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0. Biennial Written Prep > Pre-Test Review > Flashcards

Pre-Test Review Flashcards

1
Q

Source Range High Flux reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 90,000 CPS
  • 1/2 Source Range Counts
  • P6
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2
Q

Intermediate Range High Flux reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 22.5 (20) % RTP
  • 1/2 Intermediate Range Indicators
  • P10
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3
Q

Power Range High Flux, low reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 20% RTP
  • 2/4 Power Range Indicators
  • P10
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4
Q

Power Range High Flux, high reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 107% RTP
  • 2/4 Power Range Indicators
  • None
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5
Q

Power Range High Positive Rate reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 4.5 % in 2 sec
  • 2/4 Power Range Indicators
  • None
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6
Q

OTDT reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Variable
  • 2/4 OTDT Indicators
  • None
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7
Q

OPDT reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Variable
  • 2/4 OPDT Indicators
  • None
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8
Q

Pressurizer Pressure High reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 2385 psig
  • 2/4 Pressure Channels
  • None
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9
Q

Pressurizer Pressure Low reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 1950 psig
  • 2/4 Pressure Channels
  • P7
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10
Q

Pressurizer Level High reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 92%
  • 2/3 Level Channels
  • P7
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11
Q

RCS Loss of Flow reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 91% 2/3 Flow Channels on 1/4 loops (>P8)

- 91% 2/3 Flow Channels on 2/4 loops (P7)

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12
Q

RCP Bus Undervoltage reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 88 Volts
  • 1/2 on 2/4 busses
  • P7
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13
Q

RCP Bus Underfrequency reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 58.2 Hz
  • 1/2 on 2/4 busses
  • P7
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14
Q

RCP Breaker Position reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Open Auxiliary Switches
  • 2/4
  • P7
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15
Q

Steam Generator Water Level Lo-Lo reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 5 (22) %
  • 2/3 Level Channels on 1 out of 4 Steam Generators
  • None
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16
Q

Steam Generator Water Level Lo w/ Feed < Steam reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 15 (26) % level AND 0.71E6 (1.47E6) lbm/hr
  • 1/2 level channels on 1/4 Steam Generators AND 1/2 flow channels on the same Steam Generator
  • None
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17
Q

Safety Injection reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Either Train
  • N/A
  • None
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18
Q

Turbine Trip reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Oil press < 800 psig OR Stop Valves 1%
  • 2/3 Oil Channels OR 4/4 Stop Valve Limit Switches
  • P8
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19
Q

Manual reactor trip:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Manual Switches
  • 1/2
  • None
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20
Q

Manual SI actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • N/A
  • 1/2 per train
  • None
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21
Q

Containment Pressure High SI actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 1.0 psig
  • 2/3 Pressure Channels
  • None
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22
Q

Pressurizer Pressure Low SI actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 1775 psig
  • 2/3 Pressure Channels
  • P11
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23
Q

Steam Line dP SI actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 100 psid
  • 2/3 Pressure Channels on 1 SG lower than 2 other SGs
  • None
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24
Q

Steam Generator Pressure Low SI actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 500 psig
  • 1/1 Pressure Channels on 2 SGs
  • P12
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25
Q

Manual Containment Spray actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • N/A
  • 1/1 per Train
  • None
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26
Q

Containment Pressure High High Containment Spray actuation:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 2.8 psig
  • 2/4 Pressure Channels
  • None
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27
Q

Containment Isolation Phase A actuation signals

A
  • Manual

- SI

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28
Q

Containment Isolation Phase B actuation signals

A
  • Manual

- CTS

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29
Q

Steam Line Isolation actuation signals w/ setpoints and coincidences

A
  • Manual
  • Containment Pressure High High (2.8 psig on 2/4 channels)
  • Hi Steam Flow w/ P12 (1.42E6 [1.6E6] lbm/hr)
  • SG Pressure Lo (500 psig 1/1 channels on 2 SGs)
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30
Q

