ML052720170
| ML052720170 | |
| Person / Time | |
|---|---|
| Site: | Prairie Island  |
| Issue date: | 08/19/2005 |
| From: | NRC/RGN-III |
| To: | |
| References | |
| Download: ML052720170 (94) | |
Text
NRC Official Use Only Nuclear Regulatory Commission Operator Licensing Examination This document is removed from Official Use Only category on date of examination.
NRC Official Use Only
U.S. Nuclear Regulatory Commission Site-Specific RO Written Examination Applicant Information Name:
Date: August 19, 2005 Facility/Unit: Prairie Island U1/U2 Region: I II III IV Reactor Type: W CE BW GE Start Time: Finish Time:
Instructions Use the answer sheets provided to document your answers. Staple this cover sheet on top of the answer sheets. To pass the examination, you must achieve a final grade of at least 80.00 percent. Examination papers will be collected 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> after the examination begins.
Applicant Certification All work done on this examination is my own. I have neither given nor received aid.
Applicants Signature Results Examination Value 74.0 Points Applicants Score Points Applicants Grade Percent
U.S. Nuclear Regulatory Commission Site-Specific SRO Written Examination Applicant Information Name:
Date: August 19, 2006 Facility/Unit: Prairie Island U1/U2 Region: I II III IV Reactor Type: W CE BW GE Start Time: Finish Time:
Instructions Use the answer sheets provided to document your answers. Staple this cover sheet on top of the answer sheets. To pass the examination you must achieve a final grade of at least 80.00 percent overall, with 70.00 percent or better on the SRO-only items if given in conjunction with the RO exam; SRO-only exams given alone require a final grade of 80.00 percent to pass. You have 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> to complete the combined examination, and 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> if you are only taking the SRO portion.
Applicant Certification All work done on this examination is my own. I have neither given nor received aid.
Applicants Signature Results RO/SRO-Only/Total Examination Values 74.0 / 25.0 / 99.0 Points Applicants Scores / / Points Applicants Grade / / Percent
APPENDIX E POLICIES AND GUIDELINES FOR TAKING NRC EXAMINATIONS Each examinee shall be briefed on the policies and guidelines applicable to the examination category (written, operating, walk-through, and/or simulator test) being administered. The examinees may be briefed individually or as a group. Facility licensees are encouraged to distribute a copy of this appendix to every examinee before the examination begins. All items apply to both initial and requalification examinations, except as noted.
Part A: General Guidelines
- 1. [Read Verbatim] Cheating on any part of the examination will result in a denial of your application and/or action against your license.
- 2. If you have any questions concerning the administration of any part of the examination, do not hesitate to ask them before starting that part of the test.
- 3. SRO applicants will be tested at the level of responsibility of the senior licensed shift position (i.e., shift supervisor, senior shift supervisor, or whatever the title of the position may be).
- 4. You must pass every part of the examination to receive a license or to continue performing license duties. Applicants for an SRO-upgrade license may require remedial training in order to continue their RO duties if the examination reveals deficiencies in the required knowledge and abilities.
- 5. The NRC examiner is not allowed to reveal the results of any part of the examination until they have been reviewed and approved by NRC management. Grades provided by the facility licensee are preliminary until approved by the NRC. You will be informed of the official examination results about 30 days after all the examinations are complete.
Part B: Written Examination Guidelines
- 1. [Read Verbatim] After you complete the examination, sign the statement on the cover sheet indicating that the work is your own and you have not received or given assistance in completing the examination.
- 2. To pass the examination, you must achieve an overall grade of 80.00 percent or greater, with 70.00 percent or greater on the SRO-only items, if applicable. If you only take the SRO portion of the exam (as a retake or with an upgrade waiver of the RO exam), you must achieve an overall grade of 80.00 percent or better to pass. SRO-upgrade applicants who do take the RO portion of the exam and score below 80.00 percent on that part of the exam can still pass overall, but may require remediation.
Grades will not be rounded up to achieve a passing score. Every question is worth one point.
- 3. For an initial examination, the nominal time limit for completing the examination is 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> for the RO exam; 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> for the 25-question, SRO-only exam; 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> for the combined RO/SRO exam; and 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> for the SRO exam limited to fuel handling. Notify the proctor if you need more time.
- 4. You may bring pens, pencils, and calculators into the examination room; however, programable memories must be erased. Use dark pencil to facilitate machine grading.
- 5. Print your name in the blank provided on the examination cover sheet and the answer sheet. You may be asked to provide the examiner with some form of positive identification.
- 6. Mark your answers on the answer sheet provided, and do not leave any question blank.
You may write on the back side of the pages of the written examination. If you are using a machine-gradable form that offers more than four answer choices (e.g., a through e), be careful to mark the correct column.
- 7. If you have any questions concerning the intent or the initial conditions of a question, do not hesitate to ask them before answering the question. Note that questions asked during the examination are taken into consideration during the grading process and when reviewing applicant appeals. Ask questions of the NRC examiner or the designated facility instructor only. A dictionary is available if you need it. When answering a question, do not make assumptions regarding conditions that are not specified in the question unless they occur as a consequence of other conditions that are stated in the question. For example, you should not assume that any alarm has activated unless the question so states or the alarm is expected to activate as a result of the conditions that are stated in the question. Similarly, you should assume that no operator actions have been taken, unless the stem of the question or the answer choices specifically state otherwise. Finally, answer all questions based on actual plant operation, procedures, and references. If you believe that the answer would be different based on simulator operation or training references, you should answer the question based on the actual plant.
- 8. Restroom trips are permitted, but only one applicant at a time will be allowed to leave.
Avoid all contact with anyone outside the examination room to eliminate even the appearance or possibility of cheating.
- 9. When you complete the examination, assemble a package that includes the examination cover sheet and answer sheet, and give it to the NRC examiner or proctor.
Remember to sign the statement on the examination cover sheet indicating that the work is your own and that you have neither given nor received assistance in completing the examination. The examination will be retained by the stations training department.
- 10. After turning in your examination, leave the examination area as defined by the proctor or NRC examiner. If you are found in this area while the examination is still in progress, your license may be denied or revoked.
- 11. Do you have any questions?
REACTOR OPERATOR Page 1 QUESTION: 001 (1.00)
When at 100% power, a series of failures results in a complete loss of Train A DC Power to Unit 1.
When the RO looks at the SI/Reactor Trip Alarm Panel 47017, which annunciator light(s)
(if any) are expected to be LIT?
- a. NO reactor trip OR safety injection annunciator lights are LIT.
- b. ONLY the Turbine Trip/Reactor Trip and Negative Flux Rate reactor trip annunciator lights are LIT.
- c. ALL reactor trip annunciator lights will be LIT, and all safety injection annunciator lights are NOT LIT.
- d. ALL reactor trip AND safety injection annunciator lights are LIT.
QUESTION: 002 (1.00)
Given the following:
- The crew is responding to a stuck open Pressurizer PORV.
- Pressurizer Power Relief Isolation Valve A (MV-32195) control switch is taken to CLOSE.
- One second later, the MV-32195 RED light goes OUT. The GREEN light does NOT come ON.
Which one of the following explains ALL of the above indications?
- a. GREEN control board light bulb is bad.
- b. CLOSED position limit switch failure.
- c. OPEN position limit switch failure.
- d. Thermal overload of the associated breaker.
REACTOR OPERATOR Page 2 QUESTION: 003 (1.00)
Given the following conditions:
- Unit 1 Reactor Trip and Safety Injection due to a Small Break LOCA.
- 1ES-1.1 POST-LOCA COOLDOWN AND DEPRESSURIZATION is in progress.
- The Lead RO is cooling down the RCS at 85°F/hr.
- RCS pressure is 1500 psig and decreasing.
- Containment pressure is 6.8 psig and slowly decreasing.
- 11 RCP has been stopped per 1ES-1.1.
- 12 RCP is running.
- Annunciator 47015-0507 12 RCP BEARING/STATOR HI TEMP is received.
- 12 RCP stator temperature is 252°F and slowly increasing.
What action is required?
- c. Realign 12 Containment Fan Coil Unit to the gap/support positions to reestablish RCP cooling per the 47015-0507 ARP.
- d. Monitor stator temperature and stop 12 RCP if stator temperature reaches 300°F per the 47015-0507 ARP.
REACTOR OPERATOR Page 3 QUESTION: 004 (1.00)
During a Large Break LOCA, all ECCS flow is assumed to bypass the core until the completion of the Blowdown Phase. During the Refill Phase immediately following blowdown, the ECCS flow is directed to the _________.
- a. cold legs AND reactor vessel simultaneously to refill the core from the top and bottom at the same time.
- b. reactor vessel ONLY as complete core uncovery occurs during blowdown and core injection is the most effective cooling method.
- c. cold legs ONLY to refill the core barrel and start the recovery of the core from the bottom up.
- d. cold legs AND hot legs simultaneously to ensure either SI or Accumulator injection will pass through the core on the way to the break.
QUESTION: 005 (1.00)
Given the following:
- Unit 1 is at 100% power for last 42 days.
- 11 Reactor Coolant Pump #1 seal leakoff flow has dropped rapidly from 3.0 GPM to 0.9 GPM.
- 47012-0301 11 RCP STANDPIPE HI LVL is in alarm.
Which of the following has occurred?
- a. #1 Seal Failure
- b. #2 Seal Failure
- c. #3 Seal Failure
- d. #1 Seal Blockage
REACTOR OPERATOR Page 4 QUESTION: 006 (1.00)
Given the following conditions:
- The controlling channel of Pressurizer Pressure failed HIGH.
- Actions of 1C51 INSTRUMENT FAILURE GUIDE are in progress:
- 1HC431K PRZR PRESS MASTER CONTROL is in MANUAL.
- The Pressurizer Pressure Channel Selector Switch is selected to control using another channel.
- Pressurizer Pressure is 2235 psig and is slowly increasing.
- The next step in C51 states: "WHEN pressure returned to normal with no deviation from setpoint, THEN return pressure control to automatic."
- The Pressurizer Pressure Master Controller indicates:
- Deviation of 0
- Output of 10%
- Slide switch in MANUAL Which of the following correctly describes how to return Pressurizer Pressure Control to AUTOMATIC, and will NOT result in a significant pressure transient with no further operator action?
- a. Place the controller in MAN-BAL, verify zero deviation, then place in AUTO.
- b. Place the controller in MAN-BAL and verify a maximum negative deviation.
Increase the output using the manual control knob until the deviation increases to zero, then place in AUTO.
- c. Increase the output to approximately 62% using the manual control knob. Place the controller in MAN-BAL, verify zero deviation, then place in AUTO.
- d. Place the controller in MAN-BAL and verify a maximum negative deviation.
Increase the output to approximately 62% using the manual control knob, then place in AUTO.
REACTOR OPERATOR Page 5 QUESTION: 007 (1.00)
Given the following Unit 2 plant conditions:
- The unit is in Cold Shutdown with the RCS solid.
- RHR flow has been lost and CANNOT be restored.
- Wide Range level in both steam generators is 72%.
- All other systems and components are available.
In accordance with E-4 CORE COOLING FOLLOWING LOSS OF RHR FLOW, which of the following is the PREFERRED method of removing the core's decay heat?
- b. Establish flow from the RWST via an SI pump and allow the Pressurizer PORVs to cycle open and closed at the OPPS setpoint.
REACTOR OPERATOR Page 6 QUESTION: 008 (1.00)
Given the following:
- Unit 1 Reactor Trip and Safety Injection.
- 12 SG has been identified as faulted to containment and has been isolated per 1E-2 FAULTED STEAM GENERATOR ISOLATION.
- 11 SG has been identified as the ruptured SG per 1E-3 STEAM GENERATOR TUBE RUPTURE.
- 1E-3 Step 7a "Determine Required Core Exit Temperature" is in progress.
- The following conditions exist:
- 11 SG pressure is 785 psig.
- 12 SG pressure is 600 psig.
- CETC temperature is 480°F.
- Containment pressure peaked at 6 psig and is now 4.6 psig and stable.
What is the required CETC temperature and action?
- a. 498°F, set both SG PORVs to current SG pressures to maintain RCS temperature constant and continue with steps to depressurize RCS.
- b. 480°F, set 12 SG PORV to current SG pressure to maintain RCS temperature constant and continue with steps to depressurize RCS.
REACTOR OPERATOR Page 7 QUESTION: 009 (1.00)
Given the following:
- Unit 2 Reactor Trip from 55% power on loss of both Main Feedwater Pumps (MFPs).
- Both SG NR levels are offscale LOW.
- 11 SG WR level is 51%, 12 SG WR level is 48%.
- 11 AFW pump is running, 12 AFW pump is OOS.
- AFW flow is 120 gpm to 11 SG, 130 gpm to 12 SG.
- 11 AFW pump discharge pressure is 1100 psig.
- RCS temperature is 542°F and decreasing slowly.
What action will be taken to control AFW flow in 1ES-0.1 REACTOR TRIP RECOVERY and why?
- a. Isolate AFW flow to 11 SG to diagnose if 11 SG is ruptured. Flow to 12 SG may be controlled at any flowrate as 11 SG WR level is adequate to provide a heat sink.
- b. Reduce AFW flow to both SGs as required to maintain AFW pump discharge pressure at or above the current pressure, as maintaining 11 AFW pump running is more important than maintaining AFW flow >200 gpm.
- c. Reduce AFW flow to just over 100 gpm per SG to stop the RCS cooldown while maintaining a heat sink based on AFW flow.
- d. Stop AFW flow to both SGs to stop the RCS cooldown, as SG level in 11 SG is adequate to provide a heat sink.
REACTOR OPERATOR Page 8 QUESTION: 010 (1.00)
Given the following:
- 2ECA-0.0, LOSS OF ALL SAFEGUARDS AC POWER is in progress.
- The RO performing the rapid depressurization of both SGs to 300 psig does not close the SG PORVs when required.
- Pressure in both SGs reaches 180 psig before the depressurization is stopped.
What is the potential operational implication that could result from the excessive SG depressurization?
- a. Nitrogen injection from the accumulators may occur, causing natural circulation flow in the RCS to be interrupted.
- b. Transition to 2FR-P.1 RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK could be required due to the excessive RCS cooldown.
- c. Voiding may occur in the reactor vessel, causing the upper portion of the core to become uncovered and potentially causing core damage.
- d. The TDAFW pump may trip on low discharge pressure due to the low steam supply pressure, resulting in a loss of heat sink.
REACTOR OPERATOR Page 9 QUESTION: 011 (1.00)
All offsite power has been lost and safeguards buses are being supplied by their respective diesel generators.
How can the status of each Pressurizer Backup Heater Bank be determined from the Control Room?
- a. Check for RED light indication on the associated Heater Bank Control Switch; if LIT, the bank is ENERGIZED.
- b. Check for RED light indication on the Bank A and B Heater Bank Control Switches; if LIT, the bank is ENERGIZED. Banks D and E are NOT energized regardless of control switch indication.
