam to the aligned steam driven pum . The Control Room Ventilation High Radiation Monitor (RE-5350) fails high. Which of the following automatic component actions are expected to occur?
A. Main Plant Exhaust Fans STOP and Control Room Ventilation goes to RECIRC mod B. POST-LOCl Filter Fans START, Outside Air Dampers CLOSE and Toilet-Area Exhaust Fan STOP C. POST-LOCl Filter fan discharge dampers OPEN and Toilet Area Exhaust Fan START D. NSR Chiller Unit STOPS and Control Room SR HVAC STOP . Which of the following provides a possible indication of a failed incore detector?
A. CECORIBASSS display on the Plant Compute B. " Selected Computer Point" alarm at C0 C. Incore detector computer point in alarm below the limit on Plant Compute D. Small variations in reactor thermal power (PA 91112 Mwth).
28. Due to a problem on 2-TIC-223, 2-CC-223-CV fails shut causing Letdown Heat Ex_ changer outlet temperature to increase. What effect does this have on reactor power and why?
(Assume normal CVCS lineup)
A. Reactor power will decrease due to the increase in B-10 removal in the' CVCS lon Exchange B. Reactor power will decrease due to the resultant increase in B-10 concentration in the VC C. Reactor power will increase due to the resultant increase in B-10 concentration in the VC D. Reactor power will increase due to the increase in B-10 removal in the CVCS lon Exchanger.
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29. Unit 1 is op: rating G 100% pow r. RCS boron concentration is 161 ppm. The RO is
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mo.nitoring a 120 gallon DI water addition to the VCT. The following indications are observed:
Reactor thermal power at 2700 Mth and slowly increasing
Auctioneered Tc at 5480F
Highest RPS Tc at 5480F Which of the following actions should be performed first?
A. Trip the reactor and implement EOP- B. Insert Group 5 CEAs to 105".
C. Stop any makeup to the RC D. Perform a 10 second fast boratio . The correct action to take to trip the Unit 2 turbine on a loss of 125 VDC Bus.11 is:
A. Use trip button on 2002, it is unaffected by loss of 125 VDC Bus 11.
l B. Initiate turbine trip from either ESFAS logic cabinet by depressing either Turbine
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Trip Hi Level or RxTrip Bus Undervoltage bistable manual trip pushbutton.
l C. Station an operator at the front standard and when directed, manually trip the l turbine using the trip leve D. Enter the HP turbine doghouse and flip the MSR High Level Trip Bypass Switch up and down which will trip the turbine.
l l 31. The Control Element Assembly Position Display System (CEAPDS) uses a reactor power signal (Qmet) to generate which of the following functions?
A. Sequential Permissive signal.
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B. Shutdown Group Exercise limit.
l C. CEA Withdrawal Prohibit (CWP)
D. Secondary PDIL and PPDIL setpoints l
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32. Givsn th3 following: ~
- Unit 1 is in Mode 3 ^
- SIAS Pressurizer Pressure Blocked on both logic channels
- RCS pressure being reduced to 1500 PSIA
- PZR Spray valves fail shut and RCS pressure starts to increase Select the expected system response as pressure increases:
A. SlAS Pressurizer Pressure Block will be manually removed when the RO goes to
" NORMAL" at 1800 PSIA with the keyswitch for SIAS Block A at 1 C1 B..SIAS Pressurizer Pressure Block will be automatically removed when ZE and ZF i SIAS Pressurizer Pressure sensors clear C. SlAS Pressurizer Pressure Block will be manually removed when the RO goes to
" NORMAL" at 1800 PSIA with both keyswitchs for SIAS Block A and B at 1C1 D. SIAS Pressurizer Pressure Block will be automatically removed when ZD SIAS Pressurizer Pressure sensor clear . Given the following trend & alarms on the 128 RCP with Unit 1 at 100% power:
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l ANALOG TIME VIBRATION ALARMS 0000 14 mits 0100 18 mils - Alert "RCPs Vibration" alarm 0115 30 mils - Danger "RCPs Vibration" alarm 0130 36 mils 0135 0 mils What action should be taken?
A. Commence an expeditious plant shutdown, and then secure 12 B RC B. Trip reactor, implement EOP-0, perform Reactivity Control and secure 12 3 RC C.12B RCP must be secured within 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> with GS-NO concurrenc D. Immediately Contact Performance Testing Unit and GS-NO, evaluate vibration dat . As CRS, the CRO reports that the ABO noticed the Waste Gas Surge Tank pressure had lowered from ~4 PSIG to O PSIG. The CRO is concerned that if a vacuum is reached, air could mix with the H2 and result in an explosive mixtur What direction is appropriate for the CRO to verify:
' A. N 2Control Valve opens at 0 psi B. Waste Gas Surge Tank relief to Waste Gas header OPE C. Waste Gas Discharge isolation Valves 0-WGS-2191-CV and 2192-CV OPE D. Waste Gas Surge Tank drain trap aligned to Waste Gas Compressors.
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35. Givan tho following:
- Unit 2 has implemented EOP 4 (Excess Steam Demand)
- 21 SG blowdown in the Containment has been completed
- Containment temperature is ~2520F
- Containment pressure is - 47 PSIG
- Pressurizer level indicates - 128 " and pressure is - 1000 PSIA As the Containment Cooling Systems remove heat from the containment atmosphere, what effect is expected on th.e. indicated level in the Pressurizer compared to the actual level?
A. Indicated level will be less than actual level due to decreasing containment temperature, it will always be lower than actua B. Indicated level will be greater than actual level, and as the c.ontainment temperature lowers, it will approach actual leve C. Indicated level will be greater than actual level and will stay higher due to reference leg flashing as the containment temperature lower D. Indicated level will be less than actual level, and as the containment temperature lowers, it will approach actual leve . Following a design basis Loss of Coolant Accident the Containment Spray System fails to actuate as require \
As a result, the containment design pressure will be exceeded unless which of the following actions are taken as a minimum:
A. 2 Reactor Cavity Cooling Fans and 2 Containment Cooling Fans are started in SLOW spee B. 3 Containment Coolers are started in SLOW spee C. 3 Containment Coolers are started in FAST spee D. 4 Containment Coolers are started in FAST spee . A CAR unit has been shutdown and the inlet CV has failed to shut. If the CAR is in the
" Holding Mode", describe the effect, if any:
A. Air will not leak into the condense B. Air will leak into the condenser via the seal water recire pum C. Air will leak into the condenser via the hogging C D. Air will leak into the mndenser via the three way valv . WHICH ONE (1) of the following is the MAXIMUM hydrogen concentration allowed inside Containment before the Hydrogen Recombiners are required to be placed in servico?
