ADMIN Flashcards

Question 1

Q

Who orders start-up or shutdown the reactor for planned maintenance or refueling?

Answer

A

“10AC-MGR-001-0

Vice-President”

Question 2

Q

Who may order a shutdown during an emergency or when continued operation would jeopardize the plant or personnel safety?

Answer

A

10AC-MGR-001-0

Anyone with an operator license

Question 3

Q

What actions are required for a RAS?

Answer

A

“31GO-OPS-006-0
-A RAS DOES NOT have to be initiated for a REQUIRED ACTION (Except For Corrective Maintenance) that WILL NOT be in effect at the end of the shift.
• SM must be notified of inoperability
• Entry and exit as well as actions taken logged in MCR log
• SM notified when the Condition/Required Action is terminated

SS signs SS SIGN/TSA ACTIVE block of Section 2 of the RAS, signifying the sheet is active.
SM reviews and signs SM SIGN block of Section 2 indicating concurrence with the RAS
Alternating between LCO Conditions, in order to allow indefinite continued operation while not meeting the LCO, is NOT allowed.”

Question 4

Q

What are the conditions for normal entry into the drywell?

Answer

A

“31GO-OPS-005-0
Any containment entry after the initial entry where reactor power is less than or equal to 20% RTP and containment atmospheric conditions are acceptable as per subsection 6.3.”

Question 5

Q

What are the conditions for abnormal entry into the drywell?

Answer

A

“31GO-OPS-005-0
Any containment entry made with reactor power greater than 20% RTP OR the containment atmospheric conditions unknown or NOT acceptable as per subsection 6.3.”

Question 6

Q

What are the pre-entry conditions for entry into the drywell?

Answer

A

31GO-OPS-005-0 6.3 Entry Conditions:

The following conditions must be met before an initial containment entry is permitted:

Oxygen ≥ 19.5% AND < 23.5% by volume
Hydrogen ≤ 0.57% by volume
Carbon Monoxide ≤ 50 ppm
Airborne Radioactivity ≤ Hi-Hi Alarm setpoint on Fission Product Monitors OR Samples by RP, Indicate Entry Into the Drywell is Permitted
Reactor Power ≤ 20 percent RTP
Drywell Pressure > 0.0 PSIG and < 0.65 PSIG

Question 7

Q

What are the conditions for initial entry into the drywell?

Answer

A

“31GO-OPS-005-0
The first containment entry made subsequent to containment being de-inerted or drywell pneumatics on nitrogen supply, when reactor power is less than or equal to 20% RTP.
4.1.1 At least two persons are required when initial or abnormal primary containment entries are made; one of whom must be a qualified Radiation Protection Technician. A Radiation Protection Technician may NOT be required IF Radiation Protection Technicians are posted in primary containment as during a refueling outage.
4.1.2 A two-person backup team must be available for an Initial OR Abnormal Entry. This team will be equipped as specified in this procedure.
4.3.1 Approval must be obtained from the Shift Supervisor before an initial entry is made into the primary containment.
4.3.2 IF the conditions of 6.3 cannot be met, the entry will be considered abnormal AND approval for the abnormal entry must be obtained from the Plant Manager.
6.6 IF performing Initial OR Abnormal entry, THEN perform NMP-AD-006, Infrequently Performed Test and Evolutions.
7.1.1.3 After the Shift Supervisor has been notified by Radiation Protection AND Chemistry, that two successive samples of the containment atmosphere meet pre-entry conditions, the Shift Supervisor may approve initial containment entry.”

Question 8

Q

Who has the responsibility to manually align, start, or initiate any auto-start system that failed to auto-start?

Answer

A

NMP-OS-007-001
Nuclear Plant Operators (NPOs) have the responsibility to manually align, start, or initiate any automatically actuated system, equipment, signal, or function that has indication of a start failure or incomplete initiation so that it will perform its intended function unless operation would create a condition that would not mitigate a transient.
NMP-OS-007-001
WHEN a system or component has been placed in manual due to a transient caused by an automatic control malfunction, SM permission is required prior to returning the system or component to automatic control following stabilization from the transient and correction of the malfunction.”

Question 9

Q

Who can operate controls at the remote shutdown panel?

Answer

A

NMP-OS-007-001
4. During normal operation (generally non-emergency) controls at the Remote Shutdown Panel (RSDP) or Hot Shutdown Panels (HSP) which cause actual equipment operations shall be operated under the direct supervision or direction of a Licensed Operator currently assigned to the crew; the below exceptions apply:
-Controls which operate oil pumps may be operated by unlicensed personnel with SS approval.
-Controls which relate only to indication may be operated by unlicensed personnel with SS approval.
-Tags may be placed on equipment in the RSDP/HSP by unlicensed personnel
provided no manipulation of controls which can cause equipment operation will occur.

Question 10

Q

When is two-handed operation allowed?

Answer

A

NMP-OS-007-001
Control switches are operated single handed, except as specified below, or as specified in Attachment 2
Control switches are operated single handed (i.e., simultaneous manipulation) of two separate switches or controls will be avoided. This is to support use of STAR and focusing on the single piece of equipment being manipulated, except as specified below:
1. The Shift Supervisor may allow specific instances of Two-Handed Operation. This is appropriate WHEN specifically directed/permitted by procedure or required by design.
a. Two handed operation allowance is generally limited to conditions:
(1) where two switches must be operated to initiate a response, and do not require sequential operation.
(2) where two switches have similar function with a need or desire for close coordination between the two operations to mitigate the
significance/consequence of a transient or potential transient
b. Unless specified in Attachment 2, the use of Two-Handed Operation should be specifically requested, and granted on a case by case bases, such allowance should not be routine.

Hatch Specific Attachment 2 list

Energizing emergency 4KV bus while holding the 86 lockout closed
Control Rod withdrawal using rod movement and RONOR switches
Operation of RHR injection valves emergency operating procedures
Tripping of HPCI

Question 11

Q

What actions are required for lockout relays or electrical issues?

Answer

A

NMP-OS-007-001
Response to a Breaker that has Tripped or Malfunctioned
The SS may waive the following requirements based on plant conditions or specific event circumstances.
• Components that have tripped due to potential overload or failure condition should not be restarted until the cause is investigated
• Do not reset trip flags, thermal overloads or hand switch amber lights until directed by appropriate personnel after investigation has started.
• An investigation shall be performed by qualified personnel to determine the cause of the trip prior to further attempts to close the breaker or start associated equipment.

a. Mechanical relay flags (for example, on 4160V breaker cubicle doors) occasionally drop out due to vibrations. IF a breaker is clearly not tripped and no associated alarms have occurred, the system operator may attempt to reset the flag. The relay flag provides indication only. IF a relay has actuated it should have resulted in an alarm or breaker trip

Question 12

Q

What are the outage safety assessment risk colors and how often should attachment 1 be completed?

Answer

A

“31GO-OPS-024-0

Attachment 1 is performed once per shift, (to be completed as early in the shift as possible) AND when a system status change occurs.
Yellow (low risk) - This condition represents reduced but adequate safety function redundancy. This condition requires Shift Outage Manager approval. The operating shift shall be notified of the reduction in redundancy, no other contingency actions or plans are required.
Orange (moderate risk) - This condition represents a reduction in the capability to perform the safety function with little or no redundancy remaining. Steps shall be taken to minimize time spent in this condition. Planned entry into this condition requires detailed compensatory actions and contingency plans, and approval by the Outages and Scheduling Manager and the Plant Manager. If unplanned entry into orange condition occurs immediate actions will be taken to restore Yellow status.
Red (high risk) - This condition represents a potential loss of one or more Key Safety Functions. Planned entry into this condition is NOT allowed. If unplanned entry into Red condition occurs immediate actions will be taken to restore Yellow status.
The respective Unit Operator at the Controls (OATC) is responsible for completing the Outage Safety Assessment.”