- c. Use the ERCS M1.97 display to view the power supplied to Bank A heaters.
Banks B, D and E are NOT energized regardless of control switch indication.
- d. Use the ERCS M1.97 display to view the power supplied to Bank A or Bank B heaters. Banks D and E are NOT energized regardless of control switch indication.
QUESTION: 012 (1.00)
Given the following:
- Unit 1 is at 100% power.
- 12 battery charger shuts down due to an internal failure.
- 12 DC Panel voltage indicates 123.5 VDC.
What control room alarms are expected to be in at this time?
47024-1105 47024-1204 12 DC SYSTEM TROUBLE 12 DC PANEL UNDERVOLTAGE
- a. Actuated Actuated
- b. NOT actuated Actuated
- c. Actuated NOT actuated
- d. NOT actuated NOT actuated
REACTOR OPERATOR Page 10 QUESTION: 013 (1.00)
Given the following:
- Unit 1 is at 100% power, Unit 2 is in MODE 5.
- 21 Cooling Water Pump is OOS.
- Buses 26 and 27 are OOS for bus inspections.
- All CFCUs are on cooling water for chiller repairs.
The following events occur:
- 11 Cooling Water Pump locks out.
- All equipment operates as designed EXCEPT 22 Diesel Driven Cooling Water Pump fails to start automatically or manually.
- Loop A Cooling Water Header Pressure is 75 psig, Loop B 70 psig.
- Loop A Cooling Water Flow is 9,000 gpm, Loop B is 10,000 gpm
- C35 AOP2 LOSS OF PUMPING CAPACITY OR COOLING WATER HEADER WITHOUT SI is in progress.
What action is required and why?
- a. Isolate cooling water flow from Unit 1 and Unit 2 Train B CFCUs to reduce total flow demand on 12 DDCLP to below 17,500 gpm.
- b. Split the cooling water headers by closing at least one valve in the 121 Cooling Water Header (ABCD valves) and either cooling water header crossover valve (MV-32144 or MV-32159) to restore one cooling water loop to OPERABLE pressure.
- c. Manually start 121 Cooling Water Pump as it has failed to start automatically when required.
- d. Trip Unit 1 Reactor and isolate cooling water flow to the Unit 1 turbine building to reduce cooling water flow to below 13,000 gpm.
REACTOR OPERATOR Page 11 QUESTION: 014 (1.00)
Given the following:
- Unit 1 is at 100% power.
- Unit 1 instrument air header pressure is lowering.
- Operators are responding per C34 AOP1 LOSS OF INSTRUMENT AIR.
What condition is expected to be the FIRST to require initiation of a manual reactor trip?
- b. Main Steam Isolation Valves (MSIVs) dual indication from drifting closed.
- c. Lowering Pressurizer level due to all charging pumps failing to minimum speed.
REACTOR OPERATOR Page 12 QUESTION: 015 (1.00)
Given the following:
- Reactor trip and safety injection from 100% power has occurred.
- Actions of 1E-0 REACTOR TRIP AND SAFETY INJECTION have been completed and a transition to 1ECA-1.2 LOCA OUTSIDE CONTAINMENT has been made.
- You are verifying the positions of the RHR Loop Suction Isolation valves per Step 1.
Which of the following correctly describes the expected condition of the Loop A(B) RHR Suction Isolation valves, and what action (if any) must be taken to verify this position?
- a. The two loop side valves (MV-32164 and MV-32230) are labeled "Valve Closed/Breaker Open" and require local verification of valve position. The two RHR side valves (MV-32165 and MV-32231) are closed with power maintained, and verification can be made by the GREEN light lit.
- b. The two loop side valves (MV-32164 and MV-32230) are labeled "Valve Closed/Breaker Open." If further verification is desired, the MCC breakers for the MOVs may be closed to restore light indication. The two RHR side valves (MV-32165 and MV-32231) are closed with power maintained, and verification can be made by the GREEN light lit.
- c. All four isolation valve positions (MV-32164, MV-32165, MV-32230 and MV-32231) may be verified using light indication above their respective control switches with no local actions required.
- d. All four isolation valves (MV-32164, MV-32165, MV-32230 and MV-32231) are labeled "Valve Closed/Breaker Open." The MCCBs associated with the MOVs must be closed and closure attempted with control board switches.
REACTOR OPERATOR Page 13 QUESTION: 016 (1.00)
The crew has just transitioned from 1E-1 LOSS OF REACTOR OR SECONDARY COOLANT to 1FR-H.1 RESPONSE TO LOSS OF SECONDARY HEAT SINK.
1FR-H.1 Step 1 directs a transition to procedure and step in effect (1E-1) IF RCS pressure is less than all intact SG pressures. What is the reason for this transition?
- a. Providing main or auxiliary feedwater to SGs under these conditions may halt natural circulation core cooling.
- b. Core decay heat is being removed by the break flow AND the secondary heat sink is NOT required.
- c. Initiating ANY feed flow under reverse P conditions increase the likelihood of a SG tube rupture.
- d. Auxiliary feedwater flow was isolated based on RCS cooldown and 1FR-H.1 actions to restore are not required.
REACTOR OPERATOR Page 14 QUESTION: 017 (1.00)
Given the following:
- A LOCA has occurred on Unit 1.
- Bus 112 is locked out, deenergizing MCCs 1LA1, 1M1, 1X1, and 1L1.
- Containment pressure has peaked at 48 psig and is now 21 psig and decreasing.
- RWST level is 27% and decreasing.
- Both containment spray pumps are operating.
- 1ECA-1.1 LOSS OF EMERGENCY COOLANT RECIRCULATION is in progress at Step 5.
What actions should be taken with regard to the Containment Spray pumps in Step 5?
- a. Both spray pumps are stopped to preserve RWST inventory.
- b. One spray pump is stopped to preserve RWST inventory. The other should remain operating until containment pressure is below 20 psig, then it should be stopped as the operating CFCUs provide adequate containment heat removal.
- c. One spray pump is stopped to preserve RWST inventory. The other remains operating until RWST level is 8%, then it should be stopped to prevent pump damage.
- d. Both spray pumps remain running as the operating CFCUs do not provide adequate containment heat removal.
REACTOR OPERATOR Page 15 QUESTION: 018 (1.00)
Given the following:
- Both SGs are faulted to containment.
- Actions of 1ECA-2.1 UNCONTROLLED DEPRESSURIZATION OF BOTH STEAM GENERATORS are in progress.
- Secondary pressure boundary isolation is complete.
- The following conditions exist:
- Containment pressure is 35 psig and decreasing.
- RCS temperature is 325°F and rising.
- RCS pressure is 1485 psig and rising.
- Pressurizer level is offscale low.
- 11 SG WR level is 3% and stable, pressure is 35 psig.
- 12 SG WR level is 8% and decreasing, pressure is 80 psig.
- AFW flow to 11 SG is 0 gpm, 12 SG is 50 gpm.
What action MUST the RO take to stabilize the plant?
- c. Increase spray flow or open a PZR PORV to prevent a re-pressurization of the RCS and pressurized thermal shock.
REACTOR OPERATOR Page 16 QUESTION: 019 (1.00)
Given the following conditions:
- Unit 1 is at 50% reactor power and increasing.
- Tavg is 554°F and increasing.
- Tref is 560.5°F and stable.
- Turbine impulse pressure is 260 psig and increasing.
- Turbine control is in IMP OUT.
- Rods are in AUTO and withdrawing.
What event is occurring?
- a. Tref circuit failed high causing a continuous rod withdrawal.
- c. Tavg channel failed low causing a continuous rod withdrawal.
- d. Excess steam demand caused by turbine control valve opening.
QUESTION: 020 (1.00)
A fire is in progress in Zone 19, 715' elevation Auxiliary Building - Unit 1 side.
Unit 1 reactor has been tripped and MSIVs closed per F5 Appendix D IMPACT OF FIRE OUTSIDE CONTROL/RELAY ROOM.
The next step in F5 Appendix D directs opening of MCC breakers 1LA1-B2/1LA2-C2, 1 RCS LP A(B) HOT LEG RHR SPLY (OUTSIDE).
Why are these breakers opened?
- a. The fire may cause a loss of remote closure capability.
- b. To prevent spurious opening of the MOVs due to hot shorts of the control wiring.
- c. To allow manual operation of the valves during the cooldown after the fire is out.
- d. To prevent a loss of RHR suction due to hot shorts of the control wiring.
REACTOR OPERATOR Page 17 QUESTION: 021 (1.00)
The Pressurizer Level Control Selector Switch is in the White-Blue (2-3) position.
Which level channel failure WILL NOT cause letdown to isolate?
- a. White channel failed LOW.
- b. White channel failed HIGH.
- c. Blue channel failed LOW.
- d. Blue channel failed HIGH.
QUESTION: 022 (1.00)
Given the following:
- You are the Unit 1 RO.
- Unit 1 has been tripped and the control room evacuated per 1C1.3 AOP1 SHUTDOWN FROM OUTSIDE THE CONTROL ROOM due to toxic gas.
- You note the following indications at the Hot Shutdown Panel:
- 11 Charging Pump is running and 12 and 13 Charging Pumps are off.
- One letdown orifice is in service.
- 1LI-433 Cold Cal Pressurizer Level indication is 19%.
- Communications have NOT been established with other crew personnel.
What action should be taken from the Hot Shutdown Panel in regard to CVCS operation?
- a. Start additional charging pump(s) as necessary to raise Pressurizer level to 30%.
- b. Verify automatic control is maintaining Pressurizer level stable.
- c. Increase 11 Charging Pump speed to raise Pressurizer level to 21%.
- d. Isolate letdown as automatic isolation has failed to occur when expected.
REACTOR OPERATOR Page 18 QUESTION: 023 (1.00)
Given the following conditions:
- Both SI and both CS pumps are running following a steamline break.
- Both RHR pumps have been stopped.
- Containment pressure is 32 psig and decreasing.
- SI Termination criteria are met and the crew transitions to 1ES-0.2 SI TERMINATION.
What order of actions is directed for stopping pumps and establishing inventory control?
- b. SI pumps are stopped, then charging flow is established, then CS pumps are stopped when containment pressure is less than 20 psig.
- d. Charging flow is established, then SI pumps are stopped, then CS pumps are stopped when containment pressure is less than 20 psig.
REACTOR OPERATOR Page 19 QUESTION: 024 (1.00)
Given the following conditions:
- A small break LOCA has occurred on Unit 1.
- 1ES-1.1 POST-LOCA COOLDOWN AND DEPRESSURIZATION is in progress.
- 11 SI pump is running, 12 SI pump has been stopped.
- Annunciator 47016-0204 11 RWST LO LVL is received and acknowledged by you.
- You note RWST level is 33% and decreasing.
- The SS has been notified of the alarm.
Which one of the following describes the action required by ARP 47016-0204?
- a. Transition to 1ES-1.2 TRANSFER TO RECIRCULATION to ensure core cooling is maintained.
- b. Continue in 1ES-1.1 and stop the second SI pump when directed. Transfer to Recirculation is only required for a Large Break LOCA event.
- c. Initiate a transfer to the Unit 1 RWST from the CVCS Holdup Tanks per C12 to increase level above the alarm setpoint.
- d. Stop 12 SI pump and verify subcooling remains adequate, as pump damage may result from continued operation at this RWST level.
REACTOR OPERATOR Page 20 QUESTION: 025 (1.00)
Given the following:
- 1ECA-3.2 SGTR WITH LOSS OF REACTOR COOLANT: SATURATED RECOVERY is in progress.
- RCS Tave is 552°F and lowering.
- 12 SG is isolated with level 65% NR, rising at 2%/minute.
- Cooldown of the RCS is in progress using the Condenser Steam Dumps from 11 SG.
- A 95°F/hr cooldown rate has been established using steam dump MANUAL control.
- 11 SG steam flow is 0.53x106 lbm/hr.
- Pressurizer level is 30% and rising at 3%/minute.
- NO further operator action is taken.
Which ONE of the following conditions will occur FIRST assuming current trends continue?
- a. 11 MSIV automatically closes.
- b. 12 SG level goes offscale high.
- c. Steam Dump flow is lost.
- d. Pressurizer fills water solid.
REACTOR OPERATOR Page 21 QUESTION: 026 (1.00)
Given the following:
- 1FR-P.1 RESPONSE TO IMMINENT PRESSURIZED THERMAL SHOCK has been entered following a steamline break.
- Both RCPs were tripped during 1E-0 Immediate Actions.
- RCS cold leg cooldown rate was 250°F/hr during the past hour.
- An RCS soak is required.
Which of the following actions is allowed during the soak?
- a. Energizing pressurizer heaters to increase subcooling.
- b. Starting one RCP to equalize loop temperatures and to restore normal pressurizer spray control.
- c. Establishing Auxiliary Spray and operating pressurizer spray and heaters to maintain RCS pressure at or below current pressure.
- d. Initiating an RCS cooldown of less than 50°F/hr and maintaining RCS temperature and pressure within the limits of Figure FRP1-1.
REACTOR OPERATOR Page 22 QUESTION: 027 (1.00)
Given the following plant conditions:
- An earthquake causes a Reactor Trip with loss of power to RCPs.
- 2ES-0.3A NATURAL CIRCULATION COOLDOWN WITH CRDM FANS is in progress.
- A 25°F/hr cooldown rate has been established.
- RCS depressurization has been initiated using pressurizer PORVs.
- RCS voiding is detected by unexpected large changes in pressurizer level.
- The Shift Manager determines CST level is inadequate to support AFW flow for the expected cooldown duration.
Which of the following actions will allow the RCS to be placed on RHR cooling in the SHORTEST POSSIBLE time?
- a. Actuating Safety Injection due to inadequate subcooling and transitioning to 2E-0 REACTOR TRIP OR SAFETY INJECTION.
- b. Increasing steam dump flow to increase the cooldown rate to 100°F/hr, and remain in 2ES-0.3A.
- c. Allowing the RCS to repressurize to collapse the voids, and swapping AFW to cooling water when CST level is lost.
- d. Transitioning to 2ES-0.4 NATURAL CIRCULATION COOLDOWN WITH STEAM VOID IN VESSEL to increase the allowable cooldown rate to 100°F/hr.
QUESTION: 028 (1.00)
Which of the following correctly describes ALL the transformers that can be aligned to supply Unit 2 Reactor Coolant Pumps per 2C20.5 UNIT 2- 4.16KV SYSTEM?
- a. 2M, 2RX, 1R
- b. 2M, 2RX, 1M
- c. 2M, 2RY, 1R, 1M
- d. 2M, 2RY
REACTOR OPERATOR Page 23 QUESTION: 029 (1.00)
Given the following:
- VCT Level Transmitter 1LT-112 is indicating 3% higher than 1LT-141.
- 1LT-141 level decreases to 2%.
The VCT outlet MOV will be ________ and the RWST to Charging MOV will be _________.