Feed Water Isolation actuation signals w/ setpoints and coincidences

A
  • Reactor Trip w/ Lo Tave (554 deg F on 2/4 loops)
  • SG Water Level Hi-Hi (67% level on 2/3 channels on 1 SG)
  • SI
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31
Q

What starts the CEQ fans w/ setpoints and coincidences

A
  • Containment Pressure High High (1.0 psig on 2/3 Pressure Channels)
  • 5 min delay U1
  • 2 min delay U2
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32
Q

What are the safety related functions of the Reactor Protection System

A
  • Keep fuel within DNBR

- Limit RCS Pressure w/in design

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33
Q

What are the non-safety related functions of the Reactor Protection System

A
  • Initiate Turbine trip from a Reactor Trip

- Status and Alarm Conditions

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34
Q

What is the function of OTDT & what are the inputs

A
  • Protects from DNB

- Inputs from dT, Tave, AFD, and Pressurizer Pressure

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35
Q

What is the function of OPDT & what are the inputs

A
  • Protects from kW/ft

- Inputs from dT and Tave

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36
Q

What are the Safety Limits

A
  • WRB-1 DNBR >= 1.17
  • W-3 BNDR >= 1.30
  • Centerline Fuel Temperature < 5080 deg F (decreasing by 58 deg F per 10K MWD/MTU)
  • RCS Pressure < 2735 psig
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37
Q

Loss of 4kV Bus Voltage MDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 94 (93) V
  • 2/3 on EITHER T11A/T11D bus
  • None
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38
Q

Loss of 4kV Bus Voltage MDAFP Valve repositioning signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 94 (93) V
  • 2/3 on BOTH T busses in the same train
  • None
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39
Q

AMSAC MDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Feedwater Flow <25%
  • 3/4 flow channels
  • C20
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40
Q

Low Low Steam Generator Water Level MDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 5 (22) % Level
  • 2/3 level channels on 1 Steam Generator
  • None
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41
Q

Loss of Both Main Feedpumps MDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Feedpump Turbine Stop Valves Closed
  • 2/2 limit switches madeup (1 from each MFP)
  • Only Available w/ switch in AUTO
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42
Q

RCP Bus Undervoltage TDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 88 V
  • 1/2 on 2 RCP busses
  • On time delay
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43
Q

SG Water Level Low Low TDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 5 (22) % Level
  • 2/3 level channels on 2 Steam Generators)
  • None
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44
Q

AMSAC TDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Feedwater Flow <25%
  • 3/4 flow channels
  • C20
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45
Q

Loss of Voltage Load Shed signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 94 (93) V
  • 2/3 on ANY T bus
  • 2 sec Delay
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46
Q

Degraded Bus Voltage signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 113 V
  • 2/3 on EITHER T11A/T11D
  • 2 min Delay
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47
Q

RWST Sequence signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • VCT Level < 2.5%
  • 2/2 Level Channels (QLC-451/2)
  • Either IMO-910/911 full open before QMO-451/452 closes
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48
Q

Which Pressurizer Pressure Channels are used for SI

A
  • Channels 1-3
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49
Q

Which Containment Pressure Channels are used for SI

A
  • Channels 2-4
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50
Q

Which Containment Pressure Channels are used for CTS

A
  • Channels 1-4
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51
Q

When is P4 active (On) and what is the function

A
  • Both Reactor Trip Breaker A and Bypass Breaker A Open OR Both Reactor Trip Breaker B and Bypass Breaker B Open
  • Combines w/ Low Tave to initiate FWI
  • Seals in FWI from SI or Hi-Hi SG Levels
  • Permit Manual block of auto SI signals
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52
Q