A. 0.5%
B.2%
C.3%
D. 4%
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39. During refueling a new fuel css:mbly his just be n ins:rt d in its specifi d cors location when the FHS observes that the mast detent is at "0" vice "180" as required by the fuel handling procedure. Choose the answer that represents the applicable actions
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to be taken:
A. Withdraw the fuel assembly from the core, FHS and Shift Supervisor shall evaluate, and obtain written approval from the PE-NFM to resume core alteration B. Leave the assembly grappled and exit the refueling machine, the RCRO and FHS shall evaluate, and obtain verbal approval from the Shift Supervisor to resume core
, alteration C. Leave the assembly grappled and notify the Shift Supervisor and PE-NFM immediatel D. Withdraw the fuel assembly from the core, rotate mast to the correct detent, and reinsert the assembl . The most serious failure for the Spent Fuel Pool Cooling System is the loss of SFP Water. What feature of the system is designed to prevent this?
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A. Piping interconnection to either RW B. Cask Handling Crane modified to meet single failure criteri C. Two channels of remote level indication with alarm functio D. SFP pipe connections with siphon breakers, above the water level in SF . During a large break LOCA fuel cladding temperatures sharply rise within the first 20 seconds. Why does this occur?
A. MTC and doppler add positive reactivity to the core, raising power and temperatur B. RCS pressure drops to saturation pressure and the fuel rods are blanketed with stea C. RCPs trip due to SIAS and CIS and this results in no driving head for flo D. LPSI and SIT flows are blocked by the voiding in the reactor vessel downcomer regio . As the Plant Watch Supervisor you are conducting a tour of the Turbine Building.11 Plant Air Compressor is in service and you notice '.he following indications on the microcontrollers:
Alarm light is blinking
" SURGE" displayed in the function display What direction from the PWS, if any, is necessary?
A. Depress the ACK/ RESET pushbutton twic B. No action is require C. Place the MODE OF OPERATION handswitch to UNLOA D. Place the MODE OF OPERATION handswitch to MODULAT NRCFINAL.TST Version: 0 Page: 11
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43. During the performance of STP O-7B-2 on Unit 2 et 100% powar, the CRO reports that the Containment RMS isolation valve 2-RE-5291-CV fails to close on the SIAS signa What action is appropriate for this condition:
l A. Complete the STP, place the Containment RMS back in service, note the j malfunction in the STP.
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B. Shut 2-RE-5291-CV, deactivate the valve within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> per TS, note the malfunction in the ST C. Shut 2-RE-5291-CV within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, verify position once per shift, note the gnalfunction in the ST D. Notify System Engineer, evaluate STP results, note the malfunction in the ST .
44. Given the following:
l - Unit 1 is at 10% power with a Plant startup in progress l - Alarm "12 SG CONTR CH LVL" annunciated at 1C03 l - RO reports that 12 SG level by 1-LT-1106 indicates +63.5" and remaining SG level
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indications are at 0" Describe the effect on the Plant and action required:
A.12 Bypass Feedwater Valve will go SHUT requiring a manual Reactor trip and i implementation of EOP 0.
- B.12 Bypass Feedwater Valve will continue to maintain level, the downcomer selector j switch at 1C36 should be placed in the LT-1106 failure position to provide LT-1121 l
input to the control channel indication.
l C.12 Bypass Feedwater Valve will go SHUT, requiring manual operation by placing its ;
associated handswitch in the BYPASS Fall positio !
D.12 Bypass Feedwater Valve will continue to maintain level, a manual transfer from l l LOW to HIGH power of the DFWCS will be required for 12 Feed Syste j
i 45. You are the Unit 1 CRS. You are reviewing a Liquid Waste Discharge permit for'
discharging 12 RCWMT to Unit 1 Circulating Water System. The following plant i conditions exist:
Unit 1 .
Unit 2
- 90% power
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- Mode 5
- All CW Pumps tagged out * 23A Condenser Waterbox OOS for
What action should you as the CRS direct?
( A. Approve the discharge permit and give it to the Unit 1 CRO.
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B. Have Chemistry submit a new permit for discharge to Unit C. Pen and ink the permit to change to " Unit 2" and approve permit for discharg D. Have Chemistry hold the permit until 12 SW Header is returned to servic % *
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46. Unit 1 hrd been opertting continuously for 340 d:ys, wh:n a srntil RCS bak developed a short time ago. You are the Unit 1 CRS directing a r pid pow r reduction per OP-3 to place Unit 1 in hot standby. Unit i load is at 570 MWe. Reactor power is being lowered at the rate of 35% per hour. Tc is +2 degrees F from program Tc. The
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RO r3 ports that Tc is beginning to rise suddenly. What has occurred and what effect
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will there be on core reactivity?
(Note: Consider each condition separately)
A. TBV-3940 begins to shut, adds (+) reactivit B. S/G blowdown flow raised to 150 gpm, adds (-) reactivit C. MSR 2nd Stage High Load MOVs shut, adds (-) reactivit D. Low Pressure Feedwater Heater High Level Dump valves open, adds (+) reactivit . Given the following:
- Unit 1 is defueled and Unit 2 is in Mode 5
- Alarm "SFP TEMP Hi" annunciated at 1C13 Select the cooling mechanisms in preferred order per AOP GF (SFP Cooling Malfunctions):
A. Line up Unit 1 SDC to SFP system, place second SFP cooler in service, add makeup to SFP as water boils of B. Place second SFP cooler in service, line up Unit 1 SDC to SFP system, add makeup to SFP as water boils of C. Line up Unit 2 SDC to GFP system, place second SFP cooler in service, add makeup to SFP as water boils of D. Place second SFP cooler in service, line up Unit 2 SDC to SFP system, add makeup to SFP as water boils of .
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48. You havo just compl:ted watch r: lief as Unit 1 CRS. The off-going CRS had relat:d two occasions during the previous 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> where RPS Channel B Delta-T power had spiked high causing "HI POWER RESET DEMAND" alarms. A short time later you receive the following alarms and indications from Channel A RPS:
HI POWER TRIP RESET DEMAND
PROT CH TRIP
POWER LVL HI CH PRE-TRIP (NOTE: Above alarms are annunciating, then clearing every 5 seconds)
Channel A RPS T/U #1 is tripped
Delta-T power is steady
N.I. power is steady
Upper and lower linear range power is steady
Th and Tc are steady
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What actions would you direct?
