Admin Study

7. Unit 1 is in MODE 3 and Unit 2 is in MODE 1. What is the minimum allowable staffing of the control room (SM, SRO, RO, STA) per ODA-102? [Ref: ODA-102]

1 SM, 4 RO, 3 US with one of the US being STA qualified; may also be met by 1 SM, 4 RO, 2 US and a separate STA qualified individual

69. How does a TM differ from a DM? [Ref: STA-602]

A temporary modification is a temporary and reversible change to plant systems, components or structures needed for short durations, to support plant operation or outages. These changes typically involve intrusive or intimate contact with systems, structures or components which are considered operable and not covered by another process control. Design modifications are typically permanent changes to the facility or systems.

88. What are some of the conditions and limitations of the facility license and where are they found? [10CFR50.54]

10CFR50.54, "Conditions of Licenses" lists about 30 items. These conditions apply to the company's license to operate Comanche Peak. As holder of an "Operator's License," you will share responsibility, and in some cases carry sole responsibility, for ensuring compliance with these conditions. Items of particular importance to operators are paraphrased below: a) 50.54 (a) The quality assurance program described in the FSAR shall be implemented. The quality assurance program describes requirements for operation of the facility, including design control, quality document control (prints, procedures), tracking of parts and maintenance, procedures for welding and non-destructive examination, record keeping and component inspections. b) 50.54 (f) The licensee must provide information to the NRC when requested. c) 50.54 (h) The facility is subject to rules established by the NRC. d) 50.54 (i) With exceptions, operation of the controls by anyone who is not RO or SRO licensed is not allowed e) 50.54 (i-1) The licensee must maintain an operator requalification program. f) 50.54 (j) A RO or SRO must approve the manipulation of any apparatus which may affect reactivity or power level. g) 50.54 (k) A licensed operator shall be present at the controls at all times during operation. h) 50.54 (m) Minimum licensed operating staffing requirements i) 50.54 (m) An SRO must be present (not same person for each bullet): • responsible for overall plant operation (command function), • in control room at all times in MODES 1-4 • to directly supervise fuel handling j) 50.54 (q) The licensee must maintain the E-plan. k) 50.54 (x) "A licensee may take reasonable action that departs from a license condition or a technical specification (contained in a license issued under this part) in an emergency when this action is immediately needed to protect the public health and safety and no action consistent with license conditions and technical specifications that can provide adequate or equivalent protection is immediately apparent." l) 50.54 (y) "Licensee action permitted in paragraph (x) of this section shall be approved, as a minimum, by a licensed senior operator prior to taking the action."

57. What regulation allows us to: a. make changes to the facility which are described in the FSAR b. make changes to the procedures which are described in the FSAR c. conduct tests which are not described in the FSAR? d. What restrictions does the regulation impose? [Ref: 10CFR50.59]

10CFR50.59, "Changes, tests and experiments." The text of the regulation follows: (c)(1) A licensee may make changes in the facility as described in the final safety analysis report (as updated), make changes in the procedures as described in the final safety analysis report (as updated), and conduct tests or experiments not described in the final safety analysis report (as updated) without obtaining a license amendment pursuant to Sec. 50.90 only if: (i) A change to the technical specifications incorporated in the license is not required, and (ii) The change, test, or experiment does not meet any of the criteria in paragraph(c)(2) of this section. (2) A licensee shall obtain a license amendment pursuant to Sec. 50.90 prior to implementing a proposed change, test, or experiment if the change, test, or experiment would: (i) Result in more than a minimal increase in the frequency of occurrence of an accident previously evaluated in the final safety analysis report (as updated); (ii) Result in more than a minimal increase in the likelihood of occurrence of a malfunction of a structure, system, or component (SSC) important to safety previously evaluated in the final safety analysis report (as updated); (iii) Result in more than a minimal increase in the consequences of an accident previously evaluated in the final safety analysis report (as updated); (iv) Result in more than a minimal increase in the consequences of a malfunction of an SSC important to safety previously evaluated in the final safety analysis report (as updated); (v) Create a possibility for an accident of a different type than any previously evaluated in the final safety analysis report (as updated); (vi) Create a possibility for a malfunction of an SSC important to safety with a different result than any previously evaluated in the final safety analysis report (as updated); (vii) Result in a design basis limit for a fission product barrier as described in the FSAR (as updated) being exceeded or altered; or (viii) Result in a departure from a method of evaluation described in the FSAR (as updated) used in establishing the design bases or in the safety analyses.

14. Describe the difference between shift and standing orders. [Ref: ODA-106]

A Shift Order is used by Operations Management to describe work to be accomplished by the shift personnel during the shift and information to be passed on to their reliefs. A Standing Order is used by Operations Management describing work surveillances, tests or administrative actions to be accomplished on a repetitive or long-term basis.

95. How can an inoperable annunciator that cannot be deactivated or cleared be visually identified in the Control Room? How is an annunciator that has leads lifted or jumpers installed on the field inputs thus modifying the alarm function visually identified in the Control Room? [Ref: ODA-401]

A colored dot is placed on nuisance annunciators that cannot be cleared or on annunciators that have their field input modified by lifting leads or installing jumpers.

64. How are temporary changes to procedures controlled? [Ref: STA-202]

A copy of the temporary change to the procedure is placed in the in-process procedure (controlled copy, working copy). The original is routed to the responsible manager for final review and approval within 14 calendar days of the interim approval.

36. What should be done if a component is discovered out of position during the performance of an independent verification? [Ref: STA-694]

Actions to be taken: • The responsible supervisor should be immediately contacted for resolution. • The component should NOT be repositioned without responsible supervisor permission. Exceptions to this requirement may be made when a mispositioned valve is causing an obvious problem such as leaking water on the floor. • The responsible supervisor should take corrective action and initiate a CR, if required.

96. You are an adult male unescorted radiation worker and have received a cumulative Total Effective Dose Equivalent of 900 mrem so far this year. If today's date is February 12th, and you need to perform additional work in radiation areas, how much more dose can you receive? [Ref: STA-655]

Additional dose allowed - 1100 mrem TEDE. The annual administrative exposure limit is 2 rem (2000 mrem) TEDE. The NRC exposure limit is less restrictive at 5000 mrem TEDE annually.

43. What are the Fuel Handling SRO's responsibilities when CORE ALTERATIONS are in progress? [Ref: RFO-102]

All CORE ALTERATIONS shall be observed and directly supervised by either an active licensed SRO or SRO Limited to Fuel Handling who has no other concurrent responsibilities during this operation.

51. Refueling is in progress when a control power fuse for N-32 blows. What action is required? [Ref: ABN-701]

All core alterations and positive reactivity additions must be suspended.