When is P4 inactive (Off) and what is the function

A
  • Either Reactor Trip or Bypass Breaker racked in and closed

- Prevents/Defeats manual block of SI

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53
Q

When is P6 active (On) and what is the function

A
  • 1/2 Intermediate Range detectors >= 1E-10 amps
  • SR High Flux at SD alarm blocked clears
  • Permits manual block of SR High Flux Trip
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54
Q

When is P6 inactive (Off) and what is the function

A
  • 2/2 Intermediate Range dectors < 6E-11 amps

- Prevents/Defeats manual block of SR High Flux Trip

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55
Q

When is P7 active (On) and what is the function

A
  • 3/4 Power Range Detectors < 10% AND 2/2 Impulse Pressures < 10% (P10 off AND P13 on)
  • Permits auto block of “at power” reactor trips (6)
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56
Q

When is P7 inactive (Off) and what is the function

A
  • 2/4 Power Range Detectors > 10% OR 1/2 Impulse Pressures > 10% (P10 on OR P13 off)
  • Prevents/Defeats auto block of “at power” reactor trips (6)
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57
Q

When is P8 active (On) and what is the function

A
  • 3/4 Power Range Detectors <= 29%

- Permits auto block of Reactor Trip due to single loop low flow AND Turbine trip

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58
Q

When is P8 inactive (Off) and what is the function

A
  • 2/4 Power Range Detectors > 29%

- Prevents/Defeats auto block of Reactor Trip due to single loop flow AND Turbine Trip

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59
Q

When is P10 active (On) and what is the function

A
  • 2/4 Power Range Detectors >= 10%
- Permits the Manual block of:
\+ Power Range High Flux Low setpoint trip
\+ IR Trip
\+ IR Rod Stop
- Also:
\+ Resets P7
\+ Backup de-energization of SR
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60
Q

When is P10 inactive (Off) and what is the function

A
  • 3/4 Power Range Detectors < 10%
- Prevents/Defeats manual blocks of:
\+ Power Range High Flux Low setpoint trip
\+ IR Trip
\+ IR Rod Stop
- Also:
\+ Inputs to P7
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61
Q

When is P11 active (On) and what is the function

A
  • 2/3 Pressurizer Pressure Channels < 1910 psig

- Permits manual block of Pressurizer Pressure Low SI

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62
Q

When is P11 inactive (Off) and what is the function

A
  • 2/3 Pressurizer Pressure Channels >= 1910 psig

- Prevents/Defeats manual block of Pressurizer Pressure Low SI

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63
Q

When is P12 active (On) and what is the function

A
  • 2/4 Loop Tave <= 541 deg F
  • Allows manual block of SI due to low steam line pressure
  • Combined w/ High Steam Flow gives a SLI
  • Blocks all Steam Dumps
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64
Q

When is P12 inactive (Off) and what is the function

A
  • 3/4 Loop Tave > 541 deg F

- Prevents/Defeats manual block of SI due to low steam line pressure

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65
Q

When is P13 active (On) and what is the function

A
  • 2/2 Turbine Impulse Pressures < 10%

- Inputs to to P7

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66
Q

When is P13 inactive (Off) and what is the function

A
  • 1/2 Turbine Impulse Pressures > 10%

- Input to P7

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67
Q

When is P14 active (On) and what is the function

A
  • 2/3 SG NR Levels < 64% in ALL 4 SGs

- Allows MFW addition to SGs

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68
Q

When is P14 inactive (Off) and what is the function

A
  • 2/3 SG NR Levels > 67% in AT LEAST 1 SG

- Prevents MFW addition by initiating FWI and tripping both MFPs and Main Turbine

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69
Q

When is C1 met and what is the function

A
  • 1/2 IR detectors @ 18 (16) %

- Auto and Manual Rod Withdrawal Stop (Blocked above P10)