A. Remove the three spurious alarm annunciators from service, no further action is necessar l B. Bypass Channel A RPS T/Us 1,2,7,8 and 10 per Tech Spec C. IM troubleshoot the RPSICP drawer to determine what is malfunctionin D. Document problem on an issue Report, no further action is necessar l I
49. Given the following: l
- Unit 1 is in Mode 6 l
- Fuel Handling is in progress l l
- Containment Purge is in operation
- CRO reports that he will be performing a functional test of RMSs at 1C22 per 01-35 As the CRS, what monitor should NOT be tested (per 01-35) that provide AUTOMATIC ACTIONS during a fuel handling incident in the Containment?
l A. Fuel Handling Area Monitor (RI-5420)
l B. Containment Area Radiation Monitor (RI-5316A-D)
l C. Wide Range Noble Gas Monitor (RIC-5415)
D. Containment ICI Area Monitor (RI-7008)
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50. Given tha following:
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- Unit 1 and Unit 2 are at 100% power
- ESO requires P-13000-1 OOS for maintenance
- RO has been directed to shift Unit 1 RCP power supply to P-13000-2 Describe the proper method to shift an RCP power source to the opposite Unit:
A. RO starts oil lift pump, insert synch stick, observes no rotation of synchroscope at 1C01, close the breaker at 1C0 B. RO starts oil lift pump, insert synch stick, observes no rotation of synchroscope at s1C19, close the breaker at 1C19.
l C. RO inserts synch stick, observes no rotation of synchroscope at 1C01, close the breaker at 1C19 D. RO inserts synch stick, observes no rotation of the sychroscope at 1C19, close the breaker at 1C0 . Given the following:
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- Unit 2 is in Mode 1 at 10.5% power
- Main Turbine startup in progress per Ol-43A -
- DFWCS in automatic
- LT-100X Pressurizer level channel selected
- HS-100 is selected in "X / Y" position Describe the effect on the RCS if LT-110X fails due to a leak in the reference leg:
A. No change in Pressurizer level due to LT-110Y will compensate with HS-100 switch positio B. Indicated Pressurizer level will decrease as Letdown goes to maximum exceeding Charging pump capacit C. Actual Pressurizer level will decrease as Letdown goes to maximum, PZR Backup Heaters energiz D. Actual Pressurizer level will increase as letdown goes to minimum and backup Charging pumps star NRCFINAL.TST Version: 0 Page: 15
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52. A mrjor trcnsinnt occurred a short time ego on Unit 2. You cro th3 Unit 2 CRS cnd you are directing the implementation of EOP-0. The following conditions exist:
RCS pressure 1130 psia and lowering
Pressurizer level 35" and lowering
RCS subcooling 42 0F and lowering
Containment pressure 1.5 psig and rising .
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The RO is performing the RCS Pressure and Inven;ory Safety Function. He reports that SIAS actuation has been verified but there is no HPSI flow indicated. 21 and 23 l HPSI Pump amps and discharge pressure are low. What action would you recommend to the Shift Supervisor?
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A. Start 22 HPSI Pum B. No action necessary, the flow indicators must have failed.
! C. Stop, then restart 21 and 23 HPSI Pump D. Place all operating ECCS Pumps in PTL, verify valve lineup, vent pumps: ;
53. Given the following:
- Unit 1 is at 100% power
- The 18 DG is running unloaded for post maintenance testing, Electric Shop and Mechanical maintenance perconnel are standing by in the 1B DG Room l - CRO reports a"1B DG" alarm is received at 1C188 i
- OSO reports a " START FAILURE" alarm is received at the 1B DG Alarm panel l'
l - Electricians suspect blown fuses, requesting to replace them
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immediatel Using the provided electrical schematic, determine which fuses have resulted in the
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indicated response on the 18 DG and will provide direction from you the CRS for ;
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replacement:
A. Fuses FU7 and FU8 due to the start failure alarm that was annunciated from the loss of control powe B. Fuses FU1 and FU2 due to the start failure alarm that annunciated from the loss of control powe C. Fuses FU3 and FU4 due to start failure alarm from the engine running with the air start solenoids failed clos D. Fuses FU5 and FU6 due to the start failure alarm from the loss of power to the low speed and auxiliary stop relay NRCFINAL.TST Version: O Page: 16
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54. Blp:d end feed operations to cool th3 Unit 1 Quinch Tenk hava just been compl:te Given the following indications of the Quench Tank parameters: .
1) Pressure 3 psig 2) Temperature 1050F 3) Level 23.5 inches Determine if any off normal conditions exis _
A. All parameters norma B. Pressure is too lo C. Temperature is too lo D. Level is too lo . A loss of instrument air has occurred while on SDC with purification in service. What effect does this have on valve position of SI-306 (SDC Flow Control), SI-657 (SD ,
TemplFlow Cont.), and CVC-500 (VCT Diversion Valve)? (IN ORDER)
A. Fails OPEN, fails OPEN, and fails to WPS positio B. Fails CLOSE, fails CLOSED, and fails to WPS positio C. Fails OPEN, fails CLOSED, and fails to VCT positio D. Fails CLOSED, fails OPEN, and fails to VCT positio . Which one of the following conditions is indicated when the LOAD CHANNEL light on the Unit 2 turbine control panel is lit?
A. Failure in the impulse Pressure feedback loop has occurred and the EHC system is in the IMP OUT mod B Failure in the impulse Pressure feedback loop has occurred and the EHC system is in the TURBINE MANUAL mod C. Failure of the Turbine Actual Reference counter has occurred and the EHC system is in the TURBINE MANUAL mod D. Failure of the Turbine Actual Reference counter has occurred and the EHC system is in the IMP OUT mode.
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57. Following a Unit 2 reretor trip from 100% power tha following picnt conditions exist:
Pressurizer Pressure 800 psia
Containment Pressure 4.5 psig
All automatic systems have acuatated as designed Which one of the following describes the automatic response of the Component Cooling (CC) System based on these conditions?
A. Only the CC Heat Exchanger Salt Water (SW) outlet valves shu Both Shutdown Cooling (SDC) Heat Exchanger CC outlet valves ope All CC pumps start.
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B. Only the CC Heat Exchanger Salt Water (SW) inlet valves shut.
I CC Containment isolation valves shu Both 21 and 22 CC pumps star C. Both CC Heat Exchanger SW inlet and outlet valves clos Both SDC CC outlet valves ope CC Containment Isolation valves shu .
CC supply to Liquid Waste Evaporators shut Both 21 and 22 CC pumps star D. Both CC Heat Exchanger SW inlet and outlet valves clos Both SDC CC outlet valves ope CC Containment Isolation valves shu CC supply to Liquid Waste Evaporators shut All CC pumps star . On a loss of MCC-214, which boration flowpath would be available?
A. RWT outlet and a charging pum B. 22 BA pump, BA direct m/u valve and a charging pum C. 21 BA pump, BA flow control valve, VCT to a charging pum D. 21 or 22 BAST gravity valves and a charging pump 59. Which one of the following is the reason that core flush is NOT established before 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> following a LOCA?