- a. open; open
- b. open; closed
- c. closed; open
- d. closed; closed
REACTOR OPERATOR Page 24 QUESTION: 030 (1.00)
Given the following:
- Unit 1 RCS is solid.
- One Reactor Coolant Pump is running.
- Both RHR pumps and heat exchangers are in service with 4000 gpm total RHR flow.
- RHR is in a normal shutdown cooling lineup per 1C1.3 UNIT 1-SHUTDOWN.
- CV-31237 11/12 RHR HX BYPASS FLOW controller setpoint is 66%.
- CV-31235 11 RHR HX RC OUTLET FLOW (1HC-624) setpoint is 60%.
- CV-31236 12 RHR HX RC OUTLET FLOW (1HC-625) setpoint is 60%.
- RCS temperature is 295°F and stable.
12 RHR pump locks out and NO operator actions are taken.
What will be the response of the RCS and why? RCS temperature will...
- a. remain the same, as CV-31237 will throttle CLOSED to reduce total flow to 2000 gpm, resulting in the same flow through the RHR heat exchangers.
- b. increase, as 12 RHR heat exchanger is no longer receiving flow and total heat removal is cut in half.
- c. decrease, as CV-31235 and CV-31236 will throttle OPEN to attempt to maintain total flow at 4000 gpm, resulting in more heat removal.
- d. increase, as CV-31237 will throttle OPEN to attempt to maintain total flow at 4000 gpm, reducing the flow through the RHR heat exchangers.
REACTOR OPERATOR Page 25 QUESTION: 031 (1.00)
Given the following:
- Unit 2 is proceeding to MODE 5 due to repairs to 22 Component Cooling Pump that are expected to take longer than the allowed time by Technical Specifications.
- RCS temperature is 335°F and pressure is 375 psig.
- Engineering analyses to support cross-tying 12 CC pump to Unit 2 CC are expected to take another 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> to complete.
- LCO 3.7.7 COMPONENT COOLING WATER requires the unit to be in MODE 5 in the next 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.
IF RHR is placed in service at this time, what would happen? How can this be prevented?
- a. Train A RHR alone would not have the heat removal capacity to remove decay heat in MODE 4. Place RHR in service now, but maintain steam dump to the condenser to allow reaching Cold Shutdown within the LCO 3.7.7 time limit.
- b. 21 Component Cooling Pump will operate in runout as the procedure requires both RHR HX CC supply and return valves open. Maintain current RCS temperature until a second CC pump is available and notify the SS that LCO 3.7.7 requirements cannot be met.
- c. Boiling would occur in 22 RHR Heat Exchanger. Cool down the RCS below 225°F using steam dump prior to placing RHR in service.
- d. Boiling would occur in 22 RHR Heat Exchanger. Maintain CV-31239 22 RHR HX RC OUTLET FLOW closed using 2HC-625 to stop RHR flow through the heat exchanger.
REACTOR OPERATOR Page 26 QUESTION: 032 (1.00)
Given the following:
- Fuel handling is in progress in the Unit 1 containment and the Spent Fuel Pool.
- Bus 16 is OOS for a bus inspection.
- Alarm 47016-0102 11 RHR PUMP LOCKED OUT is received and the pump breaker is tripped.
- The WIN team and Operators are investigating.
What is the Technical Specification impact (if any) of the above failure?
- b. The required RHR loop is allowed to be OOS for up to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> provided no dilutions of the RCS are allowed.
- c. One hour is allowed to restore an RHR loop to service before fuel handling must be stopped and containment closure initiated.
- d. Fuel handling and any operations that may dilute the RCS must be stopped immediately, and containment closure must be completed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
QUESTION: 033 (1.00)
SP 1032A SAFEGUARDS LOGIC TEST AT POWER- TRAIN A is in progress and annunciator 47018-0305 SAFEGUARD LOGIC TRAIN A TEST is ON.
IF the RO operates a Safety Injection control board switch to the ACTUATE position, what will occur?
- a. No SI actuation or reactor trip will occur on either train.
- b. SI actuation will occur on 'B' train immediately, the reactor will trip, then SI actuation will occur on 'A' train.
- c. SI actuation will occur on 'B' train only, and the reactor will trip.
- d. SI actuation will occur on both trains, and the reactor will trip.
REACTOR OPERATOR Page 27 QUESTION: 034 (1.00)
During the startup of Unit 2 from a refueling outage, the Component Cooling Heat Exchanger Outlet CV travel stops were left in their withdrawn position.
IF a design basis accident occurs on Unit 1, what will be the effect of the travel stop position?
- a. Excessive cooling water flows will result in cavitation of the safeguards Cooling Water Pumps and threaten the ultimate heat sink for decay heat removal.
- b. Cooling water flows to Unit 1 and Unit 2 emergency diesel generators will be reduced below minimum flows to maintain OPERABILITY.
- c. Component Cooling temperatures on Unit 1 will increase above design limits due to the reduced cooling availability in the CCHX, resulting in insufficient heat removal during the injection phase.
- d. Cooling water flows to Unit 1 components such as Containment Fan Coil Units and Diesel Generators may NOT be adequate to support design bases requirements.
REACTOR OPERATOR Page 28 QUESTION: 035 (1.00)
Given the following:
- Unit 2 at 100% power.
- All systems in a normal at-power lineup.
- 2PT-431 (Blue) output fails LOW.
What will be the automatic response (if any) of the Pressurizer Pressure Control System with NO operator action?
- a. Pressurizer heaters in AUTO energize Pressurizer spray goes to minimum Pressurizer pressure increases PORV PCV-430 cycles to maintain pressure below the reactor trip setpoint.
- b. Pressurizer heaters in AUTO energize Pressurizer spray goes to minimum Pressurizer pressure increases PORV PCV-430 and PCV-431C open to prevent pressure from reaching the Pressurizer High Pressure Reactor Trip setpoint.
- c. Pressurizer heaters in AUTO energize Pressurizer spray goes to minimum Pressurizer pressure increases PORV PCV-430 opens but cannot prevent pressure from reaching the Pressurizer High Pressure Reactor Trip setpoint.
- d. Pressurizer pressure remains the same PORV PCV-430 will NOT open on an actual high pressure.
REACTOR OPERATOR Page 29 QUESTION: 036 (1.00)
Given the following:
- Reactor is at 100% power.
- Control Bank D rods are at 218 steps in AUTO.
- AFD is 0.
- Tavg is 560°F.
Which one of the following would REDUCE the margin to Departure from Nucleate Boiling (DNB)?
- a. Auctioneered high Tavg signal fails LOW.
- b. PT-485 First Stage Turbine Impulse Pressure fails LOW.
- c. Rods are manually inserted to 200 steps while diluting to maintain Tavg constant.
- d. Controlling Pressurizer Pressure channel fails LOW.
QUESTION: 037 (1.00)
Given the following:
0145 Reactor trip and safety injection due to Pressurizer Pressure at 1810 psig.
0158 RCS pressure stabilized at 2021 psig.
0202 SI Train A&B reset pushbuttons depressed.
0208 Reactor trip breakers manually closed and immediately tripped back open.
0315 Reactor trip breakers manually closed and remained closed.
At what time did the automatic Safety Injection signals regain the ability to cause an SI?
- a. 0158
- b. 0202
- c. 0208
- d. 0315
REACTOR OPERATOR Page 30 QUESTION: 038 (1.00)
Given the following on Unit 1:
- The Unit was at 100% power.
- A steam line break occurred in Containment.
- The reactor and turbine tripped.
The following conditions are noted:
- Containment pressure is 28 psig and increasing.
- B Train Containment Spray failed to actuate automatically or manually.
What action (if any) is required to prevent exceeding Containment design pressure limits?
- a. Locally start 12 Containment Spray Pump and manually open the discharge valve.
- b. Reset Containment Spray and stop Train A Containment Spray.
- c. Verify all four CFCUs are operating in Slow with full Cooling Water flow.
- d. None, one train of Containment Spray is adequate.
REACTOR OPERATOR Page 31 QUESTION: 039 (1.00)
Given the following on Unit 2:
- Bus 25 and 26 are powered from CT12.
- A Large Break LOCA occurred.
- Containment pressure reached 38 psig.
10 minutes later
- CT 12 transformer locks out.
- D5 and D6 start and load on the Safeguards busses.
What is the response of the Containment Spray System?
Both Containment Spray pumps trip and . . .
- a. lock out. The CS discharge valves fail closed.
- b. the CS discharge valves close. Manual actuation of Containment Spray is required to restore CS flow.
- c. must be manually restarted, and the CS discharge valves reopen.
- d. restart 5 seconds after power is restored, and the CS discharge valves reopen.
REACTOR OPERATOR Page 32 QUESTION: 040 (1.00)
Given the following:
- Unit 1 is at 50% power during a power reduction to turbine offline per 1C1.4 POWER OPERATION.
- Turbine LP steam inlet temperature is 425°F and increasing.
- CS-43082,1 TURB RHTRS MS SPLY CL/HOLD/OP CS is in the HOLD position.
What has occurred, and what action is required in regard to Turbine LP Steam Inlet Temperature?
- a. MSR heating is more effective due to higher supply pressure and lower turbine steam flow. Momentarily place CS-43082 in CLOSE until Turbine LP Steam Inlet temperature is below 400°F. Repeat until closed without exceeding the 100°F/hr cooldown rate or 50°F step change limits.
- b. MSR heating is more effective due to higher supply pressure and lower turbine steam flow. Place CS-43082 to CLOSE. The ramp generator will automatically throttle closed the steam supply valves such that the 100°F/hr cooldown limit is NOT violated.
- c. The MSR Steam Supply Controller has failed to maintain LP steam inlet temperature constant while in the HOLD position as designed. Momentarily place CS-43082 in CLOSE until Turbine LP Steam Inlet temperature is below 400°F.
Repeat until closed without exceeding the 100°F/hr cooldown rate or 50°F step change limits.
- d. The MSR Steam Supply Controller has failed to maintain Turbine LP Steam Inlet Pressure constant while in the HOLD position as designed. Trip the turbine.
The Turbine LP Steam Inlet Temperature is outside allowed operating limits established to prevent blade rubbing and associated turbine damage.
REACTOR OPERATOR Page 33 QUESTION: 041 (1.00)
Given the following conditions:
- The plant is at 8% power.
- Main turbine rollup completed at 1800 rpm.
- Steam Dump Control is in Steam Pressure mode with AUTO setpoint at 1005 psig.
- Main Steam Line Pressure Transmitter PT-484 fails high.
Which action(s) will occur?
- a. The Condenser Steam Dump ONLY opens and will remain open until manual action is taken.
- b. The Condenser Steam Dump ONLY opens but re-closes when RCS temperature decreases to 540°F.
- c. The Condenser and all Atmospheric Steam Dump valves open, but re-close when RCS temperature decreases to 540°F.
- d. The Condenser and all Atmospheric Steam Dump valves open, and pressure continues to decrease until automatic MSIV closure occurs.
REACTOR OPERATOR Page 34 QUESTION: 042 (1.00)
Given the following:
- Unit 1 is at 35% power.
- 11 and 12 Condensate pumps are in service.
- 13 Condensate pump is OOS.
- 11 FW pump is in service, 12 FW pump is off.
11 FW pump lube oil pressure decreases to 4 psig.
What action will occur?
- b. 11 FW pump will immediately trip, causing a turbine trip, which in turn causes a reactor trip.
- c. 11 FW pump will immediately trip, causing a reactor trip, which in turn causes a turbine trip.
QUESTION: 043 (1.00)
Given the following:
- Unit 2 has a design basis Steam Generator Tube Rupture.
- The Reactor has been tripped.
- The Turbine Driven Aux Feed pump is running.
- TDAFW steam from the ruptured Steam Generator has NOT been isolated.
How is the radioactive steam release from the TDAFW pump monitored?
- a. Shield Building Stack radiation monitoring.
- b. Aux Building Stack radiation monitoring.
- c. It is manually calculated based on steam line activity, as direct monitoring is NOT available.
- d. ERCS estimates the release based on steam line activity and flow, as direct monitoring is NOT available.
REACTOR OPERATOR Page 35 QUESTION: 044 (1.00)
Given the following:
- Unit 2 is at 100% with a normal electrical alignment.
- Alarm 47524-0704 BUS SEQUENCER - CHANNEL ALERT is received, shortly followed by 47524:0304, BUS 26 4.16KV DEGRADED VOLTAGE.
- No other annunciators are received.
- CT12 Substation voltage is 3850V.
- Bus 26 voltage is 3820V.
IF Bus 26 Voltage does NOT change, Emergency Diesel Generator D6 will . . .
- a. Start after 60 seconds, then when up to speed and voltage the CT12 source will trip, then the D6 output breaker will close.
- b. NOT start because Bus 26 voltage is still above the D6 auto-start setpoint for Bus 26 voltage.
- c. NOT start because Bus 26 will LOCKOUT due to Undervoltage (27) relaying.
- d. Start and its output breaker will close when the bus is deenergized following the opening of the CT12 source breaker, which occurs after 60 seconds of degraded voltage.
QUESTION: 045 (1.00)
Given the following:
- D1 Diesel generator is being paralleled to Bus 15.
- Incoming volts are 122, running volts 120.
- Synchroscope is rotating slowly in the clockwise direction.
- Synchroscope is approaching the 12 o'clock position.
When the D1 output breaker is closed, D1 will pick up . . .
- a. less than the expected KW load and receive VAR load.
- b. the expected KW load and deliver VAR load.
- c. the expected KW load, and receive VAR load.
- d. NO KW load, and deliver VAR load.
REACTOR OPERATOR Page 36 QUESTION: 046 (1.00)
During a loss of all AC power, 21 Battery is discharging to supply safeguards loads. Additional DC loads are being added to address emergent plant conditions.
With the battery discharging at a higher rate, what is the effect (if any) on remaining battery capacity and why?
- a. Battery capacity will be increased, because the battery operates more efficiently at the higher discharge rate.
- b. Battery capacity will be reduced, because the internal battery resistance combined with higher amp draw will waste more battery capacity as internal heating.
- c. Battery capacity will NOT be affected, because the available power is dependent only on the characteristics of the cells and the number of cells in the battery bank.
- d. Battery capacity will be reduced, as the battery is sized only to provide expected safeguards loading, and any additional loading will result in the battery being fully discharged within the first hour.
REACTOR OPERATOR Page 37 QUESTION: 047 (1.00)
You are performing the test of R-18 WASTE LIQUID DISPOSAL LIQUID EFFLUENT MONITOR in preparation for a release of the 121 ADT Monitor Tank.
What control board alarms are expected, and when are they expected?
When the Operational Selector Switch is taken to CHECK SOURCE...
- a. 47022-0209 RAD MONITOR CHECK SOURCE ACTUATED alarm ONLY is received. When the Operational Selector Switch is taken to PULSE CAL, no alarms are expected.