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70
Q

When is C2 met and what is the function

A
  • 1/4 PR detectors at 103%

- Auto and Manual Rod Withdrawal Stop

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71
Q

When is C3 met and what is the function

A
  • 2/4 OTDT at 3% < Trip Setpoint

- Auto and Manual Rod Withdrawal stop AND initiates Turbine Runback

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72
Q

When is C4 met and what is the function

A
  • 2/4 OPDT at 3% < Trip Setpoint

- Auto and Manual Rod Withdrawal stop AND initiates Turbine Runback

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73
Q

When is C5 met and what is the function

A
  • MPC-253 < 15%

- Prevents Auto Rod Withdrawal

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74
Q

When are C7A and C7B met and what are the functions

A
  • 10% turbine load reject on MPC-254 (C7A)
  • 30% turbine load reject on MPC-254 (C7B)
  • Arms Steam Dumps
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75
Q

When is C8 met and what is the function

A
  • 2/3 Oil Pressure Channels < 800 psig OR 4/4 Stop Valves at 1%
  • Turbine Trip Interlock for Steam Dumps
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76
Q

When is C9 met and what is the function

A
  • 1 Circ water pump Breaker closed
  • CRID II energized
  • 3/3 Condenser Vacuum >= 20.6 in Hg
  • Unblocks Steam Dumps
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77
Q

When is C11 met and what is the function

A
  • Control bank D at 229 steps

- Prevent Auto Rod Withdrawal

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78
Q

When is C20 met and what is the function

A
  • 2/2 Turbine Impulse Pressures > 40%

- Enables AMSAC

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79
Q

What is the input into Pressurizer Level Program Control

A
  • Auctioneered high Tave
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80
Q

How many gallons per % Level in the Pressurizer

A
  • 75 gallons per % level
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81
Q

What happens at 17% Pressurizer Level and lowering

A
  • All heaters are de-energized AND Letdown Orifice valves close to protect heaters
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82
Q

Why is NLI-151 (Pressurizer Level Cold Cal) used during cooldown

A
  • Because actual level is lower than indicated on the hot cal channels and doesn’t provide heater protection
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83
Q

What instrument inputs to LTOP Protection for NRV-152

A
  • NPS-122 (Loop 1 WR)

- Even, Even, Odd

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84
Q

What instrument inputs to LTOP Protection for NRV-153

A
  • NPS-121 (Loop 2 WR)

- Odd, Odd, Even

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85
Q

What is the normal PRT:

  • Temperature
  • Level
  • Pressure
A
  • 100 deg F
  • 83 % level
  • 3 psig
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86
Q

Why are all backup heaters energized before a large dilution

A
  • To promote boron equalization between the RCS and the Pressurizer
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Perfectly
87
Q

What are the dT limits for Aux Spray

A
  • 320 deg F (TRM)
  • 302 deg F (QTI-451)
  • 290 deg F (QTI-60)
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88
Q

During cold shutdown why must PRT level remains less than 5% level

A
  • To ensure sparger line are uncovered to aid in RCS draining
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89
Q

What is the minimum demand/flow achievable with QRV-251 in AUTO and what does this ensure

A
  • QRV-251 stops at 23.5% demand/47 gpm in AUTO

- Prevents isolating seal injection

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90
Q

What action is required with regards to the BAT during emergency boration

A
  • Must be manually shifted to FAST speed
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91
Q

What do the CCP ELO valves (QMO-225/226) do on an SI

A
  • Close on SI
  • w/ standing SI, 2 sec delay then cycle to maintain RCS pressure 1812-1825 psig (controlled by NPP-151/153)
  • Continue to cycle until SI reset AND valves taken to Pull-to-Reset
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92
Q

If shutdown margin IS NOT within COLR limits what action must be taken

A
  • Borate to restore within 15 minutes
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93
Q

Why is Charging flow kept slightly higher than Letdown flow during normal at power operations

A
  • To account for seal leakoff flow
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94
Q

Generally speaking, what functions are associated with QLC-451

A
  • VCT Makeup Functions
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95
Q

Generally speaking, what functions are associated with QLC-452

A
  • VCT Divert Functions
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96
Q