A. Boron precipitation is not a problem due to large steam flow through the brea B. Avoid entrainment of Si flow in the steam being released from the cor ~ C. Maximize cold leg injection due to high decay heat loa D. Allow for Rx vessel head cooling to minimize void formation in the head.
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60. Which ons of the following is a condition n: cess 2ry to ensura cdaquato RCS cooling flow exists during a large break LOCA per EOP 57 .'
A. Indicated Steam Generator water levels are maintained at ~0" B. CET temperatures trend consistent with Tcol C. Injection via operating SI pumps per EOP attachmen D. RCS subcooling is 50 0F based on CET . A rupture occurs downstream of 22 SRW Heat Exchanger SW control Valve, 2-SW-5212. What actions per AOP-7A (Loss of Salt Water) would allow for continued operation of the SW System?
A. Manual start of 23 SW pump on 22 SW heade B. Lineup 21 SW header as an emergency overboard flowpat C. Lineup 22 SW header as an emergency overboard flowpat D. Manual start of 23 SW pump on 21 SW heade .
62. Given the following:
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An Excessive Steam Demand Event (ESDE) has occurred and BOTH steam generators are affecte WHICH ONE (1) of the following parameters should be used to determine the steam generator to be isolated?
l A. The steam generator with the highest Tcol B. The steam generator with the lowest steam pressur C. The steam generator with the lowest AFW flo D. The steam generator with the highest leve . Given the following:
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Unit 1120VAC bus 1YO1 has been los Operators are being directed per AOP-7J, " Loss of 120 Vital AC Power," to shut Letdown Isolation Valves (CVC-515, 516).
l Which one of the following is the reason for closing these valves?
A. They have no control indication available and placing them in the shut position is a conservative actio B. They will eventually lose control air because instrument air to containment is los C. To isolate any potential leakage flowpath while power is los D. To minimize transients on the loop charging inlet nozzles when power is restored.
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64. With Unit 2 ct 850 MWE, cli MSR's in strvice, e rc ctor trip occurs. What op rator I action (in the Control Room) rnust be taken to prevent an overcooling of the RCS per EOP-07 l
A. Press "Close Valves" button on the turbine control panel.
! B. Press " Reset" button on the MSR control panel.
l C. Observe that MSR source valves go shut.
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D. Press the "MSR Trip" button 1 ,
65. Given the following:
l * Unit 2 tripped
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- EOP-5 (Loss of Coolant Accident)is implemented l
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- a concurrent loss of AC power occurs What is the MAXIMUM design time available to restore power to the affected battery
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l chargers?
A. 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> from initial loss of power B. 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from initial loss of power C. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> from time of Reactor Trip D. 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> from time of Reactor Trip 66. Given the following:
- Unit 1 completed heatup to Mode 3 at NOT and NOP on this shift
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- 1C06 alarm E-59 "12A RCP SEAL / TEMP Hl/ PRESS" annunciated
- CRO reports CCW temperatures, pressures and head tank level normal at 1C13
- RO reports 12A RCP temperatures have rlowly increased during the heatup of the RCS, parameters are normal for all other RCPs Select the action required for the apparent reason for the 12A RCP alarm:
A. Verify CC 3832 and 3833 open,one CC Containment isolation CV is shu B. Start a second CC pump, RCW evaporator in operatio C. Check CC flow to 12A RCP, additional flow is needed for RCDT HX coolin D. Check RCS leakrate,12A RCP integral heat exchanger has a CCW lea . Which one of the following describes the immediate effect on Shutdown Margin as defined by Tech Specs for a dropped CEA7 A. Shutdown Margin is unchange B. Shutdown Margin is reduced by the worth of the CE C. Shutdown Margin is increased by the worth of resultant power chang D. Shutdown Margin is unchanged by the offsetting Xe reactivity effects.
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68. Which condition is recuires entry into the LCO per Tech Specs for Containment isolation Valves in Mode 17 A. Pressurizing the safety injection tanks with nitroge B. Filling the safety injection tanks from the RW l C. Hot leg sample valve, PS-5467-CV, fails open after completion of samplin f
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D. Quench Tank vent , RC-400-CV, fails open after venting Quench Tan . Given the following:
-' Unit 2 is at 100% power
- various alarms annunciate indicating possible loss of power
- CRO reports 0 voltage indication for 2YO9 at panel 1C24A As the CRS, you direct the implementation of AOP-71 for the loss of 2YO9. A few minutes later, the RO reports that Reactor power is slowly risin Select the direction required by you to mitigate this effect and the basis:
A. Reduce reactor power and turbine load due to increased steam flow through MT Interceptor Valv B. Trip the Reactor, implernent EOP-0 due to a dilution event in progres C. Secure Charging and Letdown due a dilution event in progress .
D. Reduce reactor power and turbine load due to feedwater system cooldow . Given the following:
- Unit 1 is in Mode 3, NOT and NOP
- Both SRW heat exchangers were cleaned last shift
- Alarm "11/12 SRW HX SRW OUT TEMP HI" annuciates at 1C13
- CRO responds and reports that 11 SRW Heat exchanger outlet temperature reads 98 0F and steady.12 SRW heat exchanger outlet temperature is normal
- CRO reports that 11 SW he.ader pressure is 30 PSIG and 12 SW header pressure is 20 PSIG As the CRS, you direct the CRO to take actions per the Alarm Manual. The CRO reports that adjustment of the output on 11 SRW heat exchanger SW control valve had no effect on lowering outlet temperatur Select the direction required by you to respond to this condition:
A. Direct implementation of AOP 7A(Loss of SW) to determine if a SW system rupture exist B. Direct implementation of AOP 7B (Loss of SRW) to determine if a SRW system rupture exist C. Direct implementation of AOP 7A (Loss of SW) to determine if SW system flow blockage exist D. Direct implementation of AOP 78 (Loss of SRW) to determine if SRW system heat loads are excessiv Page: 21 NRCFINAL.TST Version: 0
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71. Given the following:
- Unit 1 is operating at 100% power.
- Alarm 1C13, CC PP(S) DISCH PRESS LO, has actuate WHICH ONE (1) of the following RCP conditions requires the operator to trip both the I reactor and the reactor coolant pump?
A., Upper thrust bearing temperature ,s 1970 B. Controlled bleed off flow is 2.0 gp C. Guide Bearing temperature is 1930 D. Component cooling water outlet temperature at the RCP is 1350 . Given:
Both Units 1 & 2 are at 100% power
A Loss of Offsite Power occurs
All DGs start and load as expected
EOP-0 is implemented for both units
Condenser vacuum is 22" HG on both Units Select the expected response on steam dumping capabilities for both Units:
A. Unit 1 TBVs are operable, Unit 2 TBVs are operabl B. Unit 1 TBVs are inoperable, Unit 2 TBVs are operable C. Unit 1 TBVs are inoperable, Unit 2 TBVs are inoperabl D. Unit 1 TBVs are operable, Unit 2 TBVs are inoperable 73. During a main steam line break event (ESDE), unaffected S/G temperature must be maintained within 25 0F of CET temperature while blowdown of the affected S/G is in progress. Which one of the following is the basis for this limitation?