- b. 47022-0209 RAD MONITOR CHECK SOURCE ACTUATED and 47022-0208, RAD MONITOR DOWNSCALE FAILURE alarms are received. When the Operational Selector Switch is taken to PULSE CAL, 47022-0108 HI RADIATION TRAIN B alarm is received.
- c. 47022-0209 RAD MONITOR CHECK SOURCE ACTUATED and 47022-0107 HI RADIATION TRAIN B alarms are received. When the Operational Selector Switch is taken to PULSE CAL, 47022-0108 HI RADIATION TRAIN B will reflash.
- d. 47022-0209 RAD MONITOR CHECK SOURCE ACTUATED alarm ONLY is received. When the Operational Selector Switch is taken to PULSE CAL, 47022-0108 HI RADIATION TRAIN B is received.
REACTOR OPERATOR Page 38 QUESTION: 048 (1.00)
Given the following:
- A Loss of Offsite Power occurred 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> ago.
- D1, D2, D5 and D6 are powering their respective safeguards buses.
- C47024-1203, D1 EMERGENCY GENERATOR LOCAL ALARM is received in the Control Room.
- The Unit 1 Turbine Building Operator reports the alarm is D1 FUEL OIL LEVEL LOW DAY TANK.
What actions are required?
- a. Close Bus Tie Breakers between Bus 15 and Bus 25 to prevent a power interruption, then trip D1 output breaker and stop D1.
- b. Immediately trip open the D1 output breaker and stop D1 as a loss of fuel oil suction is imminent, and equipment damage could occur.
- c. Transfer Safeguards loads to Train B to ensure no loss of required systems, then open D1 output breaker and stop D1. Restore power to Bus 15 from D5.
- d. Cross connect Unit 2 Fuel Oil Transfer Pumps to D1 Emergency Diesel Generator Day Tank and manually operate as required to maintain level and continue D1 operation.
REACTOR OPERATOR Page 39 QUESTION: 049 (1.00)
Given the following:
- Unit 2 is in Mode 6.
- Fuel Handling is in progress.
- D5 is OOS for 5 year Preventative Maintenance.
- Water is found in the D5/D6 Fuel Oil tanks and D6 is declared INOPERABLE.
What action(s) are required?
- a. Immediately suspend fuel handling and initiate action to restore D6 to Operable status.
- b. Initiate SP-2118 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and restore D6 to Operable within 7 days.
- c. Enter LCO 3.0.3 immediately.
- d. Initiate action to restore D5 or D6 to Operable status within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
REACTOR OPERATOR Page 40 QUESTION: 050 (1.00)
Given the following:
- Both units are at 100% power.
- 122 and 123 Instrument Air Compressors running in PREFERRED.
- 121 Instrument Air Compressor in FIRST STANDBY.
- A pipe break occurs on the outlet of the 123 Instrument Air Receiver.
- Attempts to start 121 Instrument Air Compressor are unsuccessful.
How will the Instrument Air System respond as header pressure decreases, and what effect will this have on the units?
- a. MV-32314 closes to align 122 Instrument Air Compressor to Unit 2. Unit 1 Instrument Air header will be isolated and a reactor trip will be required.
- b. MV-32315 closes. 122 Instrument Air Compressor will supply Unit 1 air header.
Unit 2 Instrument Air pressure will continue to decrease and a reactor trip will be required.
- c. MV-32314 and MV-32315 close. Unit 1 air header will be isolated and a unit trip will result. 122 Instrument Air Compressor will stop after running unloaded. Unit 2 Instrument Air pressure will continue to decrease and a reactor trip will be required.
- d. MV-32314 and MV-32315 close. Service Air header isolation MV-32318 will open to supply Unit 1. 122 Instrument Air Compressor will stop after running unloaded. Unit 2 Instrument Air pressure will continue to decrease and reactor trip will be required.
REACTOR OPERATOR Page 41 QUESTION: 051 (1.00)
Given the following:
- 11 and 21 Cooling Water Pumps are in service.
- 121 Cooling Water Pump is OOS for discharge valve maintenance and is isolated from both cooling water headers.
- 11 Cooling Water Pump trips.
- Loop A cooling Water Pressure indicates 60 psig.
- Loop B cooling water pressure indicates 78 psig.
What automatic action has occurred OR failed to occur, and what action is required?
- a. MV-32144, Loop A/B CLG WTR HDR XOVER VLV A has automatically closed; Manually start 12 or 22 Diesel Cooling Water Pumps and reopen MV-32144.
- b. MV-32034 121 CL WTR HDR VLV A and MV-32035 121 CL WTR HDR VLV B have automatically closed; Manually start 12 Diesel Cooling Water Pump.
- c. 12 Diesel Cooling Water Pump has failed to autostart on low pressure; Manually start 12 Diesel Cooling Water Pump.
- d. 12 and 22 Diesel Cooling Water Pumps have failed to autostart on low pressure; Manually start one Diesel Cooling Water Pump.
QUESTION: 052 (1.00)
What is the power supply to 123 Air Compressor?
- a. 480V MCC 1A2
- b. 480V MCC 2A1
- c. 480V Bus 160
- d. 480V Bus 260
REACTOR OPERATOR Page 42 QUESTION: 053 (1.00)
Which of the following would result in LCO 3.7.3 "Main Feedwater Regulation Valves and MFRV Bypass Valves" being NOT MET if it occurred?
- b. A control card failure that prevents AUTO or MANUAL operation from the Control Room.
QUESTION: 054 (1.00)
You are an extra operator performing a post-LLRT lineup on a containment penetration.
You hear a variable tone siren (wailing, like a police siren) with about a 4-second cycle, but due to noise in the area are unable to hear the announcement that follows.
What has occurred, and what action is required?
- a. Containment Evacuation Alarm. Immediately evacuate containment using the nearest airlock and card out of containment.
- b. Fire Alarm. Complete the valve lineup to ensure the containment penetration is isolated, then exit containment and assist the Fire Brigade or Control Room as directed.
- c. High Flux at Shutdown Alarm. Immediately evacuate containment using the nearest airlock and card out of containment.
- d. Site Evacuation Alarm. Complete the valve lineup to ensure the containment penetration is isolated, then exit containment and report to the North Warehouse.
REACTOR OPERATOR Page 43 QUESTION: 055 (1.00)
Given the following on Unit 1:
1000 hrs 1100 hrs PRT level 72% 78%
PRT temperature 96°F 94°F Pressurizer level 45% 45%
Tavg 570°F 570°F Containment temp 102°F 108°F What is the cause of the PRT level increase?
- a. Expansion due to containment heatup
- b. Pressurizer PORV leakage
- c. Letdown relief valve (inside containment) leakage
- d. Reactor Makeup to PRT leakage QUESTION: 056 (1.00)
Given the following on Unit 1:
- The Unit is in Mode 4.
- Filling the Pressurizer Solid steps are in progress.
- 11 and 12 Charging pumps are running.
- All three Letdown orifices are in service.
- Pressurizer level (Cold Cal) is 78% and increasing slowly.
What action is required when Pressurizer level indicates 80% (Cold Cal)?
- a. Reduce the speed of the operating Charging pumps to maintain RCS pressure constant.
- c. Reduce the operating Charging pump speed until charging and seal injection flow are slightly greater than Letdown flow as solid operation is IMMINENT.
- d. De-energize all Pressurizer heaters as the pressurizer spray line is now submerged and is no longer effective for pressure control.
REACTOR OPERATOR Page 44 QUESTION: 057 (1.00)
The RO is increasing power from 20% to 100% with Control Bank D (CBD) rods currently at 100 steps.
The lift coil fuse for CBD rod C-7 blows.
The RO begins to withdraw rods 2 steps at a time towards 218 steps as power is raised. Which alarm will FIRST alert the operator to the malfunction?
- a. COMPUTER ALARM ROD DEVIATION/SEQUENCING
- b. ROD AT BOTTOM
- c. COMPUTER ALARM DELTA I CHECK TYPER
- d. NIS POWER RANGE LOWER DETECTOR HI FLUX DEVIATION OR AUTO DEFEAT QUESTION: 058 (1.00)
Which NIS channels will be available following a loss of Instrument Bus 112?
- a. Source Range N31, Intermediate Range N35, Power Ranges N41, N43, and N44.
- b. Source Range N32, Intermediate Range N36, Power Ranges N42, N43, and N44.
- c. Source Range N31, Intermediate Range N35, Power Ranges N42, N43, and N44.
- d. Source Range N32, Intermediate Range N36, Power Ranges N41, N43, and N44.
REACTOR OPERATOR Page 45 QUESTION: 059 (1.00)
A short circuit occurs internally on the Master Pressurizer Pressure Controller (HC-431K).
What is the effect of this fault on the Reactor Protection System?
The controller short circuit will...
- a. NOT feed back into the protection circuit due to the use of isolation amplifiers.
- b. feed back into the protection circuit, causing the associated channel to trip.
- c. NOT feed back into the protection circuit since completely separate sensors (pressure transmitters) are used for control and protection.
- d. feed back into the protection circuit, preventing the associated channel from tripping.
REACTOR OPERATOR Page 46 QUESTION: 060 (1.00)
The following exist on Unit 2:
- A LOCA has occurred.
- 2FR-C.1, Response to Inadequate Core Cooling, is in progress
- Containment Hydrogen Concentration is 3% and increasing at 1%/hour.
- 21 Hydrogen Recombiner has been in operation for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
- The Aux Building operator reports Hydrogen Recombiner temperature is 1025°F and stable.
- NO operator action is taken.
What is the expected containment hydrogen concentration in four (4) hours and why?
Assume hydrogen generation rate remains constant and recombiner operation is only means of hydrogen control.
- a. Much less than 7%, as significant hydrogen burns will result from recombiner operation once hydrogen concentration reaches 6%.
- b. Slightly less than 7%, as recombiner efficiency will increase with hydrogen concentration.
- c. 7%, as 21 Recombiner is NOT functioning to remove any hydrogen now and will NOT begin to remove hydrogen as concentration increases.
- d. Slightly more than 7%, as the recombiner will become less efficient at removing hydrogen at higher hydrogen concentrations.
REACTOR OPERATOR Page 47 QUESTION: 061 (1.00)
Given the following:
- Unit 1 is in Mode 6 for a refueling outage.
- Refueling of the reactor core is complete.
- Source Range channel N-31 is INOPERABLE.
What indication is available to the control room operators, and what instrumentation is providing input to the containment "High Flux at Shutdown" alarm?
- a. Indication is provided by SR channel N-32 and IR channels N-35 and N-36.
Alarm function is provided by SR channel N-32.
- b. Indication is provided by Gamma-Metrics channels N-51, N-52, and SR channel N-32. Alarm function is provided by SR channel N-32.
- c. Indication is provided by SR channel N-32, IR channels N-35 and N-36. Alarm function is provided by Gamma-Metrics channels N-51, N-52, and SR channel N-32.
- d. Indication is provided by Gamma-Metrics channels N-51, N-52, and SR channel N-32. Alarm function is provided by Gamma-Metrics channels N-51, N-52, and SR channel N-32.
REACTOR OPERATOR Page 48 QUESTION: 062 (1.00)
Given the following:
- C47511-0101, 21 STM GEN FW/STM FLOW MISMATCH alarm is received
- 21 Steam Generator Water Level is 56% and increasing.
- 22 Steam Generator Water Level is 44% and steady.
- Reactor power is 99.94% and increasing at 1% per minute.
What protective signal will be directly generated if NO action is taken, and what is the action required to prevent the signal?
- a. Reactor trip Take manual control of 21 MFRV at the Control Board and reduce FW flow.
- b. Steam Line Isolation Reduce main turbine load in MANUAL at the EH control panel.
REACTOR OPERATOR Page 49 QUESTION: 063 (1.00)
The following plant conditions exist on Unit 1:
- Unit 1 is in Hot Shutdown with secondary plant startup in progress.
- The Main Air Ejectors are in service.
- One Hogger Air Ejector is operating to assist in drawing a vacuum in the condenser.
- The Ventilation systems are in their normal alignment and operation.
- 1R-15 Condenser Air Ejector Radio Gas Monitor is OOS.
Which of the following describes the relationship between the Condenser Air Removal System and the Process Radiation Monitoring System?
ALL non condensable gases discharged from the Main Air Ejector . . ..
- a. are being monitored by the Auxiliary Building Vent Stack Monitors. The Hogger discharge is unmonitored.
- b. and the Hogger discharge is being monitored by the Auxiliary Building Vent Stack Monitors.
- c. and the Hogger discharge are unmonitored releases.
- d. are being monitored by the Shield Building Vent Stack Monitors. The Hogger discharge is unmonitored.
REACTOR OPERATOR Page 50 QUESTION: 064 (1.00)
Given the following on Unit 1:
- A Steam Generator Tube Rupture occurred 5 days ago.
- The Main Condenser is being drained to the Turbine Building Sump to reduce hotwell level.
- The Turbine Building Compositor is OOS.
What action is required to continue operation of the Turbine Building Sump Pumps?
- a. Pump the Turbine Building Sump directly to the Waste Liquid system for processing and release via 1R-18 WASTE LIQUID DISPOSAL LIQUID EFFLUENT MONITOR.
- b. The Duty Chemist must perform periodic sampling of the Turbine Building Sump prior to and during sump pump operation to estimate the total release.
- c. Line up the Turbine Building Sump Pump discharge to Landlock vice Cooling Water discharge to prevent a release.
- d. The Duty Chemist must sample the hotwell and perform a calculation based on condenser activity to estimate the total release.
REACTOR OPERATOR Page 51 QUESTION: 065 (1.00)
The following conditions exist on Unit 1:
- A valid 1R-23 CONTROL RM AIR SUPPLY MONITOR A alarm occurs and all automatic actions have occurred.
- 1R-24 CONTROL RM AIR SUPPLY MONITOR B has an elevated reading and is in alarm.
- The automatic actions per the ARP for 1R-24 have NOT occurred.
What are the expected RO actions?
- a. Stop the 122 Control Room Chiller and Air Handler, as outside air has NOT been isolated to the system.
- b. Use the Test Jack on 1R-24 to force the actuation of the automatic actions.
- c. Manually bug the 1R-24 detector to force the actuation of the automatic actions.
- d. Manually start the122 Control Room Clean-up Fan as the 1R-23 actuation has isolated outside air.
REACTOR OPERATOR Page 52 QUESTION: 066 (1.00)
Given the following:
- You are an extra RO during a Unit 2 outage.
- You have been assigned to complete SP2269 SI ACCUMULATOR CHECK VALVES REFUELING LEAK TEST.
- Two outplant operators are working under your direction for the test.
- You have verified initial conditions for the test are MET (RCS pressure is between 900 and 1000 psig).
Part of the surveillance involves opening 2SI-20-16 TEST LINE SHUT-OFF UPSTREAM OF 2FI-929, a non-automatic Containment Isolation Valve that is normally locked closed.
When the procedure directs opening of this valve, what action is required?