Question 13

Q

What are important details of SUV-019?

Answer

A

“34GO-SUV-019-2
-P: Corrected Level = indicated level -15 IF the reactor is < 212F, AND indicator is on scale.
-Surveillances required once / 12 hr shift must be taken between 0800 and 1100 Eastern Time on day shift AND between 2000 and 2300 night shift.
-Surveillances required once/8 hours must be taken WITHIN 1.0 hours of the designated time.
-The paper copy of the procedure will be used:
oIF the computer will NOT perform required calculations.
oIF the output from the computer is obviously incorrect AND represents a serious degradation of the computer system operation.
oIF the version number specified in the computerized round for the procedure is incorrect AND the Software Support Personnel can NOT resolve the problem.
oIF a pre-planned Mode change for the Unit will take place during the shift
AND ‘U1/U2 MODE CHANGE SUV-019 12 hour’ tour is unavailable. “

Question 14

Q

When do you notify chemistry during startup?

Answer

A

“34GO-OPS-001-2
4.4.9 - Obtain confirmation from the on-shift Lab Foreman that reactor water,
condensate AND feedwater are acceptable for power operation
per the ‘Sampling AND Analysis During Power Operation’, subsection,
of 64CH-SAM-023-0.

4.12.19.d Notify the on shift Lab Foreman of reactor criticality.

34GO-OPS-005-2
2.2.14 Anytime reactor thermal power is increased OR decreased by > 15% RTP in one hour, the Chemistry lab shall be notified to perform the sampling requirements of Unit 2 Tech Specs.

34GO-OPS-013-2
4. Notify the Shift Manager and Shift Supervisor any time Reactor power is increased OR decreased by greater than 15% of rated thermal power in one hour. This is to ensure Chemistry Lab is notified to perform sampling requirements of Hatch ODCM Table 3-3, note C.”

Question 15

Q

During startup what SRM readings are needed for TS SR 3.3.1.2.4?

Answer

A

“34GO-OPS-001-2

4.1.13 Record the readings on all operable SRM channels below, confirming counts are >3 cps per TS SR 3.3.1.2.4.”

Question 16

Q

What signatures are required prior to going to START & HOT STBY?

Answer

A

“34GO-OPS-001-2
4.2.2 Obtain Shift Supervisor’s AND Shift Manager’s signatures confirming all prerequisites necessary to put the Reactor Mode switch in START & HOT STBY for the purpose of plant startup have been met.”

Question 17

Q

What are the steps to place the reactor mode switch in Run?

Answer

A

“34GO-OPS-001-2

2.15 Perform Rod Drift Alarm Test while withdrawing a Group 1 (RWM Step 1) control rod
2.19.4 Notify the on shift Lab Foreman of reactor criticality.

4.2.21 Continue to pull rods to establish a heatup rate < 100°F/hr.
(Control rod withdrawal must be performed in a manner that will avoid steady periods of ≤50 seconds on the SRM period meters.)
4.2.22 WHEN SRM/IRM overlap has been confirmed, withdraw SRM detectors as required to maintain an indicated level between 200 CPS AND 7 x 10^4 CPS.

2.23 As reactor power goes up, range up the IRM Range Switches to maintain IRM indication on recorders between 10 AND 80 on the 0-125 scale.
2.24 WHEN all operable IRM channels are above range 3 AND PRIOR to reaching range 7, fully withdraw all operable SRM detectors.
2.25 Confirm there is overlap between IRM ranges 6 AND 7, by completing Attachment 9.
2.26 To continue power ascension with any inoperable IRMs, obtain Shift Supervisor approval.
4.3 Perform alternate power level check by confirming that one main turbine bypass valve, is between 50% AND 100% OPEN.
4.5 Place the Reactor Mode switch in RUN
4.2 Initiate a Required Action Sheet to confirm the containment oxygen concentration is < 4% by volume WITHIN 72 hours after entering Mode 2 per TS 3.6.3.2.
4.30 At approximately 15% reactor power, adjust the APRMs per 34SV-SUV-021-0, APRM Adjustment To Core Thermal Power, such that each APRM reading is between 0% AND 2% greater than the power value calculated by a reactor heat balance.”

Question 18

Q

When is a rod drift test performed?

Answer

A

“34GO-OPS-001-2
ROD DRIFT ALARM TEST
1.0 During withdrawal of a Group 1 control rod while the Rod Movement Control switch is in the OUT NOTCH position, perform the following:
1.1 Take Rod Drift Alarm Test Switch to TEST AND confirm the following:
1.1.1 Full Core Display red ROD DRIFT light for the control rod being tested ILLUMINATES.
1.1.2 Annunciator ROD DRIFT, ALARMS.”

Question 19

Q

How often do you perform heatup AND pressurization checks?

Answer

A

34GO-OPS-001-2
HEAT-UP PRESSURIZATION CHECK
1.0 During heatup AND pressurization, perform the following at least once every 15 minutes

Question 20

Q

How do you perform IRM 6/7 overlap check?

Answer

A

34GO-OPS-001-2
IRM OVERLAP CHECK
1.4 Confirm that Column 3 (RANGE 7 READING) = Column 4 (RANGE 6 READING / 10) + 2 (on the 0-40 scale).

Question 21

Q

How do you perform IRM alternate power Check?

Answer

A

34GO-OPS-001-2
RM ALTERNATE POWER CHECK
Record the IRM readings below AND estimate reactor power using one of the following formulas:

For IRM Ranges 7 AND 8: % Power = (IRM Reading) x (.0212)

For IRM Ranges 9 AND 10: % Power = (IRM Reading) x (.212)

Question 22

Q

What are the indications of criticality?

Answer

A

“34GO-OPS-001-2
The following are indications of criticality:
oSRM period meters indicate a stable, positive period AND
oSRM levels are going up WITHOUT requiring additional control rod withdrawal.
When below the Point of Adding Heat, SUBCRITICAL is defined as - Multiple SRM/IRM readings continuously lowering without rod insertions”

Question 23

Q

During Startup, when do you start CBP or CP pumps?

Answer

A

34GO-OPS-001-2 (1)

Start condensate pumps as necessary to maintain booster pump suction pressure above the trip setpoint of 34(15) PSIG.
The third Condensate Pump should be started between 70 - 80% RTP, to prevent the pumps from experiencing pump cavitation AND damaging the pumps impeller AND seals.
Start condensate booster pumps as necessary to maintain Reactor Feed Pump suction pressure above the trip setpoint of 207 (145) psig.

34GO-OPS-005-2
-Prior to exceeding 2558 MWth evaluate the condensate system operation, AND start the third CBP.

Question 24

Q

What actions are required if rod movement is suspended for an extended period of time?

Answer

A

“34GO-OPS-001-2

IF ROD MOVEMENT IS TO BE SUSPENDED FOR AN EXTENDED PERIOD OF TIME, THE CONTROL RODS WILL NORMALLY BE INSERTED TO THE SUBCRITICAL HOLD POINT. THE SUBCRITICAL HOLD POINT IS INSERTING ALL RODS TO NOTCH 00 EXCEPT FOR GROUP 1 (RWM STEP 1) WHICH WILL BE LEFT AT NOTCH 48.
IF SRM/IRM OVERLAP IS NOT CONFIRMED, ROD WITHDRAWAL WILL BE HALTED. TECH SPECS WILL BE ADDRESSED TO DETERMINE IF ANY IRMS DECLARED INOPERABLE DUE TO FAILURE TO DEMONSTRATE OVERLAP WILL ALLOW STARTUP TO CONTINUE.”

Question 25

Q

What power level should not be exceeded if the MVP is in service?

Answer

A

5% as indicated on IRMs Average Power as calculated per Attachment 13 of 34GO-OPS-001-2

Question 26

Q

If the H2 injection is not in service, what power level should are you limited to?