75. Under what circumstances are Work Group Supervisors allowed to authorize work activities? [Ref: STI-606.01]

An RWO Supervisor may authorize (with the exception of Security equipment) Minor Work, SMAs and Work Orders that: a) Do not cause alarms AND do not impact plant operations or equipment OR; b) Are specifically permitted by Shift Operations per Attachment 8.A OR; c) Meet the guidelines for Minor Work OR; d) Are designated as Control Room Contact NOT Required in Maximo.

32. When is an Observer Safety Person required for electrical work? What is the Observer Safety Person's responsibility? [Ref: STA-124]

An observer safety person is required when working on an exposed live part with a nominal voltage rating of greater than 1000 volts. (e.g., Live-Dead-Live verification on 6.9 kV switchgear). The Observer Safety Person is a worker who is currently qualified in first aid and CPR and whose only responsibility is to observe the electrical work and warn workers of near contact with an exposed live part. The observer safety person should not be distracted from his duties. Additional responsibilities are: • Present prior to the start of the job, • Ensure rescue equipment is available, • Don appropriate PPE and FPE to facilitate rescue, • Give worker being observed your complete attention, • Initiate emergency notification and life saving actions. • When working in remote locations outside the normal response time of the first responders, the assigned observer safety person should ensure that appropriate rescue equipment and de-fibrillator are available prior to work beginning. • The observer safety person should ensure that a method of communicating with the control room or county emergency services is available and working.

40. RCS dissolved oxygen is determined to be 150 ppb following addition of lithium while operating at power. What action(s) must be taken? [Ref: STA-609, Technical Requirements Manual]

Perform Action Level 2 requirements of STA-609. Restore RCS dissolved oxygen to within Technical Requirements Manual steady state limit of < 0.10 ppm within next 24 hours.

48. Refueling is in progress when an earthquake occurs. What should you do? [Ref: ABN-907]

Perform the following: • Place fuel assembly(s) in a safe position. • IF Transfer Cart is in Containment side of transfer canal, THEN move it to the Fuel Building side. • Close/verify closed the Fuel Transfer Tube Gate Valve. • Suspend all fuel handling activities.

24. Who has authority to operate high voltage switches where human life is in jeopardy or failure of equipment justifies operation of switches? [Ref: STA-617]

Any responsible employee of Luminant may operate the required switches to prevent further damage. The Controller shall be contacted as soon as possible and informed of the circumstances and action taken.

80. Define the following terms: [Ref: ODA-308] a. Tracking LCOAR b. Outage LCOAR c. Active LCOAR d. Electronic Standard LCOAR

As follows: a) Tracking LCOAR - A LCOAR written on TS related equipment or parameters in which the LCO is impacted by an off-normal or impaired condition BUT entry into the related TS Required Action(s) is NOT required. b) Outage LCOAR - A LCOAR written on TS related equipment which is not applicable in the present MODE. The LCOAR provides a method for tracking plant configuration and degraded conditions during an outage in MODES 3, 4, 5 or 6. c) Active LCOAR - LCOARs which apply to the present plant MODE or plant conditions in which the plant is operating within a Limiting Condition for Operation (LCO) Action. d) Electronic Standard LCOAR - An electronic format which prescribes the Conditions, Required Actions, and Completion Times for TS controls, and related CPSES administrative information and requirements. Documentation that supports tracking of LCO compliance, such as special condition tracking, may be detailed and provided.

89. Identify which of the following situations below places the unit in a one hour or less Technical Specification or Technical Requirements Manual Action requirement. List the required action if any exist. Evaluate each situation independently. a. The combination of thermal power, reactor coolant system highest loop average temperature and pressurizer pressure has exceeded the limits of Reactor Core Safety Limits Figure 1 of the COLR while the unit is in MODE 1. b. RCS pressure exceeds 2735 psig while the unit is in MODE 3. c. The Bank D control rods are inserted below the insertion limit during a turbine runback from 100% power. d. Tavg drops below 551°F, in one loop, during a secondary transient at the beginning of a cycle. e. The Train A Emergency Diesel is declared inoperable while in MODE 5 with the Train A CCP as the only operable charging pump. Train B Emergency Diesel remains operable. f. Both CCPs are declared inoperable while in MODE 3. The PDP is still operable. g. During surveillance testing in MODE 1 one control rod becomes misaligned >12 steps from its group. The apparent cause is an electrical malfunction, which was repaired. h. The unit is stable in MODE 1 when the digital rod position indication for one rod in Control Bank C is lost. i. The unit is stable in MODE 3 with all shutdown bank rods fully withdrawn in preparation for a reactor startup when the digital rod position indication for one rod in Shutdown Bank A is lost. j. Main Steam Line Pressure Transmitter PT-515 fails high with the unit stable at 75% reactor power. k. First Stage Pressure Transmitter PT-505 fails low with the unit stable at 75% reactor power. l. Pressurizer Pressure Transmitter PT-458 fails low with the unit stable at 75% reactor power. m. RHR Train A is in operation in MODE 5 with loops not filled and Train B RHR is in standby when the Train B RHR Pump is declared inoperable. n. One of the three pressurizer safety valves is declared inoperable in MODE 1 after a review of maintenance records reveals that an incorrect part is installed in the valve. o. At EOL, one of the twenty main steam line safety valves is declared inoperable in MODE 1 after a review of maintenance records reveals that an incorrect part is installed in the valve. p. Specific activity of the secondary exceeds 0.1 μCi/gm DOSE EQUIVALENT I-131 in MODE 1. q. The Train A Emergency Diesel is declared inoperable in MODE 1. r. Bus 1PC1 de-energizes due to a fault in MODE 1. s. An outage progresses in record time. Fuel movement is begun 3 days after reactor shutdown. [Ref: Technical Specifications, Technical Requirements Manual]

As follows: a) Yes. TS 2.1.1. Restore and be in Mode 3 within 1 hour b) Yes. TS 2.1.2. Restore in 5 minutes c) Yes. LCO 3.1.6 Condition A d) Yes. LCO 3.4.2 Condition A e) Yes. TR LCO 13.1.32 Condition A. f) Yes. LCO 3.0.3. g) Yes. LCO 3.1.4 Condition B h) No. LCO 3.1.7 Condition A i) Yes. TR LCO 13.1.39 Condition A j) No. LCO 3.3.2 Condition D. k) Yes. LCO 3.3.1 Condition T. l) No. LCO 3.3.1 Condition E & M; LCO 3.3.2 Condition D m) Yes. LCO 3.4.8 Condition A. n) Yes. LCO 3.4.10 Condition A o) No. LCO 3.7.1 Condition A p) No. LCO 3.7.18 Condition A q) Yes. LCO 3.8.1 Condition B r) No. LCO 3.8.9 Condition B s) Yes. TR LCO 13.9.31 Condition A