A. Prevents an excessive RCS heatup after blowdown of the affected S/G is complet B. Minimizes leakage from a SGTR which may occur after blowdown is complet C. Minimizes time for RCP restart after blowdown by equalizing primary to secondary SG temperatures D. Prevents the formation of tube voids after blowdown of the affected S/G is complet .
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74. Giv:n tho following:
- Unit 2 is in Mode 3 with EOP-2 (Loss of Offsite Power) implemented
- Plant cooldown has commenced due to condensate inventory
- 21 loop Th 5200F and Tc 5250F
- 22 loop Th 5350F and Tc 520 F Which of the following is the required action for this condition?
A. 4ncrease steaming from 22 SG via TBV B. Increase steaming from 21 SG via 21 AD C. no action required, this is a normal conditio D. Restart RCPs when power is availabl . Given the following:
- Unit is manually tripped due to Loss of Instrument Air
- RCPs are secured approximately 15 minutes later due to RCP temperature limits reache Which of the following is a required action per EOP-2:
A. Monitor RCS loop differential pressures for 5-15 minutes to ensure proper RCP coastdow B. Monitor RCS loop temperatures for 5-15 minutes for thermal driving head developmen C. Immediately increase the Steaming rate from both SGs by opening all TBVs to establish natural circulation condition D. Immediately shut ADVs and TBVs to establish natural circulation condition . A discharge of the Miscellaneous Waste Monitor Tank is in progres Which one of the following conditions would require entry into AOP-6B, " Accidental Liquid Waste Release"?
A. Trip of a Circ Water Pump on the unit receiving the discharge with no corresponding reduction in discharge flow rat B. LQD WASTE DISCH valves (2201 and 2202 CVs) OPEN with discharge RMS alar . C. Discharge activity exceeds the computer alarm high setpoint specified in the release permi D. Discharge activity decreases to less than the Discharge Permit background activity value.
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77. A fire is reported to the Control Room in Unit i 12 foot turbine Building at 1000. The Fire Brigade responds at 1004 and reports that 11 SGFP pump oil has leaked out and ignited. Due to the oil leaking out, it flows down to the bowser room in the condenser pit and ignites the lube oil bowser. The fire in tha 12 foot is extinguished at 1008 and the fire in the lube oil bowser room is extinguished 5 minutes late Select one of the following that describes the ERPIP Emergency Action Level (EAL) for this event:
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l A.'An EAL is not required because less than 15 minutes has elapsed since fire fighting bega B. An EAL is nct required because non-safety related equipment is involve C. An EAL event is required because the fire burned for greater than 10 minute D. An EAL event is required because the fire affected Appendix R equipmen . Given the following:
- Unit 1 is in Mode 3, NOT and NOP (previously was at 100% power for 245 days)
- Chemistry reports that the trend on weekly samples indicate an increase in the RCS activity for non-soluble matter
- NFM reports that CECOR data indicates that fuel rod fouling is increasing Which condition will cause 1C07 alarm F-21 " RAD MON LVL Hi" to alarm AND a dose rate change in the Letdown line?
A. LOCA inside the Containment resulting in stopping RCPs after CIS actuatio B. LOCA outside the Containment resulting in activity in the 27' West Penetration Roo C. Establishing forced circulation by starting RCPs after a Loss of Offsite Powe D. Starting additional Charging pumps in response to an RCS lea . Given the following:
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Unit 1 has received a Reactor Protection System input which requires a reactor tri The Reactor has not trippe The MANUAL reactor trip buttons have failed to actuate a reactor tri WHICH ONE (1) of the following methods is used NEXT to shutdown the reactor per EOP-0, " Post Trip immediate Actions"?
A. Trip the main turbin B. De-energize the CEDM motor generator set C. Commence RCS boration using BAST gravity feed valve D. MANUALLY drive the CEAs into the cor NRCFINAL.TST Version: O Page: 24
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- Specific activity of the reactor coolant has exceeded 1.0 microcurin/grcm DOSE EQUIVALENT l-131 for greater than 100 continuous hours interva Which one of following is the basis for the requirement to cooldown below 500 F within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />?
A. Prevents the release of activity should a SG tube ruptur _
B.Jncreases reliability of the data collected for actual lodine determination per ODC C. Minimizes the expected lodine spiking phenoma from the large change in thermal power due to plant shutdow D. Increases the coolant density to enable self-shielding to reduce on-site exposure . Given the following:
3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> ago
- Once-thru-Core Cooling in progress
- RCS pressure is 700 PSIA
- Tc is 5050F, CET is 5070F
- Total HPSI flow is 340 gpm Which of the following describes the condition of Unit 2 and required action:
A. Reactor core is partially uncovered, immediately increase HPSI injectio B. Reactor core is covered, immediately increase cooldown via SG C. Reactor core is partially uncovered, immediately lower RCS pressure via Aux Spray using charging pump D. Reactor core is covered, immediately lower RCS pressure via Aux Spray and charging pump . The Chemistry Tech has reported to the CRS that the weekly sample of #13 WGDT (onservice) has been completed. The analysis results are 9 curies of noble gas and l 5% O2by volume.
l What are the required actions for the sample results per Tech Specs?
A. Isolate #13 WGDT, sample WG surge tan B. Maintain #13 WGDT in service, have RCS sampled for activit C. Isolate #13 WGDT, reduce O2 concentratio D. Maintain #13 WGDT in service, monitor letdown process rad monito .
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83. Whtt cction is requir:d to prev:nt a common moda frilura during SDC op ration p;r
Operating Instruction 3B7 A. STBY Pump H/S in "PTL" B. Recire SDC header prior to initiating SD C. Running 2 LPSI Pump D. MOV jog limit _
84. Given the following:
- Unit 1 in in Mode 5, shutdown for 7 days
- RCS pressure is 200 PSIA and temperature is 1800 F
- 12 LPSI pump is OOS for maintenance i The RO reports that the ABO noticed that 11 LPSI pump outer pump bearing is 1 overheating. Shortly thereafter, The CRO reports that 11 LPSI pump tripped and the TBO reported that the breaker tripped on overcurrent and the relay can not be rese Which of the following actions is the first to be taken to restore core cooling?