Answer

A

“34GO-OPS-001-2
-DO NOT EXCEED 15% RTP UNLESS FEEDWATER HYDROGEN INJECTION HAS BEEN ESTABLISHED PER 34SO-P73-001-2, UNLESS APPROVED BY THE OPERATIONS DIRECTOR.”

Question 27

Q

Is entry into the Immediate Exit Region allowed and what actions are required if entered?

Answer

A

“34GO-OPS-005-2

2.3 Entry into the Immediate Exit Region is allowed during a manual OR automatic power reduction (e.g., recirc run-back) initiated in response to an equipment problem which threatens continued operation of the unit (e.g., RFPT high vibration, loss of feedwater heating, loss of condenser vacuum). Action must be taken immediately to exit the region, exceeding 10 MWe/min, consistent with the following time constraints:
- For step 5.2.3.1, a Prejob brief, peer check, and oversight is not required AND the NPOs are to IMMEDIATELY take the action to insert Control Rods per the Reactivity Briefing Sheet and current rod pullsheets.
- For Step 5.2.3.2, The initiation of action to return operation to the Analyzed Region is defined as the initiation of rod movement, within 5 minutes, for the purpose of power reduction.
2.3.2 IF the ‘Immediate Exit Region’ is entered, Within 5 minutes of entering the ‘Immediate Exit Region’, initiate actions to return operation to the Analyzed Region of the Power/Flow Map outside of the RPI.
2.3.3 Restore operation to within the Analyzed Region AND outside of the RPI within one hour after entering the Immediate Exit Regio”

Question 28

Q

What actions are required if the RPI region is entered?

Answer

A

“34GO-OPS-005-2
2.2.3.a If the ‘Region Of Potential Instabilities’ (RPI) is entered, IMMEDIATELY initiate actions to exit the (RPI) and ‘Immediate Exit Region’, to return operation to the Analyzed Region of the Power/Flow Map outside of the RPI.”

Question 29

Q

What FW flow should not be exceeded with 1 RFPT in service?

Answer

A

“34GO-OPS-005-2

5.2.4 With only one Reactor Feed Pump Turbine (RFPT) in service, DO NOT exceed approximately 7 mlb/Hr Feedwater flow. “

Question 30

Q

How many CBP should be in service based on MWth?

Answer

A

“34GO-OPS-005-2
NOTE:
Reactor Power is limited to <2558 MWt with less than three condensate booster pumps in service unless Operations Management approves otherwise. With Ops Management approval, Reactor power may be increased above 2558 MWt provided RFP suction pressure remains above 250 psig”

Question 31

Q

What is the psig rate during startup?

Answer

A

“34GO-OPS-005-2
NOTE:
• Rx Pressure increase WHEN Rx pressure is above 500 psig will be limited to < 100 psig/hour OR 1.6 psig/minute”

Question 32

Q

What are important details for final FW temp reduction?

Answer

A

“34GO-OPS-005-2
For a final Feedwater Temperature Reduction of more than 10 degrees below the Nominal Temperature Line, compliance with Limitation 2.2.13 is required.”

2.2.13 For Final Feedwater Temperature Reduction Cumulative Usage Tracking,
Refer to 34SV-SUV-020-0, Core Parameter Surveillance.

34SV-SUV-020-0
CAUTION
USE OF THIS ATTACHMENT IS APPLICABLE TO BOTH PLANNED AND UNPLANNED FFTR EVENTS. PRIOR TO PLANNED FFTR EVENTS, THIS ATTACHMENT MUST BE REVIEWED TO ENSURE THAT ENOUGH TIME EXISTS TO ALLOW THE FFTR EVENT. DURING UNPLANNED EVENTS, THIS ATTACHMENT MUST BE COMPLETED SO THAT AN ADEQUATE RECORD OF FFTR CAN BE ESTABLISHED.

Attachment 2: Check the Total FFTR Cumulative Usage Time does NOT exceed (Unit One: 45 cumulative; Unit Two: 45 cumulative) days. IF the cumulative day limit is exceeded on either unit, contact Nuclear Safety and Compliance AND Reactor Engineering for immediate corrective actions to be taken.

Question 33

Q

When is Security Notified regarding plant status?

Answer

A

“34GO-OPS-013-2

9. Operations shall notify the Security Department as soon as possible after all Reactor Mode Changes.”

Question 34

Q

During plant shutdown, per 34GO-OPS-013-2, when can IV be performed?

Answer

A

“34GO-OPS-013-2
2. The IV part of any step requiring independent verification may be performed out of sequence any time after completion of the first sign-off.”

Question 35

Q

What actions are required prior to reducing below 21% RTP?

Answer

A

“34GO-OPS-013-2
5. PRIOR to reducing Reactor power below 21% RTP, perform the following:
CRITICAL STEP
a. Using approved plant procedures, resolve all insert or withdrawal errors displayed by the Rod Worth Minimizer (RWM).
b. Request the Chemistry Supervisor to calculate new MSL Rad Monitor setpoints per 64CI-OCB-007-0.
c. Request I&C adjust the MSL Rad Monitor Hi-Hi setpoints to ≤ three (3) times normal full power background per 57SV-CAL-005-0.
d. Confirm 57SV-D11-016-2, MSL Rad Monitor FT, is current.
e. Confirm the MSL Rad Monitor Hi-Hi setpoints have been set to ≤ three (3) times normal full power background per 57SV-CAL-005-0.”

Question 36

Q

How often do you record cooldown data?

Answer

A

“34GO-OPS-013-2

During cooldown, record Data on Attachment 1 at least once every 30 minutes.
Data recording can be reduced to once per 12 hours, WHEN the following conditions are met:
• Shutdown Cooling is in service OR no fuel is in the vessel
AND
• WHEN 3 consecutive coolant temperature points taken at least 30 minutes apart, differ by less than 10°F
AND
• With coolant temperature stabilized AND in the band specified by the Shift Supervisor.”

Question 37

Q

What is the limit for H2 injection in service during shutdown?

Answer

A

“34GO-OPS-013-2
CAUTION
DO NOT DECREASE REACTOR POWER BELOW 5% WITH THE HYDROGEN WATER CHEMISTRY SYSTEM INJECTING HYDROGEN INTO THE FEEDWATER SYSTEM”

Question 38

Q

During shutdown, when are IRM range switches adjusted?

Answer

A

“34GO-OPS-013-2

WHEN Reactor power, as indicated by the APRMs, is less than 15% AND above the APRM Downscale Rod Block, place all OPERABLE IRM Range Switches on range 10.
a. As Reactor power decreases, position the IRM Range switches to keep all channels reading between 10 and 80, on the 0-125 scale.

c. Prior to switching IRM channels below range 3, position SRM detectors to maintain between 200 and 7 x 10^4 cps to prevent a rod block.”

Question 39

Q

What RWL is required to be below MSL?

Answer

A

“34GO-OPS-013-2
NOTES
• A conservative value of 100 inches RWL is used for maintaining RWL below the MSL
• Actual RWL for bottom of MSLs is 111 inches.”

Question 40

Q

What are the requirements when RWM is bypassed?

Answer

A

“34GO-OPS-065
7.3.2.8 WHEN the RWM is bypassed a second licensed Operator, OR other qualified member of the technical staff, with no concurrent duties,
shall be present at the reactor control console to concurrently verify compliance with the prescribed control rod pattern AND initial the pull sheets as each line is completed. The Shift Supervisor will appoint this concurrent verifier AND provide approval to continue rod movement.