61. You are the Unit 1 Unit Supervisor and have been informed by the RO of the problem with SOP-104A which was stated in an earlier question (SOP refers to 1/2-MU instead of 1/1-MU). For each of the actions listed below, explain why each would or would not be correct and choose the best action for this situation: [Ref: STA-201, STA-202, ODA-407] a. N/A the step and allow performance of the next step. b. Use N/A to allow proceeding using the 1/1-MU handswitch. c. Process an Interim Approved Change to correct the procedure before continuing. d. Make an Editorial Change to the procedure before continuing. e. Make a One Time Procedure Change to allow proceeding until the procedure can be formally changed. f. Use the normal change process to change the procedure before continuing. g. Identify the need for a procedure change, authorize proceeding and process the change when time allows.

As follows: a. No. N/A should NOT be used to bypass steps that are inadequately or improperly written or otherwise be used in lieu of an approved change. In addition, the step is critical to proper task completion. b. No. N/A does not mean a step can be changed. N/A only allows not using a step if it meets N/A criteria. c. Yes. The procedure methodology is not as it should be. The procedure should be changed before dilution is performed. An Interim Approved Change may be performed, instead of the normal procedure change because the evolution needs to be performed soon. The normal procedure change process requires more extensive approval than the interim change. The interim change only requires approval of a knowledgeable member of operations staff and either the Shift Manager or Unit Supervisor. d. No. The change from 1/2-MU to 1/1-MU does not meet the strict criteria of STA-202 for editorial changes. e. No. A One Time Change doesn't allow for a faster or less-reviewed change. It exists to allow changes to a procedure for one use to address a unique set of circumstances without permanently changing the procedure and then having to change it back. f. Yes. This method is allowed and generally preferred. However, since this method also requires Operations Manager approval, it may be more expeditious to use the Interim Approved Change Process. g. No. The only time this latitude is given is in implementation of ERGs and ABNs and in those cases you must follow guidance given for an ERG/ABN deviation.

90. With Unit 1 operating at power, 1-HV-5545, Containment Air Radiation Monitor Supply Isolation Valve is determined to be failed open. What action should be taken? [Ref: ODA-308, Technical Specifications]

As follows: • Refer to standard LCOAR Form in ODA-308 for LCO 3.3.6. • Turn off the Containment PIG Radiation Monitor sample pump from PC-11 per SOP-706. • Enter LCO for TS 3.6.3, "Containment Isolation Valves." Close 1-HV-5544 in-line with the failed penetration isolation and make clearance tied to LCOAR to keep it in this position (within 4 hours, 3.6.3 Condition A) • Enter LCO for TS 3.3.6, "Containment Ventilation Isolation Instrumentation" and 3.4.15 "Leakage Detection Systems." Close and maintain closed 1-HV-5548 and 1-HV-5549, Containment Pressure Relief Isolation Valves. • Enter LCO for TS 3.4.15., "Leakage Detection Systems" for loss of air particulate monitoring capability. Establish grab samples or perform RCS water inventory balance per OPT-303 once per 24 hours.

92. Unit 2 is at 75% RTP when all DRPI bezel indication goes dark. What action is required? [Ref: ABN-712, Technical Specifications]

Attempt to shift power supplies per SOP-608B. If bezel indication is not restored, initiate repairs per STA-606. Place Rods in Manual, monitor and record RCS Tavg once per hour, verify rod position indirectly by using core power distribution measurement information once per 8 hours and within 4 hours if rod movement >24 steps and restore within 24 hours.

65. How can you, as Shift Manager, know that a test procedure does not constitute a test or experiment not described in the safety analysis? [Ref: STA-707, 10CFR50.59]

By using your judgment based on training and experience and by ensuring the test is properly approved. The evaluation (screening) which is performed as part of the approval process for any procedure addresses the issue of whether or not it is described in the FSAR and whether prior approval must be granted by the NRC or a license amendment is required.

1. Define the term "continuous use." [Ref: STA-201]

CONTINUOUS USE of a procedure or work instruction is required for complex or infrequent work activities for which consequences of an improper action could have an immediate, possibly irreversible adverse impact on safety, production, or reliability.

18. Which log is used to record common unit operations? [Ref: ODA-104]

Common unit operations should be recorded in the "Unit 1 & Unit 2 log".

26. What is the definition of a confined space? [Ref: STI-211.01]

Confined Space - any space in which all of the following conditions exist: 1) Large enough to be entered with the entire body. 2) Limited entry and/or exit. 3) Not designed for continuous occupancy.

29. How can you obtain a Safety Data Sheet for a chemical used in your work area? [Ref: Comanche Peak Safety Pocket Manual, CPINET - Safety Services Home Page]

Contact your supervisor or obtain a Safety Data Sheet using the SDS Finder on the Safety Services intranet website.

21. When are Control Board Status Aids required to be updated? [Ref: ODA-410]

Control board status aids should be updated to reflect the current plant component's status, as applicable, upon completion of any realignment when the associated system is in service.

45. What is the definition of "core alteration?" Identify specific activities or manipulations that should and should not be considered core alterations. [Ref: RFO-102, Technical Specifications]

Core alterations shall be the movement of any fuel, sources, or reactivity control components, within the Reactor vessel with the vessel head removed and fuel in the vessels. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position. The following items have been discussed as to whether they do or do not constitute a CORE ALTERATION per Technical Specifications. The following items are considered as "Core Alterations": • RCCA Unlatching (including RCCA drag testing) • Upper Internals Lift • Fuel Movement • RCCA Latching (including RCCA drag testing) • These items should NOT be considered "Core Alterations": • Reactor Vessel Head Removal • Positioning Underwater Lights • Positioning Underwater Cameras • Movement of fuel loading shoehorns and cables • Moveable Incore Thimble Tubes (Removal or Replacement) • Post Core Load Verification • Upper Internals Replacement • Removal of Reactor Vessel Test Capsule with fuel installed in the vessel

76. Whose approval is required to perform troubleshooting on an operating safety related component? [Ref: STI-606.05 STATION TROUBLESHOOTING ACTIVITIES]

If prepared by on-shift Operations personnel, it should be reviewed and approved by the Shift Manager. Implementation is approved by the US or Shift Manager as appropriate. If prepared by other groups the RWO manager preparing the plan must concur and approval by an SRO. If technical specification or safety related equipment is involved the plan content must receive concurrence from the Shift Operations Manager. Implementation approval is as stated above.