A. Establish core cooling by bleeding steam from the SG B. Reduce RCS pressure and line up CS pumps on SD C. Start a HPSI pump, open the PORVs to cool the core via RCS blowdown to the containmen D. Start a charging pump, open PORVs to cool the core via RCS blowdown to the containment I 85. Given the following conditions:
- Unit 1 at 80% power
- PZR backup and proportional heater control in auto I
- 1-HS-100 (PZR pressure control) in the "Y" position l
- 1-HS-100-3 (PZR htr cutoff) in the "X+Y" position
- 1-PT 100Y fails high Select the expected plant response prior to any Operator action being taken:
A. Letdown control valves will open due to common mode failure effec B. PZR heaters will deenergize and spray valves will ope C. PZR heaters are unaffected and spray valves will ope D. PZR heaters will deenergize and spray valves are unaffected.
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86. Th:ro cro 3 basic types of LOCAs the safcty injection syst:m is dasignnd to '
compensate for. However, operator response must vary depending on the actual size of the break. If RCS pressure has reduced to 1320 psia strictly due to a LOCA event the focus of operator actions should be to:
A. verifiy that SIAS, CIS and CSAS have properly initiated and realign safety injection to a recirculation mode upon receipt of a RA B. establish and maintain core and RCS heat removal via forced or natural circulatio C. establish and maintain natural circulation flow while adjusting HPSI flow to provide inventory contro D. maximize charging, throttle SRW flow to CACs, and monitor Core and RCS heat removal for further degradatio . The plant has experienced a small break LOCA. Using the following plant conditions calculate the subcooled margi Core exit thermocouple read 6000 All RCPs are stoppe Pressurizer level indicates 300".
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That indicates 5900 Tcold indicates 5600 Pressurizer pressure indicates 1545 psia (lowest channel)
A. 5 F subcoole B 0 F0 subcoole C. 5 0F above saturation temperatur D.10 F0 above saturation temperatur . AOP 2A has been implemented for Excessive RCS Leakage. What condition (s) will identify a leak located on the charging header?
A. Decreasing PZR level with minimum letdown flo B. Charging header pressure greater than RCS pressur C. Charging header flow < 44 gpm with one charging pum D. Charging header pressure less than RCS pressur NRCFINAL.TST Version: 0 Page: 27
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89. Given ths following:
- Unit 2 is in Mode 2 with Shutdown Rods ARO and Reg Rods ARI
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- Channel B WRNI indication failed low, CRO recommends declaring it OOS Select one of tha following which describes the condition allowed by Tech Spec:
A. Trip _ or Bypass affected RPS bistables within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, repair Channel B WRNI, continue Plant start u B.Yrip or Bypass affected RPS bistables within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, continue with Plant start u C. Repair Channel B WRNI within 1.25 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />, continue Plant start up.
l D. Repair Channel B WRNI within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />, continue Plant start u . During a loss of instrument air during MODE 1 operation, when would the reactor and turbine be tripped and EOP-0 implemented?
A. If instrument air pressure decreases to less than 40 psig AND in the opinion of the SS or CRS continued plant operation may cause equipment damage.
l B. If instrument air pressure decreases to less than 40 psig OR in the opinion of the SS or CRS continued plant operation may cause equipment damage.
i C. If component cooling containment isolation valves, CC-3832-CV or CC-3833-CV, begin to go shut AND low flow alarms received on the RCP D. if component cooling containment isolation valves, CC-3832-CV or CC-3833-CV, begin to go shut OR in the opinion of the SS or CRS continued plant operation may cause damage to RCP . Given the following: 1
- "CNTMT RAD LVL Hi" at 2C10 is received and verified as valid by the CRO, What procedural actions are required?
i A. Parallel implementation of EOP-5(LOCA) concurrent with EOP- B. Implementation of EOP-8 (Func Recovery) due to EOP-4 Cont Env SFSC not me C. Implementation of EOP-8 (Func Recovery) due to EOP-4 Rad levels SFSC not me D. Parallel implementation of AOP-6A (abnormal RCS activity) concurrent with EOP-4.
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92. Giv:n the following: *
- Unit 1 and Unit 2 tripped due to loss of all AC power, implemented.EOP 0
- Unit i sustains a LOCA concurrent with the loss of all AC power
- Unit 2 implements EOP 7 (Station Blackout)
- Unit 1 implements EOP-8 (Functional Recovery)
(Assume no safety functions are currently being met on Unit 1)
Select the correct success paths in order of implementation based on the safety function hierarchy for Unit 1:
A. RC, VA, PIC, HR, CE, RLEC B. RC, PIC, HR, VA, CE, RLEC C. RC, HR, PIC, VA, CE, RLEC D. RC, VA, HR, PIC, CE, RLEC 93. U-2 is operating at 100% with RCS boron concentration at 965 ppm when a reactor trip (no SlAS) occurs. The RO observes that 4 CEAs do not have their rod drop light energized but 3 of the 4 CEAs have their LEL (green light) energize Per EOP-0, what action (s), if any, are required for Reactivity Control Safety Function?
A. Monitor for drop in reactor power, a negative SUR and borate to at least 1165 pp B. Monitor for drop in reactor power, a -1/3 DPM SUR and make a note to inform the CRS of CEA indication problem C. Inform CRS that Reactivity Control Safety Function is complete and you are checking CEAPDS to determine status of all CEA D. Monitor for drop in reactor power, a negative SUR and borate to at least 2300 pp . Given the following:
- Unit 1 is at 50% power
- Maintenance is in progress on 11 Charging pump
- alarm at 1C17 " RAD MON PANEL 1C22" annunciated
- CRO reports that " UNIT 1 WP VENT" alarmed with 1-RI-5410 reading 1000 cpm
- ABO reports that 11 Charging pump was inadvertently vented As CRS, select the proper response to these conditions:
A. Direct CRO to acknowledge the alarm and remove the monitor from service until completion of maintenance on 11 Charging pum B. Declare the 1-RI-5410 OOS due to alarm setpoint is set too low, have CRO refer to Alarm Manual for compensatory action C. Direct CRO to acknowlege the alarm and bypass 1-RI-5410 for duration of maintenance on 11 Charging pum D. Direct CRO to monitor for trends on 1-RI-5410 and notify Rad Safety and Shift Superviso I NRCFINAL.TST Version: 0 Page: 29
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95. Given th3 following:
', - Unit 1 is tripp:d dus to guidance contain:d in AOP-2A (Excessivo RCS Leakage)
- EOP O is implemented and a diagnosis is made for a SGTR in 12 SG
- EOP 6 is implemented
- RO is lowering RCS pressure {
During implementation of EOP 6 (SG Tube Rupture) procedural guidance is given to l maintain subcooling at a different value than EOP 0.
l As the CRS, select the proper direction and the basis for maintaining the subcooled :
malgin requirement: I A. Maintain subcooling >25 0F to minimize the RCS leak rat B. Maintain subcooling >30 F to ensure adequate NPSH for RCP C. Maintain subcooling > 25 0F to minimize excessive Safety injection flowrat D. Maintain subcooling > 30 0F to minimize backflow from the affected SG .