THE RWM (WHEN NOT AUTO OR MANUALLY BYPASSED) ENFORCES ROD BLOCKS AT THE INSERT AND WITHDRAW LIMITS OF EACH BPWS ROD STEP. IF RWM PERMITS A ROD TO BE INSERTED OR WITHDRAWN PAST THE LIMITS OF THE ROD STEP (NOT WITHSTANDING A ROD DOUBLE NOTCH OR FAILED REED SWITCH), OR IF AT ANY TIME IT APPEARS THAT THE RWM IS NOT FOLLOWING ROD MOVEMENTS, THEN THE RWM MUST BE CONSIDERED INOPERABLE

WHEN performing actions directed by the Emergency Operating Procedures (specifically 31EO-EOP-103-1/31EO-EOP-103-2),
Shift Manager permission to bypass the RWM is NOT required”

Question 41

Q

How many rods can be bypassed?

Answer

A

“34GO-OPS-065
7.3.4.1 Individual rods may be bypassed in the RWM,
with the specific approval of Reactor Engineering AND the Shift Manager, providing the following conditions are met:
7.3.4.1.1 The total number of bypassed rods in the core will remain at 8 or less rods.
7.3.4.1.2 After the rod is bypassed, it must be fully inserted AND electrically disarmed.
7.3.4.1.3 The maximum number of bypassed rods in any one BPWS group is limited to 3 rods. In addition, the bypassed rods WITHIN the group are separated from each other in all directions by at least two control rod cells

The RWM will NOT allow a substitute position to be entered IF there is a functional reed switch for that rod’s position OR IF there are already eight control rods with substitute positions.
The rod will automatically be removed from the substitute rod list IF it is moved to a position with an operating reed switch OR IF its reed switch is returned to service.”

Question 42

Q

What is the definition of a mispositioned control rod?

Answer

A

“34GO-OPS-065
7.5.1 A mispositioned control rod is defined as a control rod that meets one of the following
criteria:
•A control rod found to be left in a position other than the intended position AND NOT identified/corrected before OR during the confirmations step of the rod motion instructions. [BWR, PWR]
OR
•A control rod moved more than one notch beyond its intended position.

7.5.2 IF a control rod is moved only one notch from its intended position, AND the rod is NOT at position 48, THEN the rod will be immediately returned to its correct position, the STA AND Shift Supervisor will be notified, a Condition Report submitted documenting the rod number AND drive water pressure AND a Plant Narrative Log entry made.

7.5.3 IF a control rod is moved either intentionally OR
unintentionally to position 48, a coupling check will be performed as required by Tech. Spec. by SR 3.1.3.5.

7.5.4 IF any control rod is moved to OR found to be more than one notch from its intended position, THEN immediately enter 34AB-C11-004-1/34AB-C11-004-2, Mispositioned Control Rods;
for corrective actions.”

Question 43

Q

What is the purpose of the RBM?

Answer

A

“34GO-OPS-065
RBM
An inadvertent rod withdrawal error would NOT result in a MCPR Safety Limit violation. Its function is to limit the local power increase on any given withdrawal attempt.

7.6.5 The RBM circuitry undergoes a nulling AND filtering sequence WHEN a rod is selected; therefore, a delay of approximately 5 seconds must be allowed between rod selection AND rod movement.”

Question 44

Q

How do you perform a coupling check?

Answer

A

“34GO-OPS-065
7.7.1 Preferred Control Rod Coupling Check method:
7.7.1.1 Anytime a control rod is withdrawn to the full-out position OR prior to declaring a control rod operable after work on the control rod OR CRD System that could affect coupling,
perform a ‘PREFERRED’ coupling integrity check of a control rod, by performance of either step 7.7.1.1.1 or 7.7.1.1.2:
7.7.1.1.1 Coupling Check from “48” position:
7.7.1.1.1.1 Apply a withdraw signal, by PLACING the Rod Movement Control switch to the withdraw position.
7.7.1.1.1.2 Confirm the withdraw logic actuates,
by ILLUMINATION of the red withdraw light.
7.7.1.1.1.3 Confirm the rod attempts to move,
by a momentary loss of the “48” position indication.
7.7.1.1.1.4 Confirm annunciator ROD OVERTRAVEL (603-248) is NOT received.”

Question 45

Q

Who can waive IVs or Surveillances?

Answer

A

NMP-GM-005-002
4.2.3 1. c. (2) Exemption – The Shift Manager may waive verification requirements for ALARA concerns. Alternate verification techniques SHALL be considered.

“34GO-SUV-001-0 Control and Surv of Locked Valves and Breakers
5.2.1 WHEN significant health/safety hazards (e.g., high radiation, high temperature, etc.) are likely to be encountered during performance of Independent Verification, the verification can be waived by the Shift Supervisor. However, in these situations, an alternate means for independent verification that does NOT involve exposure to hazards shall be used, IF available. Any independent Verification that is waived shall be documented per step 7.2.3.1.1.

5.2.2 WHEN significant health/safety hazards (e.g., high radiation, high temperature, etc.) are likely to be encountered during performance of surveillance, surveillance can be waived by the Shift Supervisor. Document waived surveillance per step 7.3.4.1.”

Question 46

Q

What steps are needed for Process Computer if it is out-of-service?

Answer

A

34GO-OPS-022-0
4.2.3 1. IF the value for CTP from process computer is NOT available,
a manual Core Heat Balance in accordance with 34SV-SUV-025-0, Core Heat Balance, will be performed three times per shift at a delta shift time of approximately 3 hours, 7 hours AND 11 hours to confirm that CTP is less than or equal to 2804 CMWT for Unit 1 or Unit 2.

CAUTION If calculated RTP falls below 2777 CMWT, power may not be restored above 2777 CMWT.

4.2.3 2. 2. IF manually calculated CTP is greater than 2777 CMWT,

a. The Operator will determine the time that the process computer was lost (Crossflow system correction factors NOT in use),
AND report this to the SS for compliance with TRM 3.3.14,

b. For the period up to 72 hours, the Operator will make recirculation flow changes as necessary to maintain CTP less than or equal to 2790 CMWT AND greater than 2777 CMWT,

c. PRIOR to exceeding 72 hours,
lower recirc flow as necessary to reduce CTP to
less than or equal to 2777 CMWT. (Reference TRM T 3.3.14)

“34GO-SUV-025-0
IF the Process Computer is out-of-service, the percent of RTP calculated on Attachment 1 OR Attachment 2, must match each of the APRM readings WITHIN + 2% of RTP. IF it does NOT, THEN adjust APRM Gains per 34SV-SUV-021-0, APRM Adjustment to Core Thermal Power.

IF the Process Computer is in service, the values calculated by the Process Computer Core Power and Flow Log MUST match the manually calculated components of the heat balance WITHIN the tolerances specified for each parameter as noted in the Comparison Calculation section of Attachment 1 or Attachment 2.”

Question 47

Q

What is considered acceptable preconditioning?

Answer

A

"AD-ADM-30-1209
Acceptable Preconditioning (of SSCs): Preconditioning based on the equipment manufacturer’s recommendations or on industry-wide operating experience to enhance equipment and personnel safety but not to influence the outcome of the test. Preconditioning for purposes of personnel protection or equipment preservation should outweigh the benefits gained by testing only in the as-found condition. This preconditioning must be evaluated and documented in advance of the surveillance.

Preventive maintenance should not be deliberately scheduled just prior to a surveillance interval test for purposes of assuring testing success.

Repetitive testing to achieve acceptable test results without identifying the cause or correction of any problem in a previous test is NOT acceptable to establish or confirm operability and may constitute “preconditioning”.

Tech Spec required periodic venting of equipment not routinely scheduled prior to the surveillance testing is acceptable.

Pump venting or draining directly prior to surveillance is acceptable provided a Technical Evaluation is performed to establish the amount of gas vented would not adversely affect the pump operation.

Except where there is a need to protect personnel or prevent equipment damage, preventive maintenance should not be performed before TS surveillance testing.

Do not routinely schedule TS surveillance interval tests after maintenance activities so the surveillance test can also serve as the post maintenance test.