74. Define "defense in depth" as it applies to plant status during outages. [Ref: STA-627, STI-604.04]

Defense In Depth (DID) - For the purpose of managing risk during shutdown, Defense In Depth is the concept of: Providing systems, structures, and components to ensure backup of Key Safety Functions using redundant, alternate, or diverse methods. Planning and scheduling outage activities in a manner that optimizes safety system availability. Providing administrative controls and contingency plans that support and/or supplement the above elements ultimately resulting in a reduction of the probability of a core-damage event during a planned outage. STI-604.04, "Outage Safety Function Guide" (OSFG) establishes the desired level of Defense In Depth.

100. Define the following: [Ref: STI-211.06] a. Annual Limit on Intake (ALI) b. Derived Air Concentration (DAC) c. Threshold Limit Value (TLV)

Definitions: 1. Annual Limit on Intake (ALI) - The derived limit for the amount of radioactive material taken into the body of an adult worker by inhalation or ingestion in a year. ALI is the smaller value of intake of a given radio nuclide in a year by the reference man that would result in a committed effective dose equivalent of 5 rem or a committed dose equivalent of 50 rem to any individual organ or tissue. 2. Derived Air Concentration (DAC) - The concentration of a given radionuclide in air which, if breathed by the reference man for a working year of 2,000 hours under conditions of light work results in an intake of one ALI. 3. Threshold Limit Value - There are three (3) categories of Threshold Limit Values (TLVs) which are defined as follows: • Threshold Limit Value - Time Weighted Average (TLV-TWA) - The time weighted average concentration for a normal 8-hour work day and a 40 hour week to which nearly all workers may be repeatedly exposed, day after day, without adverse effect. • Threshold Limit Value - Short Term Exposure Limit (TLV-STEL) - A 15-minute weighted average exposure which should not be exceeded at any time during a work day even if the 8 hour TWA is within the TLV. Exposures at the STEL should not be longer than 15 minutes and should not be repeated more than four times per day. There should be at least 60 minutes between successive exposures at the STEL. • Threshold Limit Value - Ceiling (TLV-C) - The concentration that should not be exceeded even instantaneously.

49. Place the following steps in the correct sequence: • Remove upper internal package • Flood cavity to 858'2" • Unlatch control rods • Place reactor vessel head on storage stand • Isolate dilution paths [Ref: RFO-102]

Dilution paths must be isolated prior to Mode 6 entry (vessel head detensioned). Cavity flood is started after the initial head lift but the reactor vessel head is normally placed in the storage stand before the cavity reaches 858'2" to minimize time that the load is suspended. Control rod drive shafts are unlatched after head removal and flood up to about 858'2" elevation but before removal of the upper internals package. (5, 3, 4, 2, 1)

77. What issues should be considered when using procedure sections to perform troubleshooting? [Ref: STI-606.05 STATION TROUBLESHOOTING ACTIVITIES]

Exercise caution when using procedures or procedure sections that were not specifically written to cover the activity being performed, i.e., systems are operated to OPTs, SOPs, or ABNs. If troubleshooting would result in operation outside of these procedures or if the intent of the procedure is not the same as the intent of the activity being performed, then write a temporary procedure or PCN an existing procedure to cover the activity. Steps written in a work order cannot be used to change or allow deviation from a procedure during troubleshooting of in-service equipment.

55. List some indications and controls on Unit 1 control boards which are not duplicated on Unit 2.

Indications on Unit 1 boards only: • DWST level • BAST levels • Instrument Air Compressor X-01, X-02 lights • Hydrogen purge exhaust fan controls

11. How many individuals may you escort in a vital area? [Ref: STA-902]

Five (5)

31. List and describe the types of approach boundaries used when working on exposed energized equipment [Ref: STA-124]

Flash Protection Boundary - An approach limit at a distance from an exposed live part within which a person could receive a second degree burn if an electrical arc flash were to occur. Limited Approach Boundary - An approach limit at a distance from an exposed live part within which a shock hazard exists. A non-qualified person cannot cross the limited approach unless under the direction of a qualified person. Restricted Approach Boundary - A shock protection perimeter that can only be crossed by qualified persons knowledgeable in the use of shock protection techniques, tools, and equipment.

78. A valve motor operator torque switch has been adjusted under a work order. What general types of test(s) should the work order direct Operations Department to perform prior to declaring the valve operable? [Ref: Post Work Test Guide]

Functional stroke test for position indication, exercise test, stroke time test, as-left Appendix J LLRT for Containment isolation valves, boundary valve leak test for RCS boundary isolation valves.

41. RCS dissolved hydrogen is determined to be 20 cc/Kg while operating at power. Determine the Action Level and required actions. [Ref: STA-609]

Hydrogen concentration below 25 cc/Kg (but >15) places the plant in Action Level 1. Initiate actions to restore to within optimized value of 25 to 50 cc/Kg within 7 days. Note that the exception to permit operation > 15 cc/Kg but < 25 cc/Kg for up to 24 hours without entering Action Level 1 only applies for the initial period after startup.

34. While performing a system lineup at the end of an outage, you discover the position indicator broken on one of the valves to be aligned. If you can determine by other means that the valve is correctly positioned, what action should you take regarding the lineup and the valve position indicator? [Ref: ODA-410]

If time permits, have the Prompt Team or appropriate Smart Team repair the problem. If the valve can be ascertained to be in the proper position and functional by other plant indications (flow, temperature, etc.) and it cannot be repaired prior to the need to close out the line-up, then document the problem (e.g., write a CR).

98. You, a qualified Radiation Worker, are walking through the Auxiliary Building and notice a container collecting leakage from a system is overflowing. The container is inside an area marked off as a contamination area and fluid is leaking outside the boundary. The liquid has pooled outside of the roped-off area and the container is still leaking. What should you do? [Ref: STA-653]

Inform the Control Room by gaitronics or telephone. Inform others to stay away. Don gloves and booties and use materials found in spill kits, if available, to limit the spread of contamination and to direct leakage to a floor drain, if possible.

93. Inverter IV2EC3 develops an internal fault and output breakers trip open and the associated instrument bus de-energizes. What actions are required? [Ref: Technical Specifications, ODA-308]

Initiate repairs. Enter LCO for TS 3.8.9, "Distribution Systems - Operating." Restore power to 2EC5 within 2 hours from bypass power. Align the panel 2EC5 to IV2EC1/3 per SOP-607B within 24 hours. NOTE: ODA-308-3.8.9 requires Condition D to be entered or a risk evaluation to be performed if the panel will be operated on bypass power for greater than 16 hours

50. What indications should be monitored while inserting a new fuel assembly into the core? [Ref: RFO-401, RFO-102]

Monitor the following during fuel assembly insertion: a) SR NIs should be monitored in Control Room to verify reactor remains subcritical (during CORE ALTERATIONs). b) The weight indicator should be continuously monitored to see that the indicated weight does not drop below the combined weight of the gripper mast, fuel assembly and insert assembly. A weight drop could indicate binding on other assemblies.