- a. Direct one operator to maintain constant radio communications with you and be capable of closing 2SI-20-16 within one minute of an accident.
- b. Direct one operator to remain in the vicinity of the valve and be capable of closing 2SI-20-16 within six minutes of an accident announcement.
- c. Notify the Shift Supervisor to declare Containment inoperable per LCO 3.6.1 CONTAINMENT as manual closure can NOT be credited for OPERABILITY.
- d. Notify the Shift Supervisor that an opening has been created, and logging per C19.9 CONTAINMENT BOUNDARY CONTROL DURING COLD SHUTDOWN AND REFUELING SHUTDOWN is required.
REACTOR OPERATOR Page 53 QUESTION: 067 (1.00) QUESTION DELETED FROM EXAM - DO NOT USE The control room has been evacuated per F5 Appendix B CONTROL ROOM EVACUATION-FIRE. You are conducting Attachment D, Unit 2 Reactor Operator Actions.
You have been unsuccessful in contacting the Shift Supervisor at the Hot Shutdown Panel using the radio.
What is the preferred alternate method of communication with the Shift Supervisor at the Hot Shutdown Panel?
- a. Have an extra person (runner) deliver a written message
- b. Sound Powered Telephone on Circuit 1
- c. Gaitronics Page
- d. Telephone QUESTION: 068 (1.00)
During power operation, Technical Specification LCO 3.2.1 requires that the Heat Flux Hot Channel Factor be maintained within the limits set by the Core Operating Limits Report (COLR).
How can the RO be assured that the Heat Flux Hot Channel Factor is being maintained within limits under transient power conditions? The Heat Flux Hot Channel Factor...
- a. is controlled by maintaining the core within the limits of AFD, QPTR and control rod insertion limits.
- b. will cause an alarm if it goes above the COLR limit and the ARP will require operators to reduce power to return it to within limits.
- c. is not directly measurable, but is inferred from the most recent power distribution map using the incore detectors. The acceptance criteria within the surveillance procedure for the flux map being met verifies that it has been within limits since last performance.
- d. is part of the core design performed during the last refueling outage, and is not called into question during the fuel cycle unless a calculation or fuel loading error is discovered.
REACTOR OPERATOR Page 54 QUESTION: 069 (1.00)
Which of the following is an acceptable method to determine if a Temporary Change Notice (TCN) is in effect for a procedure?
- a. Search T-track for the procedure to determine if an action is issued to track the TCN.
- b. Verify the TCN status using the electronic document search feature (Google search) on the LAN.
- c. Refer to a controlled procedure and determine if any TCNs are attached.
- d. Refer to the Control Room or Shift Manager Office TCN file.
QUESTION: 070 (1.00)
Given the following:
- Unit 1 has been operating at full power for 3 months.
- A reactor trip occurs from 80% power during a load reduction for turbine valve testing.
- The Nuclear Engineer calculated an ECC for a reactor startup 15 hours1.736111e-4 days <br />0.00417 hours <br />2.480159e-5 weeks <br />5.7075e-6 months <br /> after the reactor trip.
- The startup was suspended as criticality based on ICRR was predicted below the
+/- 100 step band around the critical rod height with ICRR less than 0.2.
Which of the following could explain the error?
- b. Auxiliary Feedwater flow was reduced just prior to criticality.
- c. The computer code overestimated the amount of xenon reactivity in the core.
- d. Criticality was earlier than the +/- 3 hour3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> band around the expected critical time.
REACTOR OPERATOR Page 55 QUESTION: 071 (1.00)
You are the RO during a shutdown for a refueling outage. The Containment HP requests that Containment In-Service Purge be placed in service "as soon as possible" to reduce dose to workers.
Which of the following is the EARLIEST plant mode reached that will allow for establishment of Containment In-service Purge?
- a. Entry into MODE 3 Hot Standby.
- b. Entry into MODE 4 Hot Shutdown.
- c. Entry into MODE 5 Cold Shutdown.
- d. Entry into MODE 6 Refueling.
QUESTION: 072 (1.00) 11 Steam Generator has known primary to secondary leakage and has been isolated per 1C4 AOP2, STEAM GENERATOR TUBE LEAK.
What action is taken to limit the spread of contamination to the Turbine Building?
- b. Isolating the Turbine Building Sump, then draining the Main Condenser Hotwell to the sump and refilling the Main Condenser Hotwell with clean water.
- c. Realigning the 11 SG Safety Relief Header drains from the Unit 2 Turbine Building sump to the Aerated Sump Tank.
- d. Realigning the 11 SG Safety Relief Header drains from the Unit 2 Condenser to the Unit 2 Turbine Building Sump.
REACTOR OPERATOR Page 56 QUESTION: 073 (1.00)
A unit startup is in progress per 1C1.2 UNIT 1- STARTUP with power stable at 10-8A.
All available instrument air compressors trip. The operators are performing actions in C34 AOP1 LOSS OF INSTRUMENT AIR when a reactor trip occurs.
Which of the following describes the procedure transitions for this event?
- a. C34 AOP1 actions are completed, then 1E-0 REACTOR TRIP OR SAFETY INJECTION is entered and exited when directed to another specific procedure.
- b. 1E-0 REACTOR TRIP OR SAFETY INJECTION is entered and exited when directed to another specific procedure. C34 AOP1 is performed in parallel to aid in plant recovery.
- c. 1E-0 REACTOR TRIP OR SAFETY INJECTION is entered. C34 AOP1 actions are not required to be completed unless specifically directed by the EOPs.
- d. 1E-0 REACTOR TRIP OR SAFETY INJECTION is entered. When the EOP network directs a return to normal operating procedures, C34 AOP1 is re-entered and completed.
QUESTION: 074 (1.00) 1E-3 STEAM GENERATOR TUBE RUPTURE is in progress when you enter the control room as an extra RO.
A depressurization of the RCS using Auxiliary Spray has just commenced.
You note that CV-31328 REGEN HX OUTLET CV is OPEN.
Is this correct and why or why not?
- a. Yes, as the tap for the Auxiliary Spray line is downstream of this valve.
- b. Yes, as the valve should be open to prevent exceeding the T limit between charging flow and the pressurizer steam space.
- c. No, the valve should be closed to maximize the effectiveness of auxiliary spray.
- d. Either position is acceptable as the Auxiliary Spray line taps off upstream of CV-31198 Charging Line Flow Control Valve.
REACTOR OPERATOR Page 57 QUESTION: 075 (1.00)
Given the following:
- The Turbine Building Operator reports a fire on the Unit 1 Hydrogen Seal Oil Skid.
- The local deluge system has actuated.
- 121 Motor Driven Fire Pump has automatically started.
- The Fire Brigade has just been called out.
The Auxiliary Building APEO reports that there is a break on the fire header to the Auxiliary Building sprinklers. You notice fire header pressure is decreasing.
What action should be taken?
- a. Manually start 121 Screenwash Pump and align it to the fire header to maintain fire header pressure, and isolate fire protection to the Auxiliary Building from the control room.
- b. Stop all pumps supplying the Fire Header to reduce damage from flooding in the Auxiliary Building, and inform the Red Wing Fire Department that your fire header is not available.
- c. Stop all pumps supplying the Fire Header to reduce damage from flooding in the Auxiliary Building, and fight the fire using dry chemical extinguishers.
- d. Direct isolation of the fire header to the Auxiliary Building and allow the system to respond automatically to the lowering header pressure.
(********** END OF REACTOR OPERATOR EXAMINATION **********)
SENIOR REACTOR OPERATOR Page 1 QUESTION: 076 (1.00)
Given the following conditions:
- A Large Break LOCA has occurred on Unit 1.
- RCS and Containment pressures are both at 31 psig.
- 11 Component Cooling pump has locked out.
- Bus 16 has locked out.
- Multiple Low CC Flow alarms are received.
- Train A SI, RHR and CS pumps are running.
- Immediate actions of 1E-0 REACTOR TRIP OR SAFETY INJECTION have been completed.
What action is required and why?
- a. Direct entry into C47 Alarm Response Procedures for Low CC Flow alarms received. These will direct tripping of 11 SI Pump and 11 RHR Pump ONLY as they may be damaged within minutes without CC flow.
- b. Enter 1C14 AOP1 "LOSS OF COMPONENT COOLING", which will direct tripping 11 SI pump when SI flow is not required. 11 RHR pump may operate during injection mode without CC, and 11 CS pump can run indefinitely without CC.
- c. Enter 1C14 AOP1 "LOSS OF COMPONENT COOLING", which will not direct any pump trip now as all pumps are needed. 11 SI pump and 11 CS pump are expected to fail within an hour, and local actions may extend this time. 11 RHR pump can operate indefinitely without CC.
- d. Assign an operator to 1E-0 Attachment L, SI ALIGNMENT VERIFICATION, which will direct starting of all Train B ECCS pumps. Once Attachment L is complete, all Train A pumps should be stopped to prevent damage from running without CC.
SENIOR REACTOR OPERATOR Page 2 QUESTION: 077 (1.00)
Given the following conditions on Unit 1:
- Reactor trip and safety injection from 100% power.
- 12 SG has been diagnosed as faulted to containment, and actions of 1E-2 FAULTED STEAM GENERATOR ISOLATION have been completed.
- 1E-1 LOSS OF REACTOR OR SECONDARY COOLANT has just been entered.
- 12 SG is at 35 psig and 2% WR level.
- Steam Dump is controlling RCS temperature at current temperature.
- Radiation monitors 1R-15 CONDENSER AIR EJECTOR alarms at 2550 cps.
What has occurred, and what is the implication of this?
- a. 12 Steam Generator is faulted and ruptured, so primary to secondary leakage cannot be stopped until cold shutdown is reached. Cooldown and SI termination will be done in 1ECA-3.1 SGTR WITH LOSS OF REACTOR COOLANT:
SUBCOOLED RECOVERY.
- b. The insurge of steam to the condenser has caused 1R-15 to alarm from the N-16 gamma radiation expected to be in the steam. Transition to 1E-3 STEAM GENERATOR TUBE RUPTURE is only made if intact SG level increases uncontrollably.
- c. 11 Steam Generator is ruptured, and 12 SG is NOT available for cooldown so primary to secondary leakage cannot be stopped until cold shutdown is reached.
Cooldown and SI termination will be done in 1ECA-3.1 SGTR WITH LOSS OF REACTOR COOLANT: SUBCOOLED RECOVERY.
- d. 11 Steam Generator is ruptured, and if a cooldown is required, 12 SG can be used provided feedwater flow is initiated slowly. Cooldown and SI termination can be done in 1E-3 STEAM GENERATOR TUBE RUPTURE.
SENIOR REACTOR OPERATOR Page 3 QUESTION: 078 (1.00)
Given the following conditions:
- Unit 1 is at 2% power during unit startup.
- The RO has been directed to raise power to 6% in order to place the generator online.
- RED channel Pressurizer Pressure PT-429 fails LOW.
- Actions of 1C51 INSTRUMENT FAILURE GUIDE for PT-429 failure are completed EXCEPT for repair and restoration of PT-429.
What additional Technical Specifications actions OR restrictions (if any) now apply?
- a. Reactor power cannot be raised above 10% until PT-429 is repaired, as it is required for the Low Pressure Reactor Trip LCO 3.3.1.
- c. None, the bistable trips are complete per 1C51, and LCO 3.0.4 allows a mode change if the Required Actions allow operation for an unlimited period of time.
- d. The unit must be placed in MODE 3 in 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and MODE 4 in 18 hours2.083333e-4 days <br />0.005 hours <br />2.97619e-5 weeks <br />6.849e-6 months <br /> per LCO 3.3.2 as the Low Pressure SI channel is INOPERABLE.
SENIOR REACTOR OPERATOR Page 4 QUESTION: 079 (1.00)
Given the following conditions:
- Unit 2 reactor startup is in progress per Appendix C1B REACTOR STARTUP GUIDELINES.
- Reactor power increases uncontrollably to above 106 cps.
- 47017:0103 SOURCE RANGE HI FLUX LVL REACTOR TRIP is LIT.
- The Shift Supervisor directs a manual reactor trip.
- The reactor trip breakers OPEN.
- You are assigned to evaluate current plant conditions for potential emergency classification and reportability.
What are ALL the outside agency/agencies that should be notified and why?
- a. The NRC using PINGP 666 EVENT NOTIFICATION WORKSHEET as a press release will be issued per 5AWI 3.6.4 NOTIFICATIONS REGARDING PLANT MEDIA SENSITIVE EVENTS OR CONDITIONS.
- b. The NRC via the Resident Inspector ONLY as LCO 3.0.3 was entered momentarily due to inoperability of both trains of Reactor Protection, per SWI-O-28 NOTIFICATION OF OPERATIONS MANAGER & RESIDENT INSPECTOR.
- c. The NRC using PINGP 666 EVENT NOTIFICATION WORKSHEET as ALERT conditions were met during the short period of the ATWS. If the ED desires, an NUE based on 'plant conditions warranting increased awareness' can be declared and sent to state and local agencies per F3-2 CLASSIFICATION OF EMERGENCIES.
- d. State and Local agencies using PINGP 577 EMERGENCY NOTIFICATION REPORT FORM as an ALERT must be declared for the ATWS per F3-2 CLASSIFICATION OF EMERGENCIES. The NRC using PINGP 666 EVENT NOTIFICATION WORKSHEET for the emergency class declaration and RPS failure.
SENIOR REACTOR OPERATOR Page 5 QUESTION: 080 (1.00)
Given the following:
- Reactor Physics testing is in progress per D30 POST-REFUELING STARTUP TESTING.
- Both MSIVs are open and steam lines are heated up per 1C1.2 STARTUP OPERATION.
- 47022-0103 AUX BLDG STM EXCLUSION ACTUATED is received.
- 47012-0204 REACTOR COOLANT SYSTEM LO-LO Tavg is received.
- Tavg is 534°F and decreasing.
- Reactor power is 1.8% and increasing.
What action(s) should be directed and why?
- a. Direct manual insertion of control rods per 1C1.2 UNIT 1- STARTUP to turn reactor power, as the unit is about to make a mode change without verification that all prerequisites have been completed.
- b. Direct a manual reactor trip and closure of both MSIVs per F9 HIGH ENERGY LINE BREAK to protect Auxiliary Building personnel.
- c. Direct a manual reactor trip per D30 to comply with LCO 3.1.8 PHYSICS TESTS-EXCEPTIONS- MODE 2 as the reactor is below minimum temperature for criticality, and the LCO requires immediate entry into MODE 3.
- d. Direct closure of both MSIVs per ARP 47012-0204 to stop the temperature transient, and if this is not successful trip the reactor per F9 HIGH ENERGY LINE BREAK.
SENIOR REACTOR OPERATOR Page 6 QUESTION: 081 (1.00)
Given the following:
- Unit 1 Reactor Trip with Loss of Offsite Power from 100% power.
- 1E-0 "Reactor Trip or Safety Injection" is in progress.