It is acceptable preconditioning to run the prelube oil pumps prior to EDG starts. Unacceptable Preconditioning activities should not to be routinely scheduled within 25% of the time period prior to the associated surveillance interval due date.”

Question 48

Q

What are the reporting requirements for various times?

Answer

A

“NMP-AD-031
Discovery date is generally the date when the event was discovered

If more than one reporting requirement is applicable, duplicate reports are not required.

Verbal communications with the Resident Inspector or other NRC staff do not satisfy the reporting requirements

15-Minutes
•Notify State and local government agencies, in accordance with the Emergency Plan, within 15 minutes of declaring an emergency class.
•Emergency response and accident mitigation information shall be provided within 15 minutes of receiving the accident notification.

1-Hour
• Notify NRC Operations Center as soon as practicable and within 1 hour of the occurrence of any deviation from the plant’s Technical Specifications authorized pursuant to Sec 50.54(x)
• Notify the NRC Operations Center via the ENS of the declaration of any of the Emergency Classes specified in the Emergency Plan immediately after notification of the appropriate State or local agencies and not later than one hour after the time the licensee declares one of the Emergency Classes.

4-Hour
• The initiation of any nuclear plant shutdown required by the plant’s Technical Specifications (that occurred within 3 years of the date of discovery
• Any event or condition that results in actuation of the reactor protection system (RPS) when the reactor is critical except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation.

8-Hour
• Any event or condition that results in the condition of the nuclear power plant, including its principal safety barriers, being seriously degraded; or the nuclear power plant being in an unanalyzed condition that significantly degrades plant safety.
• Any event or condition that results in valid actuation of any listed system except when the actuation results from and is part of a preplanned test
o General containment isolation signals affecting containment isolation in more than one system or multiple main steam isolation valves.
o ECCS including Core Spray, HPCI, and RHR
o RCIC
o Containment heat removal and depressurization systems including containment spray and fan cooler systems
o Emergency AC electrical power systems – EDGs
• Any event or condition that at the time of discovery could have prevented the fulfillment of the safety function of structures or systems that are needed to:
(A) Shut down the reactor and maintain it in a safe shutdown condition;
(B) Remove residual heat;
(C) Control the release of radioactive material; or
(D) Mitigate the consequences of an accident
• Any event requiring the transport of a radioactively contaminated person to an offsite medical facility for treatment.
• Any major loss of emergency assessment, offsite response or offsite communications capability
• Any event that results or should have resulted in emergency core cooling system (ECCS) discharge into the reactor coolant system as a result of a valid signal except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation
• Any event or condition that results in actuation of the reactor protection system (RPS) except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation
• Any event or situation related to the health and safety of the public or onsite personnel, or protection of the environment, for which a news release is planned or notification to other government agencies has been or will be made

Question 49

Q

What qualifies for an editorial change?

Answer

A

“NMP-AP-001
Editorial Change – In order to be considered an editorial change, the proposed change MUST fit one of the examples listed in Attachment 1, Editorial Changes.
a. Misspellings
b. Incorrect sequence of step numbers (e.g., 6.3.1, 6.3.3, and 6.3.2)
d. Corrections to procedure section or subsection titles
f. Errors in component numbers or nomenclature that can be verified against another occurrence in the same procedure, or controlled plant documents (e.g., Battery Charger 4A2, instead of Battery Charger 4B2)
h. Corrections to plant organizations, descriptions, and personnel which are in agreement with the FSAR or Technical Specifications as appropriate
j. Word processing or proofreading errors evidenced by original documents”

Question 50

Q

What is the definition of a pen and ink change?

Answer

A

NMP-AP-001
Pen and Ink Change - A change made to an existing procedure due to an emergent issue that meets the criteria for an editorial procedure change.

The intent of a procedure is considered to be changed IF wording or steps are added or deleted which cause:
1. A change in the purpose or scope of the procedure.

Question 51

Q

What documents require placekeeping and which steps?

Answer

A

NMP-AP-003

NOTE
Circle-Slash place-keeping is not required for a document or portion of a document that is used SOLELY TO RECORD DATA (e.g., Operator Rounds, attachments to surveillances); in these cases, the data itself functions as a form of place-keeping.

7.1. Place-keeping shall be applied to the following documents:
a. Continuous Use documents
b. Transient Response Procedures
c. Reference use procedures
d. Work Order Instructions
e. Clearance hang/remove/temp lift Checklists
f. When directed by the Supervisor, Information Use Procedures or other administrative type procedures.

CONTINUOUS USE
• Perform placekeeping as described in Section 4.7.
• Placekeep all precautions, limitations, prerequisites, notes, cautions, warnings, and steps, including list bullets

REFERENCE USE
• Perform placekeeping as described in Section 4.7.”
• REFERENCE USE procedures which operate Plant components shall be TREATED as Continuous Use instructions and place kept as such.

Question 52

Q

Which licensing document allows for a license to take reasonable action that departs from tech specs?

Answer

A

“NMP-AP-002
Per 10 CFR50.54(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.”

Question 53

Q

What are the requirements for fire brigade?

Answer

A

“NMP-ES-035-010
The Fire Brigade SHALL consist of a minimum of five qualified persons on each shift. A minimum of three of these persons MUST have competent knowledge of safety-related systems and components to understand the effects of fire and fire suppressants on safe shutdown capability. One of these will be the Fire Brigade Leader.

The Shift Manager (SM) will assign a qualified individual to act as Fire Brigade Leader.

A qualified Fire Brigade member, more than the minimum of five qualified persons on each shift may function in any role designated by the FBL.”

Question 54

Q

What is the definition of a critical step?

Answer

A

NMP-AP-003
Critical Step – A procedure step, series of steps, or action that, if performed incorrectly, will cause irreversible harm to plant equipment or people or will significantly impact plant operation.

Question 55

Q

What is considered a high rad area?

Answer

A

NMP-HP-302
High Radiation Area (HRA) - Any area, accessible to individuals, in which radiation levels from radiation sources external to the body could result in an individual receiving a dose equivalent in excess of 100 mrem in 1 hour at 30 centimeters from the radiation source.

Question 56

Q

What is considered a hot spot?

Answer

A

“NMP-HP-302
Hot Spots - Accessible components or items having contact readings in excess of > 100 mrem/hr and more than five (5) times the general area dose rate (typically 30 cm from the source). If the contact dose rate does not meet the criteria for a Hot Spot but is still at least five (5) times the general area dose rate it can be posted.”

Question 57

Q

What is considered a locked high rad area?

Answer

A

NMP-HP-302
Locked High Radiation Area (LHRA) - Any area accessible to individuals in which deep dose equivalent rates are greater than or equal to 1 rem/hr (but less than 500 rads/hr at 1 meter) 30 centimeters from the source of radiation.

Specific RWPs govern entry into LHRAs
Shall remain locked at all times except for periods of access by personnel under an approved RWP
RP escort is not explicitly required for each entry…
When door is locked closed, a peer check on the lock is required. This can be an operator

Question 58

Q

What is considered a radiation area?

Answer

A

NMP-HP-302
Radiation Area – Any area accessible to individuals, in which radiation levels could result in an individual receiving a dose equivalent in excess of 5 mrem in one hour at 30 centimeters (e.g., approximately 12 inches) from the radiation source.

Question 59

Q

What are the main shift supervisor responsibilities per the conduct of operations?