81. What time is used as the LCO initiation time? [Ref: ODA-308]

LCOAR Initiation Time - The time at which it is determined that a LCO is not satisfied (Active LCOAR) or when a LCO is impacted (Tracking LCOAR). This initiation time may be any of the following: • The time of discovery of a clearly adverse condition affecting OPERABILITY, OR • The time of notification to the Shift Manager that a Quick Turnaround Technical Evaluation (QTE) has determined that a component is inoperable, OR • The time at which the allowable surveillance interval expired in accordance with Technical Specification SR 3.0.3. When it is discovered that a surveillance has not been performed within its specified frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours OR up to the limit of the specified frequency, whichever is greater. However, a risk evaluation shall be performed for any Surveillance delayed greater than 24 hours and the risk impact shall be managed. Also, the SR 3.0.3 Bases states the missed surveillance should be performed at the first reasonable opportunity. The delay period is permitted to allow performance of the surveillance inaccordance with SR 3.0.3.

86. When do we declare entry into MODE 2? [Ref: IPO-002A/B]

MODE 2 entry is declared upon withdrawal of Control Bank A rods during a startup. This declaration is made after Control Bank rods have been fully withdrawn and reinserted to CBO to reference and offset rod banks. The declaration of MODE 2 occurs before TS conditions for MODE 2 are actually met.

85. What is the formal definition of MODE 2? [Technical Specifications]

MODE 2 is defined as the inclusive combination of reactor power < 5% and keff > 0.99.

87. When do we declare entry into MODE 6 from MODE 5? [Ref: RFO-102]

MODE 6 entry from MODE 5 is declared at the time de-tensioning of head bolts is initiated.

71. What reference is available to identify the test procedure which is used to meet a given surveillance requirement? [Ref: STA-702]

Maximo, and the Operation's Web Page. In Maximo, select Locations, then References. The test procedure(s) that satisfy the surveillance requirement will be listed under "Other Related Items". From the Ops Web Page, the information can be found under the Component Information tab. Select Component Detail, the Surveillance Detail field will list the associated test procedures.

5. A delta-I swing is in progress. As the RO monitoring the situation you decide it is time to perform a dilution and to insert rods 2 steps to dampen the oscillation. Do you have the authority to perform these activities without informing your Unit Supervisor? Why or why not? [Ref: ODA-102]

No - ODA-102 requires the RO to "Inform the Unit Supervisor prior to any dilution, boration, rod movement, or turbine load changes. Include the magnitude and direction (for rods and turbine load) of change."

91. 1-HV-5545, Containment Air Radiation Monitor Supply Isolation Valve is failed open. A spurious reactor trip occurs. The cause of the trip has been determined and corrected. Assuming 1-HV-5545 is the only inoperable plant component, would you be allowed to restart with this valve out of service? [Ref: Technical Specifications]

No - Technical Specification LCO 3.3.6 would allow conformance to the action requirement of 3.6.3 (affected penetration isolated) and thus allow continued operation of the facility for an indefinite period of time, therefore allowing a MODE change. However, the action statement of 3.4.15 would not. Continued operation with the Containment PIG out of service is allowed provided grab samples are obtained or RCS water inventory balance is performed every 24 hours, but the PIG must be restored within 30 days. A risk assessment in accordance with 3.0.4.b may allow a MODE change as it is not specifically precluded in TS 3.4.15.

9. You are the RO working your second day of a four day run of dayshift. Your relief calls in saying he will be 3 hours late today. Are you allowed to stay over to cover him until he arrives? If so, what actions are required? [Ref: STA-615]

No more than 26 hours should be worked in any 48-hour period. If you stay over, you will end up working 27 hours in a 48-hour period. A waiver (STA-615-1) may be authorized provided: • The crew member's absence would cause a violation of minimum manning requirements • No other qualified individual is available to provide coverage • The Operations Shift Manager or site senior-level manager with requisite signature authority determine that a waiver is necessary to mitigate or prevent a condition adverse to safety • A cognizant supervisor completes a face-to-face fatigue assessment no more than four (4) hours prior to the start of the waiver period (extended work hours) • The waiver is approved before the waiver period begins • You must remain in compliance with all other work hour rules (must have a minimum 10-hour break before starting the third day of your scheduled dayshift run). Consequently, another qualified individual must be available to cover at least the first one and one half (1-1/2) hours of your next shift (assume relief arrives at 2100 and complete turnover at 2130).

10. Both units are operating at 100% power. One of the ROs needs tomorrow (a scheduled shift day) off. The crew is operating with four ROs. Can he be permitted to take the day off without scheduling someone else to take his place on shift? [Ref: ODA-102]

No.

2. You are the Unit 1 RO. SOP-104A, "Reactor Makeup and Chemical Control System" has just been revised. You are using the procedure to perform a normal periodic dilution to compensate for fuel burnup when you notice the procedure says, "Place 1/2-MU, RCS MU MAN ACT in STOP." You believe there is a typographical error; the procedure should refer to 1/1-MU vice 1/2-MU. Can you proceed with the dilution? If not, what should you do? [Ref: STA-201]

No. You must stop the task in progress and immediately notify the Shift Manager or Unit Supervisor of your discovery of the procedure error.

99. As the Unit Supervisor who just received a call about the potentially radioactive spill in the Auxiliary Building previously described, what should you do? [Ref: ABN-903, STA-653]

Notify Radiation Protection and dispatch operators to investigate. Coordinate actions with RP to block off area to reduce exposure and prevent spread of contamination.

17. Where can management expectations on verbal communication be found? [Ref: ODA-102, NMG-114]

ODA-102 and NMG-114 (located on CPINET and in the procedures database)

70. What surveillance requirements are met by performance of a Unit Calorimetric? [Ref: OPT-309]

OPT-309 satisfies Technical Specification Reactor Trip System (RTS) Instrumentation requirements for SR 3.3.1.2.2a, 3.3.1.2.6 and 3.3.1.2.7, and, the Technical Requirements Manual surveillance for TRS 13.3.34.1.

46. Containment closure must be established prior to initiating core alterations. What procedure is used to establish or verify Containment closure? [Ref: RFO-102]

OPT-408A/B is used to verify Refueling Containment Closure prior to CORE ALTERATIONS.