- An automatic Safety Injection actuation on Low Pressurizer Pressure occurs
- The following indications are noted:
- Tavg is 554°F and slowly decreasing.
- RCS pressure is 1400 psig and decreasing.
- Pressurizer level is 65% and increasing.
- Both SI pumps are running with flow indicated.
- Containment pressure is 2.3 psig and increasing.
What actions will be taken to address the above conditions?
- a. Manually close the open Pressurizer PORV or close its block valve per 1E-0, then transition to 1ES-0.2 SI TERMINATION when RCS pressure returns to SI pump shutoff head.
- b. Manually close the spray valves or trip both RCPs per 1E-0 to correct the open spray valve(s), then transition to 1ES-0.2 SI TERMINATION when RCS pressure returns to SI pump shutoff head.
Transition to 1E-1 LOSS OF REACTOR OR SECONDARY COOLANT and then 1ES-1.1 POST-LOCA COOLDOWN AND DEPRESSURIZATION to reach MODE 5 Cold Shutdown.
- d. Trip both RCPs per the 1E-0 information page in response to the Small Break LOCA, then transition to 1E-1 LOSS OF REACTOR OR SECONDARY COOLANT and then 1ES-1.1 POST-LOCA COOLDOWN AND DEPRESSURIZATION to reach MODE 5 Cold Shutdown.
SENIOR REACTOR OPERATOR Page 7 QUESTION: 082 (1.00)
Unit 2 is at 100% power and the following log entries have been made:
0700 Received unexpected alarm 47519-0601 CONTAINMENT CONDENSATE HI LEAK RATE.
0705 22 CFCU weir tank drained per C19.3 LEAKAGE WITHIN CONTAINMENT and level immediately returned, 2 gpm leakrate indicated.
0706 Entered C35 AOP4 COOLING WATER LEAKAGE IN CONTAINMENT.
0830 Containment entry team reports 22 CFCU has through-wall leakage from an H-bend on the north face.
0850 22 CFCU cooling water supply and return valves are CLOSED with breakers OPEN per C35 AOP4. Cooling water temperature is 86°F.
0900 2CL-22-4 is throttled OPEN per C35 AOP4. 22 CFCU outlet pressure is 48 psig.
Which of the following correctly states the Technical Specification status of the CFCUs and Containment during the time period above?
- a. Containment was INOPERABLE per LCO 3.6.1 at 0700. Containment Cooling Train B was INOPERABLE per LCO 3.6.5 at 0700. Containment was restored to OPERABLE at 0900. 24 CFCU had sufficient cooling capacity in this configuration to be considered an operable train at 0900, restoring Containment Cooling Train B to OPERABLE at 0900.
- b. Containment was INOPERABLE per LCO 3.6.1 at 0830. Containment Cooling Train B was INOPERABLE per LCO 3.6.5 at 0830. Containment was restored to OPERABLE at 0900. Unit 2 remains in a 7 day required action per LCO 3.6.5 Condition C.
- c. Containment was INOPERABLE per LCO 3.6.1 at 0830. Containment Cooling Train B was INOPERABLE per LCO 3.6.5 at 0850. Containment was restored to OPERABLE at 0900. Unit 2 remains in a 7 day required action per LCO 3.6.5 Condition C.
Containment Cooling Train B was INOPERABLE per LCO 3.6.5 at 0830.
Containment Cooling Train B was OPERABLE at 0850 as 24 CFCU has sufficient cooling capacity in this configuration to be considered an operable train.
SENIOR REACTOR OPERATOR Page 8 QUESTION: 083 (1.00)
Fuel handling is ongoing in the SFP in preparation for an upcoming outage.
When the SFP crane begins to lift an assembly from its storage location, an unusually large number of bubbles are noticed rising from the upper nozzle. The bubbles continue for about 30 seconds.
What has occurred, and what action is required (if any) by the SRO in charge of fuel handling?
- a. Damage to the fuel assembly, lower the assembly back into the storage grid and notify the Unit 1 Shift Supervisor to enter D5.2 AOP1, DAMAGE FUEL ASSEMBLY.
- b. Damage to the fuel assembly, initiate an evacuation of the SFP using D5.1 AOP1, SFP AREA EVACUATION- NON-REFUELING.
- c. Movement has dislodged bubbles on the outside of the assembly, continue fuel handling provided area radiation monitors are not in alarm.
- d. A localized criticality event has caused steam bubbles to form, lower the assembly back into the storage grid then evacuate the SFP per D5.1 AOP1, SFP AREA EVACUATION- NON-REFUELING.
SENIOR REACTOR OPERATOR Page 9 QUESTION: 084 (1.00)
Given the following:
- Unit 2 is at 100% power.
- 21 Steam Generator has a 45 gpd stable tube leak.
- All other equipment is in a normal power alignment.
At 0200 on a Sunday morning, 2R-15 CONDENSER AIR EJECTOR RADIO GAS MONITOR detector fails.
What priority should be assigned to the repair of 2R-15, and what compensatory actions are required?
- a. Priority 1 Work Order (begin immediately and work 24/7 until resolved).
Sample the air ejector and calculate the leak rate every 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> until repaired.
- b. Priority 1 Work Order (begin immediately and work 24/7 until resolved).
Repair 2R-15 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> or Place Unit 2 in MODE 3 HOT STANDBY in the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
- c. Priority 2 Work Order (prepare and conduct work within 3 weeks).
Sample both steam generators and calculate leakage every 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> until repaired.
- d. Priority 3 Work Order (schedule in next Component/System week in Work Week Process).
Sample the air ejector and calculate the leak rate every 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> until repaired.
SENIOR REACTOR OPERATOR Page 10 QUESTION: 085 (1.00)
Given the following:
- Unit 2 Reactor Trip on low pressurizer pressure.
- A LOCA in containment has been diagnosed.
- 2ES-1.1, POST-LOCA COOLDOWN AND DEPRESSURIZATION is in progress.
- 21 SI pump has been stopped per 2ES-1.1.
- Containment pressure is 12 psig and stable.
- Containment radiation is 220 R/hr and rising.
What has occurred and what procedure should be performed in response?
- a. The core is partially uncovered but fuel damage has not occurred, remain in 2ES-1.1 but restart 21 SI pump to restore cooling.
- b. Containment radiation is expected to reach this level in this accident without fuel damage, evacuate the Auxiliary Building of unnecessary personnel per F3-9, EMERGENCY EVACUATION.
- c. Fuel failure has occurred, enter 2FR-C.2, RESPONSE TO DEGRADED CORE COOLING on the ORANGE CSF to restore cooling to the partially uncovered core.
- d. Fuel failure has occurred, enter 2FR-Z.3, RESPONSE TO HIGH CONTAINMENT RADIATION on the YELLOW CSF to start containment cleanup fans.
SENIOR REACTOR OPERATOR Page 11 QUESTION: 086 (1.00)
Given the following:
- A new 11 Mixed Bed Ion Exchanger is being flushed prior to being placed in service.
- VCT level control is being maintained in AUTOMATIC.
- HC-110 BORIC ACID FLOW CONT is in AUTO at 25%.
- An automatic makeup is in progress.
The following then occurs:
- HC-110 controller setpoint fails to 0%.
- Five seconds later, the deviation meter reads 0% and the output meter reads 100%.
What will occur, and what actions are directed by the Shift Supervisor as a result of the above malfunction?
- a. The inadvertent dilution will continue as long as the automatic makeup continues. Stop the makeup and enter C12.5 AOP2 MALFUNCTION OF AUTOMATIC MAKEUP, which will direct performance of manual makeups as necessary per C12.5 CVCS BORON CONCENTRATION CONTROL.
- b. The inadvertent boration will automatically stop when alarm 47015-0403 BORIC ACID FLOW CONTROLLER DEVIATION is received. Alternate between Emergency Borations per C12.5 AOP1 EMERGENCY BORATION OF THE REACTOR COOLANT SYSTEM and manual dilutions per C12.5 CVCS BORON CONCENTRATION CONTROL.
- c. The inadvertent boration will continue as long as the automatic makeup continues. Stop the makeup. Alternate between Emergency Borations per C12.5 AOP1 EMERGENCY BORATION OF THE REACTOR COOLANT SYSTEM and manual dilutions per C12.5 CVCS BORON CONCENTRATION CONTROL.
- d. The inadvertent dilution will automatically stop when alarm 47015-0403 BORIC ACID FLOW CONTROLLER DEVIATION is received. Enter C12.5 AOP2 MALFUNCTION OF AUTOMATIC MAKEUP, which will direct performance of manual makeups as necessary per C12.5 CVCS BORON CONCENTRATION CONTROL.
SENIOR REACTOR OPERATOR Page 12 QUESTION: 087 (1.00)
Given the following:
- Unit 1 is at 80% power.
- Red Channel Tavg Loop 1B failed HIGH at 1400.
- Actions of 1C51.1 have been completed.
- It is now 1930 and you observe the bistable conditions indicated on panels 44178, 44205 and 44179.
What action (if any) is required?
- a. None, the required bistable trips have been completed and allow operation without restriction.
- b. LCO 3.3.2 ESFAS INSTRUMENTATION required actions for Main Feedwater Regulation Valve closure are NOT met. Reduce power to <40% power and close and deactivate both Main Feedwater Regulating Valves within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
- c. LCO 3.3.2 ESFAS INSTRUMENTATION required actions for Main Steamline Isolation are NOT met. Trip the LO LO Tavg MN STM ISOL bistable 1TC-401-D within 30 minutes OR be in MODE 3 by 0200.
- d. LCO 3.3.2 ESFAS INSTRUMENTATION required actions for Main Steamline Isolation are NOT met. Initiate actions to shut down Unit 1 within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />, and be in MODE 3 by 0130.
SENIOR REACTOR OPERATOR Page 13 QUESTION: 088 (1.00)
Given the following:
- Unit 1 is holding power at 15% for an extended period of time following a refueling outage.
- 12 Main Feedwater Regulation Valve (MFRV) is 5% open.
- Per 1C28.2 UNIT 1 FEEDWATER SYSTEM, the RO attempts to close 12 MFRV Bypass valve in MANUAL to reduce erosion of 12 MFRV surfaces.
- 12 MFRV Bypass valve sticks 10% open and cannot be closed.
- You are evaluating the status of LCO 3.6.3 Containment Isolation Valves and LCO 3.7.3 MFRVs and MFRV Bypass Valves.
Which of the following correctly describes the LCOs NOT MET and their Required Actions (if any), and why this completion time is appropriate?
- a. No LCOs are NOT met. Operation of the unit is not restricted.
- b. LCO 3.6.3 is NOT met. Close and deactivate the bypass valve OR isolate flow through the bypass valve within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is acceptable as the valve provides a Containment Isolation function, but feedwater is a closed system within containment.
- c. LCO 3.6.3 and LCO 3.7.3 are NOT met. Reduce power and isolate Main Feedwater flow to 12 SG within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is acceptable as the valve cannot be isolated at power, and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> is sufficient time to perform a controlled power reduction.
- d. LCO 3.7.3 is NOT met. Close and deactivate the bypass valve OR isolate flow through the bypass valve within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> is acceptable as the valve provides a Feedwater Isolation function, but there is a low probability of an event requiring isolation and other valves in the line provide redundancy.
SENIOR REACTOR OPERATOR Page 14 QUESTION: 089 (1.00)
Given the following:
- Unit 1 at 100% power.
- 12 RHR pump is OOS due to a seal leak Alarm 47024-1001 BUS 15 SEQUENCER NOT IN SERVICE alarm is received. Investigation shows a power supply failure that cannot be repaired for 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
The Bus 15 Load Sequencer is declared INOPERABLE and LCO 3.3.4 4KV SAFEGUARDS BUS VOLTAGE INSTRUMENTATION Condition C is entered.
The only operator actions have been to place D1 in PULLOUT and align Bus 15 for block loading per 1C20.7 AOP2, BUS 15 LOAD SEQUENCER NOT IN SERVICE.
Which of the following correctly states the additional Technical Specifications and Required Actions entered as a result of the above?
- a. D1 and all equipment supported by D1 are INOPERABLE per LCO 3.8.1 AC SOURCES- OPERATING, but conditions and required actions for equipment supported by D1 are NOT required to be entered per LCO 3.0.6. However, LCO 3.3.4 requires declaring 11 RHR pump INOPERABLE in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />. This will cause entry into LCO 3.0.3 per LCO 3.5.2 ECCS-OPERATING.
- b. Bus 15 is INOPERABLE per LCO 3.8.9 DISTRIBUTION SYSTEMS-OPERATING, and D1 is INOPERABLE per LCO 3.8.1 AC SOURCES-OPERATING. However, the Conditions and Required Actions are NOT required to be entered per LCO 3.0.6. LCO 3.0.3 will NOT be entered.
- c. D1 and all equipment supported by D1 are INOPERABLE per LCO 3.8.1 AC SOURCES- OPERATING. However, per LCO 3.0.6 the Conditions and Required Actions for supported equipment are NOT required to be entered.
LCO 3.0.3 will NOT be entered.
- d. D1 is INOPERABLE per LCO 3.8.1 AC SOURCES- OPERATING. All equipment supported by D1 are declared INOPERABLE immediately, as OPERABILITY requires normal AND emergency power. LCO 3.0.3 is entered immediately per LCO 3.5.2 ECCS-OPERATING.
SENIOR REACTOR OPERATOR Page 15 QUESTION: 090 (1.00)
Given the following:
- Unit 1 is at 100% power.
- The power supply for the paper motor drive to 1R-11 CNTMT/SHIELD BLDG VENT AIR PARTICLE MONITOR begins to operate intermittently, causing the paper filter to stop and start at erratic intervals.
What alarm(s) will be received, and what actions (if any) are required?
- a. 47022-0309 RAD MONITOR SAMPLING EQUIP PANEL ALARM. No further actions are required, as the intermittent failure of the paper drive will conservatively result in higher 1R-11 readings, and the monitor remains OPERABLE.
- b. 47022-0108 HI RADIATION TRAIN B PANEL ALARM. Declare 1R-11 and 1R-12 INOPERABLE and perform actions per C11 RADIATION MONITORING SYSTEM to isolate the sample inlets and outlets. Per H4 ODCM, no releases may be made via the Shield Building stack until the monitor is repaired.
- c. 47022-0309 RAD MONITOR SAMPLING EQUIP PANEL ALARM and 47022-0108 HI RADIATION TRAIN B PANEL ALARM. Declare 1R-11 INOPERABLE and perform actions per C11 RADIATION MONITORING SYSTEM to maintain Containment Inservice Purge valves CLOSED per LCO 3.3.5 CONTAINMENT VENTILATION ISOLATION INSTRUMENTATION.
- d. 47022-0309 RAD MONITOR SAMPLING EQUIP PANEL ALARM. Declare 1R-11 INOPERABLE and perform actions per C11 RADIATION MONITORING SYSTEM to perform RCS water inventory balance or analyze containment grab samples every 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> per LCO 3.4.16 RCS LEAKAGE DETECTION INSTRUMENTATION.