Answer

A

NMP-OS-007
SS is responsible for the safe and efficient operation of the assigned unit
• SS approval must be obtained prior to conducting any evolutions or testing that affect core reactivity
• Approve the removal of equipment and systems from service for maintenance, testing or operational activities
• SS Walks down the control boards and control room displays at turnover and at least once during the shift (preferably with the UO/OATC) to verify component position and system parameters. This walk-down should be recorded in the unit control log.(verified current version 17.0)
• Gives permission to start Infrequently Performed Tests and Evolutions in accordance with NMP-AD-006.
• Reviews AND approves the Unit Control Log for the assigned unit. The off-going SS will make a log entry stating that they have reviewed the log and that the log clearly and accurately reflects the status of the unit and the activities that occurred during the previous shift. (NMP-OS-007-008 3.3.4)

Question 60

Q

Whose approval is needed prior to affecting core reactivity?

Answer

A

“NMP-OS-001

SS approval must be obtained prior to conducting any evolutions or testing that affect core reactivity

Question 61

Q

What are the main shift manager responsibilities per the conduct of operations?

Answer

A

“NMP-OS-007
Shift Manager is the senior management representative on
shift and has primary responsibility for the safe operation of the facility.
• Reports to the MCR when notified by the SS of:
o Unplanned LCO entry <72hours
o AOP/EOP entry
o Any time decision is being made in knowledge base instead of rule base in response to a failure or transient
• The Shift Manager maintains awareness by walking down control boards and displays on a frequency no less than once per shift. This walk-down should be recorded in the unit control log.
• Declares emergencies per the plant Emergency Plan. The ED has the following non-delegable duties:
o The decision to declare, escalate, or terminate emergency classifications.
o The decision to notify offsite emergency response agencies.
o The decision to recommend protective actions to offsite authorities.
o The decision to request federal assistance.
o Authorization for plant personnel to exceed 10CFR20 radiation exposure limits.
o Authorization for use of potassium iodide (KI) tablets during a declared emergency.
o The decision to dismiss nonessential personnel from the site at an ALERT or higher emergency classification.
• Responsible for the oversight of planned and unplanned risk changes
• Gives permission to start Infrequently Performed Tests and Evolutions in accordance with NMP-AD-006.

Question 62

Q

What is a critical parameter?

Answer

A

NMP-OS-007-001
Critical Parameter - Any parameter that the Shift Supervisor has determined will merit heightened awareness and will require a specific response from the crew or plant systems at a certain parameter value such as:
• parameters not under the normal control of automatic systems
• parameters not being controlled in the expected band by automatic systems
• parameters not being maintained in the expected band due to plant transient or degraded equipment

Question 63

Q

What are the OATC responsibilities per conduct of operations?

Answer

A

“NMP-OS-007
OATC
• Prevent challenging the automatic safety systems by taking action to manually initiate ESF actuations if the established critical parameter limits are exceeded and automatic actuation setpoints are threatened.
• Ensure the reactor is shut down when
o Safety of the reactor is in jeopardy, or
o Operating parameters exceed any of the reactor protection system trip set points and automatic reactor trip does not occur, or
o Personnel or equipment safety require it, or
o Unusual circumstances warrant it.
• Walks down the applicable portions of the control boards and control room displays at turnover and at intervals throughout the shift (mid-shift, and after system manipulations are recommended) to monitor component position and system parameters, these walkdowns include the following panels:
a. (Farley, Hatch, Vogtle 1-2) Normally OATC-Front Panels, UO-Back Panels.

Question 64

Q

What is a key parameter?

Answer

A

NMP-OS-007-001

Key Parameters - A set of pre-identified parameters that have been determined to provide the most margin to reactor core safety WHEN maintained within established bands.

BWR
• Reactor power 
• Reactor pressure
• Reactor water level
• Containment parameters

Answer 65

A

NMP-OS-007-001

All alarms treated as valid until proven otherwise
When performed planned activities, operators anticipate alarms caused by that activity and will preview the ARP for those alarms, for any required response.
Cleared alarms are not required to be communicated
Normally all MCR alarms should be communicated during non transient conditions. (May group as single communication)

Answer 66

A

NMP-OS-007-001
During transient conditions alarms may be used to help establish priorities and it is understood that all ARPs are consulted immediately.
o If alarm is indicative of NEW or unknown issue, the alarm should be communicated commensurate with the significance of the issue

Un-expected alarm response is as follows (inclusive of MCR or Local alarm panels):
o Silence and/or acknowledge the alarm, IF applicable.
o Communicate the alarm to the appropriate supervisor/watch-stander/area.
o The responding operator references and implements the alarm response procedure as applicable.
o WHEN multiple alarms are received simultaneously, the responding operator silences and/or acknowledges the alarms. IF the cause is understood (diagnosed), the responding operator announces the cause of the alarms. ARP usage is prioritized.

Answer 67

A

NMP-OS-007-001
Expected Alarms response is as follows:
• PRIOR to alarm actuation operators:
1. PREVIEW all associated ARPs and other procedures (e.g. SOPs).
2. As appropriate, FLAG alarms in advance which are anticipated to occur multiple times or at relatively high frequency during pre-planned evolutions.
3. COMMUNICATE the pending alarm to the appropriate station/area personnel

•WHEN the expected alarm is actuated, the operator will:

Ensure compensatory actions are performed per the appropriate ARP or other procedure (e.g. an SOP).
If there are no compensatory actions required, then the ARP is not required to be referenced again after the alarm is actuated (it was referenced prior to actuation).
Ensure the appropriate station/area personnel received the alarm as expected.

Per 31GO-OPS-014-0, Expected Annunciator Flags (EAFs) are limited in duration to the time remaining on the shift during which they were placed on the expected annunciator(s) OR for the duration of a Unit or System Outage at the discretion of Operations Supervisory personnel.

Answer 68

A

NMP-OS-007-001
o Re-flash (become active, clear, and reoccur) often due to an actual plant condition or indication failure or Seal-in (remain active) or re-flash at a longer frequency due to alarm system failure where the actual plant condition does not exist.
o After the initial alarm response, the Alarm Response Procedures are to be referenced once per shift for any nuisance alarm. Compensatory actions may be required as determined by the Shift Supervisor
o Nuisance alarms may be silenced, left flashing, and flagged to assist the operators in alarm management

Answer 69

A

NMP-OS-007-001
• Used during abnormal or emergency situations to ensure control room team members have a shared understanding of the events in progress. May be used in non-emergency conditions as well.
• Used for quick dissemination of plant status changes and priorities.
• A pause in the briefing is taken to respond to alarms or manipulate controls, however it is permissible to silence and not implement ARP actions until completion of the brief during a transient.
• Orders and directives are not given during Crew Briefs…therefore no repeat backs are used during Crew Briefs

Answer 70

A

NMP-OS-007-003
Night Orders – Operations related information or orders issued by an Operations Manager/Shift Manager or designee to provide instructions to be carried out during backshifts, weekends, holidays, etc. Night Orders MUST NOT deviate from or change the intent of existing plant operating procedures nor do they deviate from other plant design or regulatory documents.

Night Orders are valid for 72 hours. (< 6 whole 12hr shifts)
Only ONE active night order at a time.
SS and SM shall review night orders to ensure they are carried out.

Answer 71

A

NMP-OS-007-003
Standing Orders – Temporary instructions issued to plant operating personnel. They address subjects NOT covered by existing plant operating procedures. Standing Orders MUST NOT deviate from, or change the intent of existing plant operating procedures, nor do they deviate from plant design or regulatory documents.

A standing order log will be maintained to track Standing Orders issued throughout the year
Standing Orders are maintained electronically, and a paper copy may be maintained in MCR

• Standing Orders containing directions to manipulate the plant shall only include directions to perform actions bounded by current approved procedures.
o If there is a conflict between a standing order and published plant procedure, the plant procedure will prevail in all cases.
o Standing orders may direct early actions or initiate additional monitoring of plant equipment.
o Standing Orders are approved by an Operations Manager or Shift Manager Standing Orders are reviewed monthly and any that have been in effect for greater than 6 months shall be evaluated for conversion to a procedure.

Answer 72

A

NMP-OS-007-008
The logs required to be reviewed are those generated since the last shift worked OR the last 24 hours, whichever is the least.