33. Who is responsible to ensure completed lineups of SOP-308A, "Heater Drains System" are updated in System Status Files at the completion of a Unit 1 outage? [Ref: Shift Operations Desktop Instruction 3, ODA-410]

Once the "paper" or eSOMS lineup is completed and no longer needed by the BOP WWM, and the train or system is turned over to the Control Room, then copies of the completed lineup can be made or printed from eSOMs and forwarded for the System Status File. Filed by the Shift Attendant.

54. What document identifies the design differences between the units and where is it located? [Ref: Operations Web Page]

Operations Web Page, "Unit Differences"

12. Define the terms "vital area" and "protected area." [Ref: STA-902]

PROTECTED AREA - The site area located inside the plant's double fenced line and to which access is controlled. VITAL AREA - Posted areas within the Protected Area that house safety-related equipment.

30. When work is being performed on exposed live electrical equipment, which methods can be used to alert others in the vicinity? [Ref: STA-124]

Place barricades/barriers in accordance with STA-124 or; Post an attendant to warn and protect other workers (> 480V only)

66. What is the authority level required to approve installation of a temporary modification in the plant? [Ref: STA-602]

Plant Manager

38. You are performing a lineup on the CCW system at the end of an outage. The lineup requires 1CC-0341, SEAL WTR HX OUT ISOL to be locked throttled. However, it is presently closed. How far open should you set the valve? [Ref: TDM-901A, SOP-502A]

Position 1CC-0341 approximately 3 and 1/8 turns off the full closed position. Use 1-FIS-4607 to adjust flow to 375 gpm. All system valves may need to be lined up using the lineup and the "turns open" settings of the TDM before going back and balancing system flows to desired flowrates.

44. At what temperature should RCS temperature be maintained during refueling? [Ref: RFO-102]

RCS temperature should be maintained at 80-90F. Temperature may be maintained at 110F until Cavity fill is initiated then reduce to 80-90F. RFO-102 prerequisite requires temperature less than 140°F.

39. What are the requirements on a person performing an independent verification? [Ref: STA-694]

Requirements on independent verifier: 1. Not same individual as the individual who performed initial alignment and free to establish own conclusions 2. Physically separate of initial alignment performer by time and distance 3. Qualified for the task and verification techniques

15. At what frequency should the Shift Operations Manager review the Standing Orders and update them? [Ref: ODA-106]

Review should be conducted annually.

25. What checks must be performed to ensure Containment atmosphere will support entry in MODES 1, 2, 3 or 4? [Ref: STA-620, STI-211.01]

STI-211.01 defines Containment as a Non-Permit Required Confined Spaces (NPRCS). And should be sampled at least once per shift (when in use). STA-620 requires the Shift Manager to have the Containment atmosphere checked for Class C atmosphere prior to initial entry and at least weekly thereafter (resets on Sunday at Midnight), the RWO supervisor to ensure Containment atmosphere has been checked during the week for a Class C atmosphere, personnel entering Containment during Power Operations to monitor Containment atmosphere for Class C atmosphere weekly using Containment atmosphere monitors available in MT&E issue area (and notify Control Room to log results in Unit Log), and RP to evaluate airborne radioactivity concentrations using the Containment PIG or air sample results. Safety Services should perform atmospheric monitoring of the Reactor cavity upon receiving notification of entry during Modes 4-2 power ascension following refueling outage.

22. You accidentally puncture your finger with a stapler while in the Control Room. What are you required to do? [Ref: Comanche Peak Safety Pocket Manual]

Seek immediate medical attention appropriate for the injury, report the injury to your supervisor, initiate documentation for the injury using the Luminant Injury Report form (located on Safety Services website)

19. Identify five (5) items which should be entered in the station log. [Ref: ODA-104]

Significant operating actions or occurrences should be entered in the Station Log including: 1) A description of any reportable occurrence. 2) Complaint calls from offsite. 3) Occurrence of any work related sickness or injuries. 4) Communications with the NRC. 5) Parties involved, when reporting outside calls or emergency communications. 6) Entry and exits of the Emergency Plan. 7) Out of specification Chemistry parameter leading to mode change, power reduction or LCO entry. 8) Pertinent communications with the Generation Controller. 9) Mode changes. 10) Transfer of command function. 11) Time, subject on POEs requested to support or confirm OPERABILITY.

20. Identify ten (10) items which should be entered in the unit log. [Ref: ODA-104]

Significant operating actions or occurrences should be entered in the Unit 1 and Unit 2 Log including: 1) Decisions made by supervisors concerning operation of the units. 2) Entry and exits of the Emergency Operating Procedures. 3) Entry and exit from ABNs. 4) Main Generator on-line or off-line time. 5) Amounts of boration or dilution 6) Unplanned or unexpected change in plant radiological conditions. 7) Completion and results of surveillance tests not conducted under the auspices of a work order. 8) Changes in reactor power level of more than 2% including reason for the change, and final power level. 9) Changes to turbine electrical load such as OPT testing (e.g. OPT-206A/B, OPT-217A/B), QSE orders, changes to adjust power level within limits, etc. 10) When QSE Generation Controller voltage change requests cannot be performed with reason why request cannot be performed. 11) Occurrence of a grid reportable event and any communications associated with this event. (STA-501 NR-41 and corporate procedure G-3025 define reportable event.) 12) Starting and stopping of major equipment (i.e., CWPs, AFW pumps, etc.) 13) Changes to system configuration not tracked by ODA-410, including configuration changes resulting from ABN/ALM procedure response. 14) Unusual or significant maintenance activities that affect operations. 15) Unplanned escalation of Probabilistic Risk Assessment (PRA) Level AND actions taken to address the new PRA Level. 16) Actuation of significant annunciator alarms. 17) Instrument or equipment malfunctions or failures and action taken to resolve the problem. 18) CVCS transients including loss, initiation or isolation of charging or letdown flowpaths. 19) Reactor Coolant pressure transients including challenges to PORVs and safeties. 20) Mode changes 21) Changes of control systems to alternate channels or manual control. (Unless positioned during the performance of an OPT, SOP, or Maintenance/I&C Surveillance where the position is governed by the procedure. 22) Occurrences while performing procedures where parameters were out-ofspecification or not in accordance with expected results. 23) Initiation and termination of liquid or gaseous discharges. 24) Entry into an Emergency Action Level (EAL).