What happens at 87% VCT level on QLC-451/452

A
  • Trip open divert AND alarm (QLC-451)

- Divert full open (QLC-452)

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97
Q

What happens at 78% VCT level on QLC-451/452

A
  • Nothing (QLC-451)

- Divert starts opening (QLC-452)

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98
Q

What happens at 24% VCT level on QLC-451/452

A
  • Makeup secured (QLC-451)

- Nothing (QLC-452)

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99
Q

What happens at 14% VCT level on QLC-451/452

A
  • Auto makeup starts AND low level alarm (QLC-451)

- Nothing (QLC-452)

100
Q

What happens at 7% VCT level on QLC-451/452

A
  • Nothing (QLC-451)

- Low level alarm (QLC-452)

101
Q

What happens at 2.5% VCT level on QLC-451/452

A
  • VCT Low Low Level Alarm (QLC-451/452)

- RWST Sequence on 2/2

102
Q

What flow path does QRV-303 Letdown Divert Valve fail to

A
  • Fails to VCT
103
Q

What are the inputs to the Steam Dump controller in Tave Mode while on the “Load Rejection Controller”

A
  • Auctioneered Tave-Tref
104
Q

What are the inputs to the Steam Dump controller in Tave mode while on the “Turbine Trip Controller”

A
  • Auctioneered Tave-547
105
Q

How many groups of Steam Dump Valves are available while on the “Load Rejection Controller” AND at what temperature delta do they begin to open

A
  • Group 1 (5 deg delta)
  • Group 2 (9 deg delta)
  • Group 3 (13 deg delta)
106
Q

How many groups of Steam Dump Valves are available while on the “Turbine Trip Controller” AND at what temperature delta do they begin to open

A
  • Group 1 (0 deg delta)

- Group 2 (10 deg delta)

107
Q

What temperature is T no load

108
Q

How many groups of Steam Dump Valves are available below “Low-Low Tave” when the controller has been taken to “Bypass Interlock”

A
  • One Group available below 541 deg F
109
Q

What pressure is being controlled with the Steam Dump Controller in “Steam Pressure Mode”

A
  • Bypass Header UPC-101
110
Q

What are the ECCS Design Acceptance Criteria

A
  • Peak clad temperature ,2200 deg F
  • Max clad oxidation <17%
  • H2 generation <1%
111
Q

At what pressure does the CCP start to inject during an accident

112
Q

At what pressure does the SI start to inject during an accident

113
Q

At what pressure do the accumulators start to inject during an accident

114
Q

At what pressure does the RHR start to inject during an accident

115
Q

At what flow rate does the CCP inject during an accident

A
  • 150-550 gpm
116
Q

At what flow rate does the SI inject during an accident

A
  • 400-600 gpm
117
Q

At what flow rate does the RHR inject during an accident

118
Q

What is acceptable volume range for the Accumulators

A
  • 921-971 cuft
119
Q

What is acceptable pressure range for the Accumulators

A
  • 585-658 psig
120
Q

What is acceptable boron concentration range for the Accumulators

A
  • 2400-2600 ppm
121
Q

What interlocks must be met in order to start an RCP

A
  • Bearing Lift Pump Motor Start Closed

- Bearing Lift Oil Pressure > 510 psig

122
Q

What is the flow rate up through the #1 RCP seal

123
Q

What is the flow rate up through the #2 RCP seal

124
Q

What is the flow rate up through the #3 RCP seal

125
Q

Where does #1 RCP seal return go

A
  • Seal Water Hx to the CCP suction/VCT
126
Q

Where does #2 RCP seal flow go

A
  • RCP standpipe/RCDT
127
Q

Where does #3 RCP seal flow go

128
Q

With regards to the RCPs, what must be done on a loss of CCW or a Phase B Containment Isolation AND what is the timeframe for this action AND why is this action taken