SENIOR REACTOR OPERATOR Page 16 QUESTION: 091 (1.00)
You are the Fuel Handling SRO during Unit 1 core reload operations.
A twice-burned assembly is being lowered into a core location using the HOIST JOG SWITCH.
The slack cable light and tube down lights are LIT, but the Z-axis/digital readout indexing shows the assembly is 3/4" above the full down position noted for new and once-burned assemblies.
What action should be taken?
- a. Notify the Nuclear Engineer, as the assembly may not be aligned properly with the index pins and may be damaged if not corrected. Release the assembly once full insertion is verified with a submersible camera.
- b. Notify the Nuclear Engineer, as the assembly may have been damaged by contact with an adjacent assembly. Return the fuel assembly to the SFP to allow for a detailed inspection with a submersible camera.
- c. Release the assembly as the light indications are sufficient to verify the assembly is on the bottom. Direct a work request be written to calibrate the Z-axis/digital readout.
- d. Release the assembly as the twice-burned assembly is expected to be elongated by this much due to irradiation, and continue with fuel handling.
SENIOR REACTOR OPERATOR Page 17 QUESTION: 092 (1.00)
Given the following:
- A Small Break LOCA is in progress on Unit 1.
- ERCS failed during the event and is not available.
- You have been assigned to perform manual Critical Safety Function (CSF) status trees.
- When checking the ICCM Thermocouple Page per F-0.2 CORE COOLING, you note the following Core Exit Thermocouple (CETC) readings:
- 5 highest CETCs: E6- 2128°F, I8- 2011°F, F6- 1942°F, D7- 1885°F, H5- 1780°F
- Average of all CETCs: 1162°F
- 5 lowest: C3- 594°F, J3- 599°F, G13- 600°F, E12- 605°F, C3- 619°F
- Subcooling is -20°F.
- RVLIS full range indicates 41%.
What can you determine about the core status, and which procedure will be required to be implemented NEXT for the above conditions?
- a. Some liquid inventory has already been removed from the core and operator action is required to prevent a challenge to core cooling per 1FR-C.2, RESPONSE TO DEGRADED CORE COOLING. No cladding damage is occurring yet.
- b. Most liquid inventory has already been removed from the core and extraordinary operator action is required to prevent core damage from occurring per 1FR-C.1, RESPONSE TO INADEQUATE CORE COOLING. No cladding damage is occurring yet.
- c. Most liquid inventory has already been removed from the core and cladding damage is already occurring in some areas of the core. Extraordinary operator action is required to recover the core per 1FR-C.1, RESPONSE TO INADEQUATE CORE COOLING.
- d. All liquid inventory has been removed from the core and cladding damage is occurring in all areas of the core. Extreme operator action is required to recover the core per 1SACRG-1, SEVERE ACCIDENT CONTROL ROOM GUIDELINE INITIAL RESPONSE.
SENIOR REACTOR OPERATOR Page 18 QUESTION: 093 (1.00)
A planned gaseous radioactive release is to occur on August 1. Which of the following is a disallowed wind direction for making the release AND the reason this wind direction is disallowed? (Wind speed is 5 mph)
- a. From 278 degrees, to prevent gaseous effluents from settling directly into the river.
- b. From 178 degrees, to prevent gaseous effluents from settling on plant buildings due to scrubbing by water vapor from the cooling towers.
- c. From 148 degrees, to prevent gaseous effluents from settling over the nearsite special population (reservation and casino).
- d. From 358 degrees, to prevent gaseous effluents from entering the river by cooling tower scrubbing.
SENIOR REACTOR OPERATOR Page 19 QUESTION: 094 (1.00)
Given the following conditions:
- The Thermal Power Monitoring (TPM) screen shows reactor power has exceeded 100% during the shift.
- You note the following on the TPM screen:
- Last minute average power 99.52%
- Last 5 minute average power 99.52%
- Shift Average power is 100.12%
- Shift Maximum power is 102.11%
- One hour remains before the 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> shift ends on the TPM display.
The RO questions whether the operating license limits for the unit have been or will be violated.
The maximum power limit _______ , and the SS should _______ to maintain compliance with the shift average power limit.
- a. has been met; maintain power at 100% or less
- b. has been exceeded; immediately reduce power to 99.0% or less
- c. has been met; immediately reduce power to 99.0% or less
- d. has been exceeded; maintain current power level or less
SENIOR REACTOR OPERATOR Page 20 QUESTION: 095 (1.00)
Given the following:
- You are the Work Control Center Shift Supervisor.
- A Temporary Change Notice (TCN) has been written to a surveillance procedure to run 21 Safety Injection (SI) Pump with the discharge valve throttled to collect motor data.
- The test is NOT described in current procedures or the Updated Safety Analysis Report.
- The System Engineer has brought the TCN to you for review prior to the scheduled surveillance run this shift.
- The TCN has been OC approved.
The TCN review should...
- b. be signed ONLY if an approved 50.59 screening or evaluation is attached.
- c. be signed ONLY if the duty Shift Supervisor concurs with the change.
- d. NOT be signed under any circumstances.
QUESTION: 096 (1.00)
Unit 2 is being refueled following a complete core offload.
Any deviation from the specified order of the approved Fuel Transfer Log, while transporting fuel to or from the Spent Fuel Pool or the core, requires the approval of ___________ before any changes are made.
- a. Two Nuclear Engineers
- b. Two Senior Reactor Operators
- c. One Nuclear Engineer and One Senior Reactor Operator
- d. the Engineering Shift Outage Coordinator and the Outage Director.
SENIOR REACTOR OPERATOR Page 21 QUESTION: 097 (1.00)
Given the following:
- Procedure C21.3-10.7 RELEASING RADIOACTIVE GAS FROM 127 LOW LEVEL GAS DECAY TANK actions through section 7.6 "Release Procedure" are complete and a release is in progress.
- 127 LLWGDT pressure has been reduced from 90 to 85 psig.
It begins to rain, and rain is expected to continue for about 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
Which of the following actions is required to be directed by the Shift Supervisor?
- a. Continue with the release provided wind conditions remain within allowable limits.
- b. Suspend the release due to the rain per section 7.7 "Suspending a Waste Gas Release." When it stops raining, direct performance of steps in section 7.6 "Release Procedure," provided the release can be completed within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
The release may continue under the previously approved release authorization form.
- c. Terminate the release due to the rain per section 7.8 "Terminating a Waste Gas Release." If it is desired to release the remainder of the tank, attach the release authorization form on the current procedure to a new procedure and repeat the procedure in its entirety.
- d. Terminate the release due to the rain per section 7.8 "Terminating a Waste Gas Release." Prior to releasing gas from the tank again, a new release authorization form must be generated and approved by the Radiation Protection Manager. The release procedure must be performed again in its entirety.
SENIOR REACTOR OPERATOR Page 22 QUESTION: 098 (1.00)
You are the Emergency Director (ED) during a LOCA outside containment.
A worker is critically injured and unconscious in the RHR pit. The Duty Chemist estimates that each of the two proposed rescue team members will receive 30 REM while rescuing the injured person.
Which of the following describes the correct course of action in accordance with F3-11 SEARCH AND RESCUE and F3-12 EMERGENCY EXPOSURE CONTROL?
- a. The ED can authorize only volunteers to rescue the injured person.
- b. The ED can assign personnel to rescue the injured person.
- c. The ED must receive the Plant Manager's permission to exceed the 25 REM dose limit for the volunteer rescuers.
- d. The ED cannot authorize the entry with this expected dose. Direct the rescue team to pursue alternate means of rescue to reduce the dose to the rescuers below 25 REM.
QUESTION: 099 (1.00)
Unit 1 is in Mode 1 when a BOP System Field Contact Power Supply problem results in a loss of ALL of the BOP annunciators. Maintenance estimates 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to repair.
This condition __________ an Emergency Plan EAL threshold and requires __________
monitoring of plant status.
- a. meets; increased
- b. meets; hourly
- c. does NOT meet; increased
- d. does NOT meet; hourly
SENIOR REACTOR OPERATOR Page 23 QUESTION: 100 (1.00)
Given the following:
- 47011-0401 11 STM GEN HI WATER LVL TURBINE TRIP has alarmed.
- PZR level is lowering.
- PZR pressure is lowering.
- All but 5 control rods have rod bottom light indications.
- Reactor power is 7%.
- NO operator actions have been taken.
The Reactor Operators will first enter procedure _____________ and perform Step 1 to verify
____________. These actions are NOT successful in changing the above conditions. When completion of immediate actions is reported, the Shift Supervisor will begin his read-through with Step 1 of procedure ______________.
- a. 1FR-S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS; automatic rod insertion OR manual rod insertion. 1FR-S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS.
- b. 1FR-S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS; the turbine is tripped to prevent an uncontrolled cooldown of the RCS. 1FR-S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS.
- c. 1E-0 REACTOR TRIP OR SAFETY INJECTION; the reactor is tripped. 1E-0 REACTOR TRIP OR SAFETY INJECTION.
- d. 1E-0 REACTOR TRIP OR SAFETY INJECTION; the reactor is tripped. 1FR-S.1 RESPONSE TO NUCLEAR POWER GENERATION/ATWS.
(********** END OF SENIOR REACTOR OPERATOR EXAMINATION **********)
RO/SRO REFERENCES Page 1 ANSWER: 001 (1.00) ANSWER: 005 (1.00) ANSWER: 010 (1.00)
- c. b. a.
REFERENCE:
REFERENCE:
REFERENCE:
Simulator response 1C20.9 1C3 AOP3 section 2.1 ARP 1ECA-0.0 step 21, Caution AOP1 section 2.1 Fig B8-2 47012-0301, 0401 and Bases F-0.4 ARP 47017-0101 (similar for HIGHER MEMORY all RP alarms) X-HIAW-1-39 BANK MODIFIED Westinghouse logic 015 AA1.22 ..(KA's) 055 EK1.02 ..(KA's)
HIGHER NEW 007 EK2.03 ..(KA's) ANSWER: 006 (1.00) ANSWER: 011 (1.00)
- c. c. & d.
REFERENCE:
REFERENCE:
ANSWER: 002 (1.00) 1C51.1 Pressurizer Pressure ERCS M1.97 display Fig
- d. 1P-429-High step 1C C7 B20.6-7b Dwg PZP-026 MCC
REFERENCE:
section 5.1.4 (Tracking Report 1P2, 1R2 SP2265 section 7.2 Control System) MEMORY NF-40780-4 Note green light HIGHER NEW from switch signal 3 (bo) and NEW 056 AA2.17 ..(KA's) red from 7 (ac), indicating 027 2.1.20 ..(KA's) both should be on during valve travel until valve is fully ANSWER: 012 (1.00) open OR closed. ANSWER: 007 (1.00) c.
HIGHER d.
REFERENCE:
MODIFIED
REFERENCE:
ARP 47024-1105, 1204 008 AK2.01 ..(KA's) E-4 flowpath and bases MEMORY MEMORY BANK BANK 058 AK1.01 ..(KA's)
ANSWER: 003 (1.00) 025 AK1.01 ..(KA's) d.
REFERENCE:
ANSWER: 013 (1.00)
ARP 47015-0507 1ES-1.1 ANSWER: 008 (1.00) a.
Information Page b.
REFERENCE:
MEMORY
REFERENCE:
C35 AOP2 NEW 1E-3 step 7 and bases HIGHER 009 EA2.24 ..(KA's) SWI-O-10 step 7.8.4.c NEW HIGHER 062 AA1.07 ..(KA's)
MODIFIED ANSWER: 004 (1.00) 038 2.1.2 ..(KA's)
- a. ANSWER: 014 (1.00)
REFERENCE:
a.
Fig B18A-1, B18A-5 ANSWER: 009 (1.00)
REFERENCE:
MEMORY c. C34 AOP1 Attachment A NEW
REFERENCE:
MEMORY 011 EK3.05 ..(KA's) 1ES-0.1 step 10 RNO, bases BANK 1C28.1 Limitation 4.2 065 AA1.05 ..(KA's)
HIGHER MODIFIED 054 AK3.03 ..(KA's)
RO/SRO REFERENCES Page 2 ANSWER: 015 (1.00) ANSWER: 019 (1.00) ANSWER: 024 (1.00)
- b. a. a.
REFERENCE:
REFERENCE:
REFERENCE:
1C15 (RHR) section 5.7 1C5AOP1 Symptoms Fig ARP 47016-0204 1ES-1.1 "Shutdown and Alignment B5-6, B7-4 SWI-O-0 Att 1 Alarm for ECCS Operation" Fig HIGHER Response B15-01 1ECA-1.2 Step 1 MODIFIED MEMORY MEMORY 001 AK2.06 ..(KA's) MODIFIED NEW E03 2.4.31 ..(KA's)
E04 EA1.1 ..(KAs)
ANSWER: 020 (1.00)
- b. ANSWER: 025 (1.00)
ANSWER: 016 (1.00)
REFERENCE:
c.
- b. 1C15 F5 Appendix D p. 42
REFERENCE:
REFERENCE:
MEMORY ARP 47011-0203 2ECA-3.1, 1FR-H.1 Step 1 and caution, NEW 2ECA-3.2 bases 1E-0 Step 8, 1E-1 067 AK3.04 ..(KA's) HIGHER Step 3 (AFW control steps) MODIFIED MEMORY E07 EA1.1 ..(KAs)
BANK ANSWER: 021 (1.00)
E05 EK2.2 ..(KAs) b.
REFERENCE:
ANSWER: 026 (1.00)
Fig B7-20 c.
ANSWER: 017 (1.00) HIGHER
REFERENCE:
- b. BANK 1FR-P.1 Step 23 and bases
REFERENCE:
028 AK2.02 ..(KA's) MEMORY 1ECA-1.1 step 5 and bases MODIFIED B19 NF-40022-1 Note: E08 EA1.3 Provide copy of 1ECA1.1 ANSWER: 022 (1.00)
Step 5 b.
HIGHER
REFERENCE:
ANSWER: 027 (1.00)
MODIFIED 1C1.3 AOP1 step 2.4.17 d.
E11 EK3.4 ..(KAs) HSD-28
REFERENCE:
MEMORY 2ES-0.3A 2ES-0.4 MODIFIED HIGHER ANSWER: 018 (1.00) 068 AA2.07 ..(KA's) MODIFIED
- a. E10 EK1.1 ..(KAs)
REFERENCE:
1ECA-2.1 and bases ANSWER: 023 (1.00) 1FR-H.5 d. ANSWER: 028 (1.00)
HIGHER
REFERENCE:
a.
MODIFIED 1ES-0.2
REFERENCE:
E12 2.1.2 ..(KA's) HIGHER 2C20.5 Table of Contents Fig BANK B20.5-1 E02 EK1.1 ..(KAs) MEMORY NEW 003 K2.01 ..(KA's)
RO/SRO REFERENCES Page 3 ANSWER: 029 (1.00) ANSWER: 034 (1.00) ANSWER: 038 (1.00)
- b. d. c. & d.