58. When requesting engineering services or field work to change or repair buildings and components, which buildings and components are considered as site facilities? [Ref: STI-716.02]

Site facilities include all or any portion of buildings, structures, site improvements, complexes, equipment, rolling stock or other conveyances, roads, walks, passageways, parking lots, or other real or personal property, including the site where the building, property, structure, or equipment is located, that is not considered plant Systems Structures or Components (SSCs) or part of the Dry Cask Storage System as referenced by STA-606.

52. How frequently must the RO monitor SR NIs when CORE ALTERATIONS are in progress? [Ref: RFO-102]

Source range nuclear instrumentation shall be monitored by a Control Room operator at all times when CORE ALTERATIONS are being performed.

94. Refueling Water Storage Tank Level Transmitter 1-LT-0932 fails high with Unit 1 in MODE 1. What action is required? [Ref: Technical Specifications]

Technical Specification 3.3.2, "ESFAS Instrumentation," Condition K requires that associated ECCS switchover bistable be bypassed within 72 hours. Technical Specification 3.3.3, "Accident Monitoring Instrumentation," is not affected because only two indicating channels are required of the four normally available.

79. Both units are at 100% RTP. Unit 2 Train A SSW Pump is out of service to replace a temperature element. Unit 1 Train B SSW Pump motor catches fire and trips off. What LCO action(s) apply? [Ref: Technical Specifications]

Technical Specification 3.7.8 Condition B and 3.8.1 Condition B. Additionally, both units are in a tracking LCOAR for T.S. 3.7.8 Condition A.

23. A worker calls the RO and reports that his co-worker is unconscious in the 790' Auxiliary Building and then hangs up. What is the appropriate Control Room response? [Ref: Comanche Peak Safety Pocket Manual, DTI-OPS-002]

The Control Room should sound the Yelp tone and make an announcement on gaitronics and radio to the effect of: "Attention in the plant. This (is / is not) a drill. A Medical Emergency Exists in (Location). Medical Response Team contact the Control Room and respond to (Location)'." The alarm and message should then be repeated.

28. What administrative controls are established to ensure personnel protection from overheating during work activities? [Ref: STI-211.07]

The Heat Stress Management Program directs job planning, evaluation of engineering controls to reduce exposure, establishment of stay times, training personnel to recognize heat stress symptoms, workers to utilize self-determination to limit exposure risk, and use of personal protection such as alternate cooling equipment.

13. What activities and events should be announced on the plant gaitronics system? [Ref: ODA-102]

The ODA section on Plant Gaitronics lists the following: • Commencement of a reactor startup or shutdown • Reactor trips or load rejections • Abnormal or emergency conditions • Activation of the E-plan, change in E-plan EAL (emergency action level), site evacuation, a change in the Emergency Coordinator • Starting major plant equipment • Changes in electrical distribution system lineup • Significant changes in radiological conditions

53. The refueling machine operator reports to you, the RO, that a spent fuel assembly has been dropped. Shortly thereafter, PC-11 alarms are received on the Containment PIG monitors. What should you do? [Ref: ABN-908]

The RO should report a dropped fuel assembly to the Unit Supervisor, acknowledge the PC-11 alarms and report them to the Unit Supervisor. These are entry conditions for ABN-908 and should be recognized by the RO. If necessary, the RO should prompt the Unit Supervisor to take ABN-908 actions, including notifying the Shift Manager, making a plant announcement and evacuating Containment, and verifying Containment ventilation isolated.

42. Chloride concentration in Steam Generator blowdown spikes to 600 ppb due to placing a contaminated polisher in service at 100% power. The polisher is immediately removed from service and concentration rapidly decreases to <100 ppb. What additional action(s) should be taken? [Ref: STA-610]

The SG chloride spike places the unit under Action Level 3 criteria, which requires a power reduction to < 5%, regardless of the duration of the excursion and may require a plant shutdown and cooldown based on the recommendation of the Chemistry manager.

68. Who ensures required procedure revisions are approved and ready for implementation prior to installation of the TM? [Ref: STA-602]

The Temporary Modification Coordinator (TMC) is responsible for verifying that the changes to procedures affected by the TM have been approved or other controls are in place prior to installation or restoration of the TM.

82. Safety Injection Pump 1-02 has been declared inoperable for administrative reasons but is still functional and available. An active LCOAR is initiated and has been properly logged. What else needs to be done? [Ref: ODA-308]

The US should ensure the SSII panel is manually actuated when any System or Component covered by the SSII panel becomes inoperable AND is required in the present MODE. • The SSII panel should be manually actuated as soon as possible after the initiation time of the Active LCOAR. • SSII actuation should be documented on the LCOAR. • The SSII panel should remain manually actuated until the US notifies the RO that the LCO Action has been exited, the LCOAR has been terminated, AND the equipment is OPERABLE.

4. The Turbine Building Operator calls the control room and asks you to shift the running TPCW pumps on his unit so that he can take a closer look at the pump coupling to ensure it is okay. Who can approve this evolution? [Ref: ODA-102]

The affected unit's Unit Supervisor is responsible for approving changes in equipment and system operational status.

16. Normally, who has approval authority for Operations Lesson Learned? Who has approval authority if the information is considered of immediate "need-to-know"? [Ref: ODA-106]

The approval authority of the Lessons Learned is the Shift Operations Manager or designee. If the information is of immediate "need-to-know" importance, the approval authority should be the Shift Manager. When that is the case, the Shift Manager should inform the Shift Operations Manager at the earliest opportunity.

47. What is the minimum elapsed time allowed for completion of core off-load following reactor shutdown? [Ref: RFO-102]

The design analysis of the Spent Fuel Cooling Systems assumes that a normal full core off-load starts at 75 hours after the reactor is subcritical and is complete no earlier than 125 hours after the reactor is subcritical (FSAR 9.1.3.1.1). The 125-hour limitation is a conservative value which may be modified by a core-specific offload calculation.

83. What is the basis for maintaining the control rods above the rod insertion limit? [Technical Specifications]

The insertion limits of the shutdown and control rods are initial assumptions in all safety analyses that assume rod insertion upon reactor trip. The insertion limits directly affect core power and fuel burnup distributions and assumptions of available SDM, and initial reactivity insertion rate. Limits on control rod insertion have been established, and all rod positions are monitored and controlled during power operation to ensure that the power distribution and reactivity limits defined by the design power peaking and SDM limits are preserved.

60. Siemens, A.G. publishes a bulletin recommending replacement of the air side seal oil pump's start switch (A ON, B ON, OFF) at the GAC, with one that is "functionally equivalent." How would we determine if this constitutes a change to the facility as described in the FSAR? What CPNPP process would be utilized to make the replacement? [Ref: STA-716, ECE-5.08]

The modification would be reviewed against the requirements of STA-716 and ECE-5.08. A Design Equivalent Change would likely be utilized.