Narrative Logs Contents
All pertinent data, alarms, actions taken, plant response, and indications are recorded in the appropriate operator log(s) to allow reconstruction of plant operations and events

When directing other departments to perform required actions, such as technical specifications, operability determinations, or other actions needed

At the end of each shift, the logs should be reviewed and approved by the applicable SS

Answer 73

A

NMP-OS-007-013
The minimum shift crew composition shall be in accordance with 10 CFR 50.54. Shift crew composition may be less than the minimum requirement for a period of time not to exceed 2 hours in order to accommodate unexpected absence of on duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

This is not by position, this is crew composition as a whole.

Example:
0100 - RO leaves sick (below min staffing time starts)
0145 - SRO gets called away from the plant (still below min staffing)
0200 - Replacement RO arrives on site (still below min staffing)
0315 - Replacement SRO arrives on site (staffing meet)

Total time min staffing not met was from the initial RO leaving until the SRO arrives. 2 hours 15 min. This would be a violation of min staffing.

Answer 74

A

NMP-OS-007-008
The SM, SS, and Control Room Operators (OATC is responsible) must review entries prior to taking the shift. The logs required to be reviewed are those generated since the last shift worked OR the last 24 hours, whichever is the least.

Answer 75

A

NMP-OS-007-013

Normal shift scheduling shall be a minimum of 5 SROs

The FBL and STA function cannot be combined

When there are only 4 SROs on a shift the ED and STA functions can be combined. However, the crew must be prepared to combine the ED and STA functions if a control room evacuation is required coincident with activation of the fire brigade.

EP Staffing -

Shift Manager (SM) / Emergency Director (ED)
Unit 1 Shift Supervisor (SS)
Unit 2 Shift Supervisor (SS)
Shift Technical Advisor (STA) (Can be combined with SM or SS)
Fire Brigade Leader / Shift Support Supervisor (SSS)
Safe Shutdown Designated personnel (7)
a. 4 NPOs
b. 3 SOs (Could be covered by extra NPOs)
Fire Brigade (4) (Generally SOs)
Chemistry Tech (2)
RP Tech (3)

This provision does NOT permit any shift crew position to be unmanned upon shift change due to an oncoming shift crewman being late or absent. If necessary, out-going shift personnel should be held over, making use of a part 26 waiver, to ensure all required EP positions remain covered.

Answer 76

A

NMP-ES-035-010

The Fire Brigade SHALL consist of a minimum of FIVE qualified persons on each shift.

A minimum of THREE of these persons MUST
have competent knowledge of safety-related systems and components to understand the effects of fire and fire suppressants on safe shutdown capability.

One of these will be the Fire Brigade Leader.

The Shift Manager (SM) will assign a qualified individual to act as Fire Brigade Leader.

A qualified Fire Brigade member, more than the minimum of five qualified persons on each shift may function in any role designated by the FBL.

Answer 77

A

34GO-OPS-013-1/2

If Secondary Containment is not operable, Primary Containment must be verified operable in order to remain in Mode 3,
Any entry into Mode 3 using this TS allowance must be limited to no more than 7 days,
Although not mandatory, the plant should attempt to reduce pressure to less than 500 psig within 12 hours after entering mode 3. Risk should be assessed for those periods of time that the plant is above 500 psig after 12 hours in mode 3.

Answer 78

A

NMP-OS-007-013
The shift crew composition may be less than the minimum requirement of 10CFR50.54 (m)(2)(i) and Tech. Spec. for a period of time not to exceed 2 hours in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

10CFR50.54 (m)(2)(i)
• At least one unit operating the minimum personnel is 2 SRO’s, 3 RO’s, 3 NLO’s and 1 STA.
• Neither unit operating (Mode 4 or 5) the minimum personnel is 1 SRO, 2 RO’s, 3 NLO’s, 0 STA.
• Note these numbers do not include EP, Fire Brigade or Fuel Movement SRO requirements.

TS 5.2.2

a. A total of three plant equipment operators (PEOs) for the two units is required in all conditions. At least one of the required PEOs shall be assigned to each reactor containing fuel.
b. At least one licensed Reactor Operator (RO) shall be present in the control room for each unit that contains fuel in the reactor. In addition, while the unit is in MODE 1, 2, or 3, at least one licensed Senior Reactor Operator (SRO) shall be present in the control room.

Answer 79

A

An area having smearable contamination equal to or greater than 1000 dpm/100 cm² beta/gamma or 20 dpm/100 cm² alpha

Answer 80

A

Continuous Use – Reading each step of the document prior to performing that step, performing each step in the sequence specified and place-keeping each step as complete before proceeding to the next step.

Reference Use - Referring to a document periodically during the performance of an activity to check that all segments of an activity have been performed, each step has been performed in the sequence specified and, where required, are documented.

Information Use – An activity may be performed from memory, but the document is available, not necessarily at the work location, for use as needed to ensure the task is being performed correctly.

Answer 81

A

SS is responsible for the safe and efficient operation of the assigned unit
• SS approval must be obtained prior to conducting any evolutions or testing that affect core reactivity
• SS Walks down the control boards and control room displays at turnover and at least once during the shift (preferably with the UO/OATC) to verify component position and system parameters. This walk-down should be recorded in the unit control log.
• Gives permission to start Infrequently Performed Tests and Evolutions in accordance with NMP-AD-006.

Answer 82

A

Use of Not Applicable (N/A)
Steps without conditional statements or specified conditions may be marked N/A, if ALL the following criteria are satisfied:
• The step is NOT needed for the current mode, condition, or configuration of the plant.
• The intent (method of operation or the results) of the steps or sections does NOT change.
• The initial conditions, precautions, or prerequisites sections are NOT violated

N/A is NOT to be used to bypass steps that are inadequately or improperly written and is NOT to be used in lieu of an approved change.

Steps that contain conditional statements or provide specific conditions for being marked as NOT applicable may be marked N/A without additional written justification or supervisory approval.

Answer 83

A

Prior to any entry, a containment entry tagout to ensure Nitrogen has been isolated to the primary containment is required prior to entry.
• DW Pneumatics
• RB Instrument Nitrogen to Non-Interruptible Air Valves
• Nitrogen Tip Purge
The containment entry tagout will also prevent Control Rod Withdrawal in Modes 1 or 2 and TIP Operation.

Instrument Air must be available to DW Pneumatics

Answer 84

A

31GO-OPS-014-0
Annunciators/recorder points deactivated/bypassed per another controlling document (i.e., other procedures, DCRs, LDCRs, and DCPs), will only be tracked per 31GO-OPS-014-0. Any required Applicability Determinations (AD) and 10CFR50.59 Screening / Evaluations / reviews will have been performed by the other process. If the other process is to be in place greater than three months for a required annunciator, then the associated AD and 10CFR50.59 screening will be attached to the APC sheet

Any APC sheet for a pulled annunciator card or bypassed point that has been active for greater than three months (90 days) or will be active greater than three months prior to the next periodic review, will be sent to Engineering Support Supervision to have an AD and 10CFR50.59 performed for those APC sheets.

The SS shall assign required Compensatory Action as per the requirements of this procedure. The SM will review and approve the Compensatory Actions.

The SS shall ensure Compensatory Action(s) is(are) performed at the frequency assigned on the APC Sheet, OPS-1468
Whenever an APC Log entry has been made and an APC Sheet written, THEN INSTALL an APC blank YELLOW magnetic tile beside the annunciator number label under the Annunciator window AND/OR a TM Tag on the associated recorder or plant component, if any. The TM Tag is to give the APC Sheet number and otherwise identify it as associated with an APC Sheet. Later, at step 38, if it is a deactivated annunciator the YELLOW magnetic blank tile will be replaced with a YELLOW magnetic “P” tile beside the Annunciator number label under the Annunciator window. The YELLOW “P” tile will signify that the annunciator has been “pulled”. Also, for APC sheets initiated for annunciators, place a label in the top right hand corner of the ARP with the given APC Sheet number (e.g. 1-05-025).