96. Given the following:
- Unit 2 is in Mode 2, EOL and at ~2% Reactor power with Main Turbine tripped
- 21 SGFP running with 22 SGFP lined up in STBY
- AFW system aligned for normal operation
- The RO reports that Tc is lowering, approaching 5150 F Tavg and Reg Group 5 CEAs have being withdrawn from 125" to raise power and restore RCS Tavg
- The CRO reports that 21 SGFP overspeed and tripped on high discharge pressure
- Shortly thereafter, the RO reports Unit 2 is in Mode 1 with .5 DPM SUR As the CRS, describe the action (s) required and basis for the decision:
A. Direct the insertion of Reg group 5 to return to Mode 2, start up 22 SGF B. Direct a reactor trip due to positive reactivity excusion from execssive CEA motio C. Direct the insertion of Reg group 5 to maintain power at 5%, start 23 AFW Pum D. Direct a reactor trip due to a positive reactivity excusion from excessive cooldow . Given the following:
- Unit 2 tripped from 100% power
- EOP-0 " Post Trip Immediate actions" are being performed
- The Main Turbine did not trip as expected Which one of the following actions should be performed per EOP-0 to trip /stop the turbine?
A. Manually close both MSIV B. Manually stop EHC pump C. Manually Shut Turbine Throttle Valves using Test pushbutton D. Locally trip the Turbine from the front standar l NRCFINAL.TST Version: O Page: 30
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98. Given ths following:
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- Unit 2 is et 80% powar '
- Unidentified RCS leakage is .5 GPM
- No SG leakage is identified
- RO reports that VCT trace indicates an increase in RCS leakage As the CRS, you direct the implementation of AOP 2A (Excessive RCS leakage).
Which of the following conditions would require Unit 2 to be shutdown per T.S. 3.4.6.27 A. 5 GPM leakage identified from body of 2-CVC-500 (VCT Diversion).
B. 5 GPM leakage identified from the packing gland on PORV-40 C. 5 GPM leakage identified from RCP intregral heat exchange ]
D. 5 GPM leakage identified from seat of SI-652-MO . Given the following: )
- Reactor power is at 100% ;
- A transient has caused pressurizer level to DECREASE 14 inches below the programmed leve The Pressurizer Level Control System is in AUTOMATI The Charging Pump operational mode selector switch is in the "13 + 11" positio i WHICH ONE (1) of the following describes the response of the Pressurizer Level i Control System? !
A. Charging pumps 11,12, and 13 will be running and letdown flow will be isolate l
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B. ONLY the 13 charging pump will be running and letdown flow will be isolate C. ONLY charging pumps 12 and 13 will be running with letdown flow at minimu D. Charging pumps 11,12, and 13 will be running with letdown flow at minimu . The 4 major actions of EOP-2, Loss of Offsite Power are designed to:
A. Protect the condenser from overpressure, restore forced circulation, restore RCS pressure, and restore affected electrical buse B. Protect the condenser from overpressure, verify shutdown sequencer loads operating, establish inventory control and restore affected electrical buse C. Restore affected electrical buses, maintain natural circulation, commence plant cooldown to shutdown cooling entry conditions and determine appropriate ERPIP action D. Minimize inventory losses, isolate the affected steam generators, depressurize and cooldown to shutdown cooling entry condition ,
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Thursday, March 26,1998 @ 08:18 AM Answer Key Page: 1 Test Name: NRCFINAL.TST Test Date: u gg Question ID Type Pts 0 1 2 3 4 5 6 7 8 9 1: 1 EMER PROCEDURES 005 MC-SR 1 D A B C DA B C DA 1: 2 CONDUCT OF OPS 002 MC-SR 1 B C DA B C D A B C
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1: 3 EMEP PROCEDURES 001 MC-SR 1 D A B C DAB C DA 1: 4 EQDIPMENT CONTROL 001 MC-SR I C DA B C DA B C D 1: 5 EQUIPMENT CONTROL 005 MC-SR I C DA B C DA B C D 1: 6 RADIATION CONTROL 001 MC-SR 1 C DA B C DA B C D 1: 7 RADIATION CONTROL 002 MC-SR 1 C DA B C DA B C D 1: 8 EQUIPMENT CONTROL 003 MC-SR 1 B C DA B C D A B C 1: 9 CONDUCT OF OPS 003 MC-SR 1 A B C D A B C DAB l- 10 CONDUCT OF OPS 004 MC-SR 1 A B C D A B C D A B 1: 11 CONDUCT OF OPS 006 MC-SR 1 A B C D A B C D A B 1: 12 EQUIPhENT CONIROL 002 MC-SR 1 A B C D A B C DA B l- 13 CONDUCT OF OPS 001 MC-SR 1 B C DA B C D A B C 1: 14 EQUIPMENT CONTROL 006 MC-SR I C DA B C DA B C D 1: 15 EQUIPMENT CONTROL 004 MC-SR 1 A B C D A B C D A B 1: 16 CONDUCT OF OPS 005 MC-SR 1 DA B C DA B C DA 1: 17 EMER PROCEDURES 004 MC-SR I C D A B C D A B C D 1: 18 ESFAS 002 MC-SR 1 B C DA B C D A B C 1- 19 LIQUID RADWASTE 001 MC-SR 1 B C DA B C D A B C 1: 20 CONTAINMENT SPRAY 001 MC-SR 1 D A B C DA B C DA _