63. What constitutes a temporary change to a procedure? [Ref: STA-202]

The regulatory term for a change to a procedure which has been approved by a management individual and an SRO but has not received the final 14-day approval. At CPNPP, it is referred to as an "interim approved change."

6. How far back in time should you review the unit log when assuming the watch as the Unit Supervisor, the BOP or the RO? [Ref: OWI-107]

The review of Station and Unit Narrative Logs should include a review of the period since the on-coming person's last on-duty shift, not to exceed five days.

84. What is the basis for maintaining average coolant temperature <588 (592)°F? [Technical Specifications]

The safety analyses of normal operating conditions and anticipated operational occurrences assume initial conditions within the normal steady state envelope. The limits placed on RCS pressure, temperature, and flow rate ensure that the minimum departure from nucleate boiling ratio (DNBR) will be met for each of the transients analyzed. The RCS coolant average temperature limit is consistent with full power operation within the nominal operational envelope. Indications of temperature are averaged to determine a value for comparison to the limit. A higher average temperature will cause the core to approach DNB limits.

97. Assuming an individual has received 1200 mrem for the year to date and has no other exposures in excess of routine dose limits, what would the dose limit be for a planned special exposure as a member of a Steam Generator tube plugging team? [Ref: STA-655]

Under a Planned Special Exposure an individual is allowed to receive 4000 mrem for the year due to the Planned Special Exposure if he or she has not had other exposures in excess of routine occupational dose limits. So, for this case the PSE limit would be 4000 mrem.

56. What are the setpoints on each unit for the following: [Ref: ABN-502, 710] a. SG Low Level Reactor Trip b. High SG Level Turbine Trip (P-14) c. Auto CCW Makeup d. CCW Surge Tank Empty/Safeguards Loop Isolation

Unit 1 Setpoint Unit 2 Setpoint a) SG Low Level Reactor Trip 38% 35.4% b) SG High Level (P-14) 84% 81.5% c) Auto CCW M/U 63% 39% d) Surge Tank Empty 57% 33%

73. The unit is operating at power. The Auxiliary Building NEO reports that the Train A CCP had a significant oil leak, which stopped when the pump was secured. You can run the pump if necessary for a short time. What priority should be assigned to the Work Order? [Ref: STI-606.01]

Urgent (Priority 2) Activities required for maintaining plant reliability, safety issues and longer term Technical Specification Action Statements. The Responsible Manager should ensure work starts within 24 hours and continues daily. SM could assign a Priority 1 based on Regulatory implications of having an inoperable CCP.

35. During power operation, the inlet isolation to the main turbine lube oil temperature control valve is discovered partially closed. In response, the Shift Operations Manager directs the performance of a verification lineup on the turbine plant cooling water system. What is a verification lineup and what valves need to be verified on the lineup? [Ref: ODA-410, Operations Guideline 12]

Verification lineups may be performed at management's discretion if and when the need arises to verify component alignment. Those same lineups initially performed for system operation may be used; however, Verification Lineups do not require independent verification for completion. Verification Lineup attachments need only be completed for flowpath valves. The following valves may be marked N/A (not applicable) during the performance of Verification Lineup attachments at the Shift Manager's discretion. • Vent valves • Drain valves • Test connection valves • Sample valves • Throttle valves during "at power, system in-service" verification lineup

72. When hanging or removing clearances, no SOP is necessarily in use. The clearance hanger only has the clearance package in hand. During this evolution, what controls ensure that equipment is operated in accordance with approved instructions? [Ref: STA-605, STI-605.01]

When the clearance has been prepared, it shall be forwarded to the SRO or cognizant Operations Supervisor in control of the clearance review. 1. The SRO shall provide a supervisory review of the clearance to ensure proper tagging sequence, adequate boundary for personnel and equipment safety and that the necessary plant configuration is maintained on systems defined in STA-601 for Shift Operations responsibility. 2. The SRO shall denote all cleared equipment that requires a Verification prior to releasing the prepared clearance for implementation. (Clearances placed for Technical Specification LCO. requirements or configuration control.) 3. The SRO should determine if other work is to be performed on equipment within the clearance boundary. If the exact clearance boundaries ensure proper safety, other Work Orders may be performed under the same clearance. 4. The SRO should ensure the applicable work order(s) are associated with the clearance. 5. The SRO shall ensure the clearance has been prepared or reviewed by a qualified clearance preparer and then reviewed by an SRO.

8. Both units are operating at full power. The operating crew is composed of the following: (1) SM (3) US (2 are STA qualified) (4) RO (1) FSS (1) RP Tech (1) Chem Tech (8) PEO (1) RW One of the STA qualified Unit Supervisors receives a call that a close family member has a medical emergency. He informs the Shift Manager that he is going home immediately to assist with the emergency. Is this action permissible? How should the Shift Manager respond? [Ref: ODA-102]

Yes, this is permissible and can be classified as the unexpected absence of an onduty crew member. With his absence, the crew complement is one less than the minimum required. The Shift Manager must take immediate action to restore crew complement to minimum within 2 hours.

37. Is the Service Water Intake Ventilation System a system requiring independent verification when performing component lineups? [Ref: STA-694]

Yes.

62. Section 5.4 of Technical Specifications says, "written procedures shall be established, implemented, and maintained covering the activities referenced below." Do SOPs fall under this specification? [Ref: Technical Specifications, Regulatory Guide 1.33, Rev 2, February 1978]

Yes. Appendix A of Regulatory Guide 1.33 provides a list of procedures needed to operate a nuclear station and includes IPOs, ABNs, SOPs, STAs, etc.

59. The Operations Manager supports replacing the PDPs with a third CCP on each unit. Would this constitute a change to the facility as described in the FSAR? What CPNPP process would be utilized to make the replacement? [Ref: STA-716]

Yes. The NSSS, including all supporting systems are described in the FSAR. The design modification process would be utilized.

27. Is the auxiliary boiler fire box classified as a confined space? [Ref: STI-211.01]

Yes. The auxiliary boiler fire box meets the definition of a confined space.

67. Does the installation of a temporary modification (TM) need to be independently verified? [Ref: STA-602]

Yes. The installation of the modification and the associated TM tags and removal of temporary modifications are required to be independently verified.

3. Can you, as the Unit 1 US go to the RCP Vibration Panel? If so, what restrictions apply? [Ref: ODA-102, STA-616]

Yes. You should inform the RO/BOP that you are leaving the AT THE CONTROLS area and minimize your time away from the horseshoe area. One other SRO must be in the AT THE CONTROLS area, the RO and BOP must be in the AT THE CONTROLS area.