If the condition is a distraction to the operating crew or it is masking a problem, the SM and SS can determine if it is necessary to deactivate/bypass the annunciator without PRB approval. This starts a 14 day clock to determine if PRB/Plant Manager approval is needed on safety related equipment.

APC Logbook reviews:

Review EACH SHIFT to ensure compliance with Comp Actions and to ensure all entries are still required.
Review MONTHLY to ensure compliance with this procedure
Review MONTLY to ensure that APC sheets older than TWO MONTHS have a CR generated requesting an Applicability Determination and 50.59 for recommendations for permanent resolution
Review MONTLY to determine if any APCs older than 3 months do not have a 50.59 screening
Review MONTLY to determine if an APC is older than 6 months. IF so, report to Operations Supervision and Reg Affairs

Answer 85

A

Before reaching the Point of Adding Heat - Multiple SRM/IRM readings continuously lowering without rod insertions.

OR

After reaching the Point of Adding Heat - Multiple SRM/IRM readings continuously lowering without rod insertions.
AND
Multiple IRM’s have been down ranged at least two ranges below the levels established when initially at the Point of Adding Heat.

Answer 86

A

34GO-OPS-065
5.2.1 The Emergency in function may be used only
To prevent or correct a rod double notch in the OUT direction or
• as specified by 34AB-C11-004, “Mispositioned Control Rods” or
• as specified by 34AB-C11-003, “Inability to Move a Control Rod: or
• as specified by 31EO-EOP-103, “EOP Control Rod Insertion” or
• as specified by 34AB-C11-005, “Control Rod Insertion Methods”

Answer 87

A

Transient Response Use- a special sub-category of Continuous Use procedures, however due to their design and purpose have special usage allowances for variations to Continuous Use rules. These variations include:
• A version check variation
• A step sequence variation (e.g. Early operator actions, Fold-out page actions)
• A procedure in hand variation (e.g. Reader-Doer)
• A step progression variation
• A performing step from memory (e.g. Immediate Actions, manual backup of auto-actions) allowance.
• A procedure conflict variation (e.g. standard prioritization which does NOT prevent progression through the procedure)
• A procedure alteration protocol (variance).

Answer 88

A

Declared Pregnant Worker
• Declaration is voluntary
• 450mrem/term
• 500mrem/term is federal limit

Answer 89

A

On site Admin Limit is 2000mrem TEDE for current year
• Approval to extend to 4000mrem TEDE for current year given by RP Supervisor and Individual’s Supervisor
• Plant Manager can approve extensions to 4500 mrem TEDE for current year
• Site Vice President can approve up to 5000 mrem (Federal Limit) TEDE for current year

Answer 90

A

Temporary Configuration Change (TCC)- A temporary alteration made to systems, structures, or components that DOES NOT conform to the approved design configuration. TCCs are made to address degraded conditions, implement temporary repairs, and support short-term operational needs and one-time plant evolutions.
• Temporary Modifications – A short term alteration made to systems, structures or components that is not controlled by procedure or work instructions. (Temporary setpoint changes, installed or removed filters, electrical circuit alterations, temporary fans or heaters)
• Procedurally Controlled TCCs – A temporary plant alteration REQUIRED for the performance of an approved procedure and addressed entirely in that procedure
• TCC in Support of Maintenance – A temporary configuration change that directly supports a maintenance activity that is developed and implemented in work instructions (routine instrument or relay calibrations, installing jumpers, positioning of components for a tagout, pulling annunciator cards for a single annunciator)

Answer 91

A

Emergent TCC – A TCC needed immediately to eliminate a threat to the safety of personnel or facilities

Answer 92

A

PLANT REVIEW BOARD (PRB)
• Reviews and approves TMs that affect Nuclear Safety per NMP-GM-009, Plant Review Board Charter.
• Approves TCC extensions past refueling outage

SHIFT MANAGER
• Determines if Emergent TCCs are needed
• Authorizes installation of Emergent TCCs

Answer 93

A

Exclusion from the TCC Process - Some operational activities that involve changing or manipulating equipment are NOT considered to be TCCs as described in this document. Exclusions are tagged and controlled per the appropriate station procedure(s) for implementing the change. Examples are as follows:
• Operations clearances (tagouts) established for the protection of personnel and equipment installed in accordance with the station clearance and tagging procedures, including isolation of equipment using system or component design features such as removing fuses, spectacle flanges, and permanently installed bypass/defeat mechanisms.
• Admin controls to place functions in a tripped condition to comply with tech spec actions statements
• Connections of portable tools to permanently installed electrical outlets, air drops, or demin water connections for short durations

Answer 94

A

The TM tag color is purple with a white diagonal stripe.
• Tags are required for all TCCs except procedurally controlled TCCs if worker remains in the area and there is no interruption in the work and leads can be easily identified to prevent landing error.

Answer 95

A

During Control Rod Manipulations:
A plant page will be made prior to and approximately every 30 minutes during. A page will be made upon completion of manipulations.

Answer 96

A

Reactivity Management SRO supports the Shift Supervisor during significant planned reactivity maneuvers (>20% power change) or at the discretion of the Shift Manager. The Reactivity Management SRO is cognizant of the reactivity plan, keeps the Shift Supervisor informed of reactivity manipulations, and maintains oversight of reactivity manipulations.
• During Reactor startup the Reactivity Management SRO is required from the start of control rod withdrawal until all of the following conditions are met:
o Reactor is stable at greater than 10%
o Shift Manager agrees that the Reactivity Management SRO is no longer needed.

Answer 97

A

All communications with the load Dispatcher will be documented in the Unit Control Log or GenComm
Whenever plant conditions require a load change, the Load Dispatcher shall be notified as soon as possible of the proposed load and rate of change using GENCOM and verbally via phone call if practicable.

Answer 98

A

LARGE EARLY RELEASE FREQUENCY (LERF) - A measure that predicts the likelihood of the number of accidents (significantly less than one) in one reactor year that would cause a large release of radioactive material to the environment prior to offsite protective measures being taken.

Answer 99

A

CORE DAMAGE FREQUENCY (CDF) - CDF is a measure that predicts the likelihood of the number of accidents (significantly less than one) in one reactor year that would cause damage to the reactor core.

Answer 100

A

Approvals
SVP approves voluntary entry into RED conditions
PM approves voluntary entry into ORANGE conditions
SM approves voluntary entry into a YELLOW condition

Answer 101

A

NMP-OS-026

5.2
a. Maintenance of an active license REQUIRES that an individual spend seven (7) eight-hour shifts or five (5) twelve-hour shifts in a position that requires the license per the Technical Specifications (i.e., OATC, UO, SS, SM, or SRO during Core Alterations as defined in Technical Specifications) in a calendar quarter.
b. IF an individual stands a combination of complete 12 or eight-hour shifts that total 56 hours in the quarter, THEN this requirement is satisfied. A shift of less than eight (8) hours DOES NOT count toward the 56-hour total.
c. In order to maintain the Supervisory portion of the SRO license active, a SRO MUST stand at least one (1) complete watch per calendar quarter in an SRO-only supervisory position. The remainder of complete watches required in a calendar quarter may be performed in either a credited SRO or RO position.

The STA position is maintained IAW NMP-TR-421

1.4 1. Proficiency for the dual-role STA (Option 1 of 50 FR 43621) is satisfied by maintaining SRO proficiency.
1.4 3. Each STA SHALL be evaluated annually performing the STA function in a simulator scenario.
1.4 4. Each STA SHALL maintain satisfactory performance in the LOCT and STA Continuing Training Programs.

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