1: 21 MAIN FEEDWATER 001 MC-SR I C DA B C DA B C D 1: 22 NUCLEAR INST 003 MC-SR I C DAB C DA B C D 1: 23 REACTOR COOLANT PP 001 MC-SR 1 B C DA B C D AB C 1: 24 NUCLEAR INST 004 MC-SR 1 B C DA B C D A B C 1: 25 AFW 001 MC-SR 1 C D A B C D A B C D 1: 26 AREA RAD MONITOR 001 MC-SR 1 B C DA B C D A B C 1: 27 INCORE TEMP MON 001 MC-SR 1 A B C D A B C DA B 1: 28 CVCS 001 MC-SR 1 B C DA B C D AB C 1: 29 CVCS 002 MC-SR I C DA B C DA B C D 1: 30 DC DISTRIB1TDON 001 MC-SR I C DA B C DA B C D 1: 31 ROD POSITION IND 001 MC-SR 1 D A B C DAB C DA 1: 32 ESFAS 003 MC-SR 1 B C DA B C D AB C 1: 33 REACTOR COOLANT PP 002 MC-SR 1 B C DA B C D A B C 1: 34 WASTE GAS 001 MC-SR 1 A B C D AB C DAB 1: 35 CONTAINMENT COOL 003 MC-SR 1 B C DA B C D A B C 1: 36 CONTAINMENT COOL 002 MC-SR 1 B C DA B C DAB C 1: 37 COND AIR REMOVL 001 MC-SR 1 D A B C DAB C DA 1: 38 H2 RECOMBINER 001 MC-SR I A B C D A B C DAB 1: 39 FUEL llANDLING 001 MC-SR I C DA B C DA B C D 1: 40 SFP COOLING 002 MC-SR 1 D A B C DA B C DA 1: 41 REACTOR COOLANT SYS 001 MC-SR 1 B C DA B C DAB C 1: 42 STAllON AIR 001 MC-SR I C DA B C DA B C D 1: 43 CONTAINMENT SYS 001 MC-SR 1 B C DA B C D A B C 1: 44 STM GENERATOR 002 MC-SR 1 B C DA B C D AB C 1: 45 CIRCULATING WAlliR 001 MC-SR 1 B C DA B C D A B C
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Thursday, March 26,1998 @ 08:18 AM Answer Key Page: 2 Test Name: NRCFINAL.TST Test Date: g g ,)
Question ID Type Pts 0 1 2 3 4 5 6 7 8 9 1: 46 MAIN AND REHEAT STM 001 MC-SR I C DAB CDA B C D 1: 47 SFP COOLING 003 MC-SR 1 B C DA BCD AB C 1: 48 RyCTOR PROJECT 10N 001 MC-SR 1 B CDA B~ C D AB C 1: 49 CONTAINMENT PURGE 002 MC-SR I B C DA B C DA B C 1: 50 AC DISTRIBlJilON 002 MC-SR 1 D A B C DAB C DA 1: 51 PZR LEVEL CONTROL 002 MC-SR I C DAB C DA B CD 1: 52 EMER CORE COOLING 001 MC-SR 1 D AB C DA B C DA 1: 53 EMER DG 002 MC-SR 1 B C DA B CD A B C 1: 54 PZR RELIEF /QT 001 MC-SR 1 D AB C DAB C DA l- 55 SDC 001 MC-SR I C DA B C DA B C D 1: 56 MAIN TURB GEN 001 MC-SR 1 A B C D AB C DA B 1: 57 SERVICE WATER 001 MC-SR 1 C DAB C DA B , CD 1: 58 EMER BORAllON 001 MC-SR 1 B C DA B C D A B C 1: 59 LARGE BREAK LOCA 002 MC-SR 1 B C DA B CD AB C '
1: 60 LARGE BREAK LOCA 001 MC-SR 1 C DA B C DA B C D 1: 61 LOSS NUC SRW(SW) 002 MC SR 1 B C DA BC D ABC l 1: 62 S1M LINE RUPTURE 002 MC-SR 1 B C DA B C D A B C 1: 63 LOSS VITAL AC 002 MC-SR 1 B CDA B CDA B C 1: 64 STM LINE RUPTURE 001 MC-SR 1 B C DA B C D A B C 1: 65 STAT 10N BLACK OUT 001 MC-SR 1 A B C D A B C DA B 1: 66 RCP MALFUNCDON 001 MC-SR 1 C DAB C DA B C D 1: 67 DROPPED ROD 001 MC-SR 1 A B C D A B C DAB 1: 68 LOSS CONTINTEG 001 MC-SR 1 C DAB C DA B C D 1: 69 LOSS VITAL AC 001 MC-SR 1 D ABC DAB C DA 1- 70 LOSS NUC SRW(SW) 001 MC-SR 1 C DAB C DA B C D 1: 71 LOSS OF CCW 001 MC-SR 1 A B C DAB C DAB 1: 72 LOSS OF COND VAC 001 MC-SR 1 B C DA B CD A BC 1: 73 RCS OVERCOOLING 001 MC-SR 1 A B C DABC DAB l- 74 NARTRAL CIRC 001 MC-SR 1 B C DA B C DAB C 1: 75 RCP MALFUNCTION 002 MC-SR 1 B C DA B C D A B C 1: 76 ACCID LIQ RELEASE 001 MC-SR 1 B C DA B C DAB C ;
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1: 77 PLANT FIRE 001 MC-SR 1 A BC DA B C DAB 1: 78. HIRCS ACTIVITY 001 MC-SR I C DAB C DA B C D 1: 79 ATWS 001 MC-SR 1 B C DA B CDA B C 1: 80 HI RCS ACTIVITY 002 MC-SR 1 A B C D A B C DAB 1: 81 INADEQUATE CORE CLG 001 MC-SR 1 A B C DAB C DAB 1: 82 ACCID GAS RELEASE 001 MC-SR I C DAB C DA B CD 1: 83 LOSS OF RHR (SDC) 002 MC-SR 1 A B C DABC DAB 1: 84 LOSS OF RIIR (SDC) 001 MC-SR I B C DA B C D A B C 1: 85 PZR PRESS MALF 001 MC-SR 1 B C DA B C D A B C 1: 86 SMALL BREAK LOCA 002 MC-SR 1 B C DA B CD ABC 1: 87 SMALL EREAK LOCA 001 MC-SR 1 B C DA B CD AB C
'l: 88 LOSS RC M/U 001 MC SR 1 D ABC DAB C DA 1: 89 LOSS SR NIS 001 MC-SR 1 B C DA B C D ABC 1: 90 1SS OF INST AIR 001 MC-SR 1 B C DA B C D A B C ]
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', Thursday, March 26,1998 @ 08:18 AM Answer Key Page: 3 Test Name: NRCFINAL.TST Test Date:
y Answer (s) j Question ID Type Pts 0 1 2 3 4 5 6 7 8 . 9 1: 91 FUNC RECOVERY 001 MC-SR 1 B C DA B CDAB C 1: 92 FUNC RECOVERY 002 MC-SR 1 A B C DAB C DAB 1: 93 RX TRIP STABIL 001 MC-SR ~ l A B CD ABC DAB 1: 94 AREA RAD ALARMS 002 MC-SR 1 D AB C DAB C DA 1: 95 SG TUBE RUPTURE 001 MC-SR 1 A B C D ABC DAB 1: % LOSS OF MTW 001 MC-SR 1 D AB C DAB CDA W - :3>l: 97 RX TRIP STABIL 002 MC-SR 1 A B CD AB C DAB 1: 98 EXCESSIVE RCS LEAK 001 MC-SR I C DAB C DA B C D 1: 99 PZR LEVEL MALF 001 MC-SR 1 D AB C DAB C DA l- 100 LOOP 001 MC-SR 1 B C D A B C D A B C
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