REFERENCE:
REFERENCE:
REFERENCE:
B12A p. 20 Fig B12A-3 C35 precaution 3.2 1C15 Basis TS 3.6.5 HIGHER section 5.8 DBD Component HIGHER NEW Cooling System p. 198 NEW 004 K4.07 ..(KA's) MEMORY 022 A1.02 ..(KA's)
NEW 008 K1.01 ..(KA's)
ANSWER: 030 (1.00) ANSWER: 039 (1.00)
- d. d.
REFERENCE:
ANSWER: 035 (1.00)
REFERENCE:
1C1.3 step 5.8.5 1C15 steps a. B18D 5.1.14, 5.1.36, 5.1.38 B15 p.
REFERENCE:
HIGHER 10 1C51.3 X-HIAW-1-7 RCS NEW HIGHER flow diagram Fig B7-14 Pzr 026 A3.01 ..(KA's)
NEW Pressure Control System 005 K1.09 ..(KA's) HIGHER MODIFIED ANSWER: 040 (1.00) 010 K6.02 ..(KA's) a.
ANSWER: 031 (1.00)
REFERENCE:
- c. 1C1.4 step 5.2.15.C and
REFERENCE:
ANSWER: 036 (1.00) note/caution prior B22A p. 12 2C15 LCO 3.7.7 a. HIGHER HIGHER
REFERENCE:
NEW NEW LCO 3.3.1 Table 3.3.1-1 p 7 039 A3.02 ..(KA's) 006 A1.12 ..(KA's) COLR section 3.3.1 Fig B5-6 Fig B7-14 HIGHER ANSWER: 041 (1.00)
ANSWER: 032 (1.00) BANK c.
- d. 012 K5.01 ..(KA's)
REFERENCE:
REFERENCE:
B7 Fig B7-8 Fig B7-12 LCO 3.9.5 HIGHER HIGHER ANSWER: 037 (1.00) BANK NEW c. 039 K3.06 ..(KA's)
REFERENCE:
006 2.2.22 ..(KA's) 1ES-0.2 step 8 and note Fig B18C top right RTA ANSWER: 042 (1.00) contact in SIR A relay circuit b.
ANSWER: 033 (1.00) to reset auto SI
REFERENCE:
- d. HIGHER B7 B28A 1C1.4 B23
REFERENCE:
MODIFIED HIGHER SP1032A section 8.4 Fig 013 K4.10 ..(KA's) NEW B18C-6 059 K4.02 ..(KA's)
HIGHER MODIFIED 013 K5.02 ..(KA's)
RO/SRO REFERENCES Page 4 ANSWER: 043 (1.00) ANSWER: 048 (1.00) ANSWER: 053 (1.00)
- d. c. c.
REFERENCE:
REFERENCE:
REFERENCE:
B27 NF-39218 B11 B37A C47024-1203 C55300-0303 LCO 3.7.3 1C28.2 AOP1 Fig MEMORY B38B Fig B38B 1C20.5 B7-28 NEW AOP1 MEMORY 061 K1.09 ..(KA's) HIGHER NEW NEW 059 2.2.22 ..(KA's) 064 K6.08 ..(KA's)
ANSWER: 044 (1.00)
- a. ANSWER: 054 (1.00)
REFERENCE:
ANSWER: 049 (1.00) a.
B20.5 C47524-0304 a.
REFERENCE:
C47524-0704
REFERENCE:
NMC Outage Handbook F5 MEMORY LCO 3.8.1 LCO3.8.2 ARP Firefighting section 3.5 BANK C47524-1004 MEMORY 062 K3.02 ..(KA's) MEMORY MODIFIED NEW 103 A2.04 ..(KA's) 064 2.2.22 ..(KA's)
ANSWER: 045 (1.00)
- b. ANSWER: 055 (1.00)
REFERENCE:
ANSWER: 050 (1.00) d.
C20.7 b.
REFERENCE:
HIGHER
REFERENCE:
Tank Book ERCS B4A B12A MODIFIED B34 Fig B34-8 HIGHER 062 A4.03 ..(KA's) HIGHER MODIFIED MODIFIED 007 A3.01 ..(KA's) 078 K3.03 ..(KA's)
ANSWER: 046 (1.00)
- b. ANSWER: 056 (1.00)
REFERENCE:
ANSWER: 051 (1.00) b.
B20.9 section 3.1 SR 3.8.6.6 c.
REFERENCE:
bases p. 3.8.6-10
REFERENCE:
C12 1C1.3 MEMORY B35 C35 AOP2 MEMORY NEW HIGHER NEW 063 A1.01 ..(KA's) NEW 011 2.1.32 ..(KA's) 076 A2.01 ..(KA's)
ANSWER: 047 (1.00) ANSWER: 057 (1.00)
- d. ANSWER: 052 (1.00) a.
REFERENCE:
- b.
REFERENCE:
C47022-0108, 0208, 0209
REFERENCE:
B6 p. 6 ARP C47013-0507, 47048 R-18 ARP C21.1-5.1 B34 0407, 0603, 0303 section 5.4 MEMORY HIGHER MEMORY NEW NEW MODIFIED 078 K2.01 ..(KA's) 014 K4.06 ..(KA's) 073 A4.03 ..(KA's)
RO/SRO REFERENCES Page 5 ANSWER: 058 (1.00) ANSWER: 063 (1.00) ANSWER: 068 (1.00)
- b. a. a.
REFERENCE:
REFERENCE:
REFERENCE:
B9A B26 B11 LCO 3.2.1 and bases, SR MEMORY HIGHER 3.2.1.1 BANK MODIFIED MEMORY 015 K2.01 ..(KA's) 055 K1.06 ..(KA's) BANK 2.1.32 ..(KA's)
ANSWER: 059 (1.00) ANSWER: 064 (1.00)
- a. b. ANSWER: 069 (1.00)
REFERENCE:
REFERENCE:
c.
Fig B7-14 C11 B21B
REFERENCE:
MEMORY MEMORY 5AWI 1.11.2 BANK NEW MEMORY 016 K5.01 ..(KA's) 068 K6.10 ..(KA's) NEW 2.2.11 ..(KA's)
ANSWER: 060 (1.00) ANSWER: 065 (1.00)
- c. d. ANSWER: 070 (1.00)
REFERENCE:
REFERENCE:
c.
C19.8 section 5.2, note at Fig B37B-01 ARP 47047
REFERENCE:
5.2.2 FR-C.1 Step 8 bases R-23 ARP 47048 R-24 B11 C1A Limitation 4.1, 4.4 Fig HIGHER MEMORY C1A-3 App. C1B 3.3 NEW NEW HIGHER 028 K3.01 ..(KA's) 072 A1.01 ..(KA's) NEW 2.2.34 ..(KA's)
ANSWER: 061 (1.00) ANSWER: 066 (1.00)
- b. a. ANSWER: 071 (1.00)
REFERENCE:
REFERENCE:
c.
B9A B9B Tech Spec Basis SP 2269 sections 3.0, 6.0
REFERENCE:
3.9.3 2C1.2 Appendix D TS 3.6.1, 1C19.2 Fig B19-9 C1.1.19-1 HIGHER 3.6.3, 3.7.2 and bases penetration 42B, 43A BANK MEMORY MEMORY 034 A4.02 ..(KA's) NEW NEW 2.1.8 ..(KA's) 2.3.9 ..(KA's)
ANSWER: 062 (1.00)
- c. ANSWER: 067 (1.00) ANSWER: 072 (1.00)
REFERENCE:
deleted c.
C47511-0101 2C28.2 AOP1
REFERENCE:
REFERENCE:
Fig. B18C-4 Fig B18C-3 F5 App B C4 AOP2 Attachment A, B HIGHER MEMORY MEMORY NEW MODIFIED NEW 035 A2.04 ..(KA's) 2.1.16 ..(KA's) 2.3.11 ..(KA's)
RO/SRO REFERENCES Page 6 ANSWER: 073 (1.00) ANSWER: 078 (1.00) ANSWER: 083 (1.00)
- b. c. b.
REFERENCE:
REFERENCE:
REFERENCE:
C34 AOP1 step 2.4.1 1E-0 LCO 3.0.4, 3.3.1, 3.3.2 D5.2 AOP1 Symptoms, entry procedure HIGHER Immediate Manual Actions MEMORY NEW MEMORY BANK 027 AA2.16 ..(KA's) NEW 2.4.5 ..(KA's) 036 AA2.02 ..(KA's)
ANSWER: 079 (1.00)
ANSWER: 074 (1.00) c. ANSWER: 084 (1.00)
- c.
REFERENCE:
a.
REFERENCE:
F3-2 section 5.5, Condition
REFERENCE:
1E-3 and basis 12K SWI-O-28 2C4 AOP2 5AWI 15.1.1 MEMORY HIGHER section 6.4 5AWI 15.0.2 NEW NEW Table 3 2.4.20 ..(KA's) MEMORY 029 2.4.30 ..(KA's) NEW 037 2.1.2 ..(KA's)
ANSWER: 075 (1.00)
- d. ANSWER: 080 (1.00)
REFERENCE:
- b. ANSWER: 085 (1.00)
ARP C47022-0611 B31A
REFERENCE:
d.
C31 ARP 47022-0103,
REFERENCE:
HIGHER 47012-0204 LCO 3.1.8 F9 2FR-Z.3 2ES-1.1 Information NEW steps 2.4.1, 2.4.5 Page F-0.2, F-0.5 CSF status 2.4.27 ..(KA's) HIGHER trees NEW HIGHER 040 2.4.49 ..(KA's) NEW ANSWER: 076 (1.00) E16 2.4.4 ..(KA's) b.
REFERENCE:
ANSWER: 081 (1.00) 1C14 AOP1 Table 1 p. 9-10 a. ANSWER: 086 (1.00)
HIGHER
REFERENCE:
a.
MODIFIED 1E-0 and bases
REFERENCE:
026 AA2.06 ..(KA's) HIGHER ARP 47015-0403 C12.5 NEW AOP2 section 2.4.3 C12.5 008 AA2.01 ..(KA's) section 5.5 ANSWER: 077 (1.00) HIGHER
- d. NEW
REFERENCE:
ANSWER: 082 (1.00) 004 A2.06 ..(KA's)
E-3 Step 7, bases E-1 b.
Information Page- E-3
REFERENCE:
transition criteria E-2 LCO 3.6.1 and bases, 3.6.5 1FR-H.5 step 4 guidance for C35 AOP4 NF-39217-2, 3 establishing flow to dry SG HIGHER HIGHER NEW NEW 038 EA2.02 ..(KA's) 069 AA2.01 ..(KA's)
RO/SRO REFERENCES Page 7 ANSWER: 087 (1.00) ANSWER: 091 (1.00) ANSWER: 096 (1.00)
- c. a. c.
REFERENCE:
REFERENCE:
REFERENCE:
LCO 3.3.2, Table 3.3.2-1 C17 D5.2 Section 5.1.2 LCO 3.3.1, Table 3.3.1-1 MEMORY MEMORY HIGHER NEW BANK NEW 034 A2.03 ..(KA's) 2.2.31 ..(KA's) 013 2.1.33 ..(KA's)
ANSWER: 092 (1.00) ANSWER: 097 (1.00)
- c. b.
ANSWER: 088 (1.00)
REFERENCE:
REFERENCE:
REFERENCE:
HIGHER Special Consideration 5.1-5.3 LCO 3.7.3 and bases B.1 NEW and Note Step 7.6.1, 7.6.4 and B.2 017 A2.02 ..(KA's) and 7.6.11 MEMORY MEMORY NEW NEW ANSWER: 093 (1.00) 2.3.8 ..(KA's) 059 2.2.22 ..(KA's) d.
REFERENCE:
ODCM H4 3.7.3, p. 73 TS ANSWER: 098 (1.00)
ANSWER: 089 (1.00) 5.5.1 Note: Provide copy of a.
- a. Fig B25-1
REFERENCE:
REFERENCE:
MEMORY F3-12 section 8.0 F3-11 LCO 3.0.3, 3.0.6, 3.5.2, BANK 3.6.3, 3.6.4 3.8.1, 3.8.9 5AWI 3. Note: MEMORY Provide a copy of LCO 3.3.4 071 2.2.22 ..(KA's) BANK HIGHER 2.3.10 ..(KA's)
NEW 062 2.4.31 ..(KA's) ANSWER: 094 (1.00)
- b. ANSWER: 099 (1.00)
REFERENCE:
c.
ANSWER: 090 (1.00) SWI-O-50 section 6.8 Prairie
REFERENCE:
- d. Island Unit 1 Operating C47.0 AOP1 2.4.1.A,
REFERENCE:
License Section (C)1 2.4.1.F.2, 2.4.2 F3-2 EAL C11 section 6.3 ARP HIGHER 12B 47022-0309 3.A LCO 3.3.5, BANK MEMORY 3.4.16 and bases 2.1.10 ..(KA's) MODIFIED HIGHER 2.4.32 ..(KA's)
NEW 073 A2.01 ..(KA's) ANSWER: 095 (1.00) b.
REFERENCE:
5AWI 3.3.5 App B #22 PINGP 436 1300 (TCN)
MEMORY BANK 2.2.8 ..(KA's)
RO/SRO REFERENCES Page 8 ANSWER: 100 (1.00) d.
REFERENCE:
E-0 and FR-S.1 Entry Conditions, Steps 1-2 SWI-O-10 7.8.4.a.1, 7.8.4.f.1 HIGHER MODIFIED 2.4.1 ..(KA's)
(********** END OF RO/SRO REFERENCES ********** )
RO/SRO REFERENCES Page 9 RO/SRO A N S W E R K E Y MULTIPLE CHOICE 001 c 021 b 041 c 061 b 081 a 002 d 022 b 042 b 062 c 082 b 003 d 023 d 043 d 063 a 083 b 004 a 024 a 044 a 064 b 084 a 005 b 025 c 045 b 065 d 085 d 006 c 026 c 046 b 066 a 086 a 007 d 027 d 047 d 067 deleted 087 c 008 b 028 a 048 c 068 a 088 d 009 c 029 b 049 a 069 c 089 a 010 a 030 d 050 b 070 c 090 d 011 c & d 031 c 051 c 071 c 091 a 012 c 032 d 052 b 072 c 092 c 013 a 033 d 053 c 073 b 093 d 014 a 034 d 054 a 074 c 094 b 015 b 035 a 055 d 075 d 095 b 016 b 036 a 056 b 076 b 096 c 017 b 037 c 057 a 077 d 097 b 018 a 038 c & d 058 b 078 c 098 a 019 a 039 d 059 a 079 c 099 c 020 b 040 a 060 c 080 b 100 d
(********** END OF RO/SRO ANSWER KEY ********** )