A
  • Trip the RCPs
  • Within 2 minutes
  • Prevent damaging bearings
129
Q

If at power what must be done if an RCP trips

A
  • Trip the reactor
130
Q

What do the Incore NIs do

A
  • Determine magnitude/location of fuel burnup
  • Identify misaligned rods
  • Perform flux profiles/QPTR
131
Q

What type of detectors are the Source Range NIs

A
  • BF3 Proportional
132
Q

What type of detectors are the Intermediate Range NIs

A
  • Compensated Ion Chamber
133
Q

What would your Intermediate Range NIs read if they are over compensated

A
  • IR would give a false LOW indication
134
Q

What would your Intermediate Range NIs read if they are under compensated

A
  • IR would give a false HIGH indication
135
Q

What type of detectors are the Power Range NIs

A
  • Uncompensated Ion Chamber
136
Q

What type of detectors are the Gammametrics NIs

A
  • Fission Chamber
137
Q

What is the tech spec limit for QPTR

138
Q

Describe how QPTR is calculated

A
  • Max upper vs AVERAGE of all Upper

- Max Lower vs AVERAGE of all Lower

139
Q

If AFD IS NOT in target band what actions are required

A
  • Above 90% power -> restore within 15 mins

- If you cannot restore w/in 15 mins then be less than 90% within 15 mins (30 mins total)

140
Q

What are the inputs to Rod Control

A
  • Auctioneered High Tave
  • Auctioneered High PRNI
  • MPC-253
141
Q

During restoration of a mis-aligned rod, why is an urgent failure generated in the other banks of rods in that power cabinet

A
  • All lift coil disconnect switches are open for that entire group
142
Q

How fast do the shutdown rod banks move

A
  • 62 steps per minute

- No indication of S/D banks C & D

143
Q

How fast do the control banks move in MANUAL

A
  • 48 steps per minute
144
Q

How fast do the control banks move in AUTO

A
  • 8-72 steps per minute
145
Q

At what temperature error (Tave - Tref) do Rods start to move

146
Q

At what speed do rods move in AUTO with a temperature error between 1.5 deg F and 3.0 deg F

A
  • 8 steps per minute
147
Q

At what speed do rods move in AUTO with a temperature error between 3.0 deg F and 5.0 deg F

A
  • Increases linearly from 8 steps to 72 steps per minute
148
Q

At what temperature error (Tave - Tref) do Rods stop moving

149
Q

What does the Variable Gain Unit do for Rod Control

A
  • Increases the output at low power

- Reactivity changes at low power have a smaller effect on power than at high power

150
Q

What does the Mismatch Rate Comparator do for Rod Control

A
  • Provides faster response to transient conditions
  • Rate of change vs. Turbine 1st stage press AND NIs
  • Rate eventually decays away
151
Q

What must be done with 1 rod out of the ARM (Allowable Rod Misalignment)

A
  • Borate to SDM within 1 hour AND lower power to 75% within 2 hours
152
Q

What must be done with more than 1 rods out of the ARM (Allowable Rod Misalignment)

A
  • Borate to SDM within 1 hour OR be in M3 in 6 hours
153
Q

What is the definition of Mode 1

A
  • Keff >= 0.99

- > 5% RTP

154
Q

What is the definition of Mode 2

A
  • Keff >= 0.99

- <= 5% RTP

155
Q

What is the definition of Mode 3

A
  • Keff < 0.99

- >= 350 deg F

156
Q

What is the definition of Mode 4

A
  • Keff < 0.99

- 200 deg F < Tave < 350 deg F

157
Q

What is the definition of Mode 5

A
  • Keff < 0.99

- <= 200 deg F

158
Q

In Mode 4 how many RCS Loops are required operable AND what action is required if NOT met

A
  • 2 RCS OR RHR loops with 1 in operation

- Restore Immediately

159
Q

In Mode 5 with Loops Filled how many RCS Loops are required operable AND what action is required if NOT met

A
  • 1 RHR loop operable and in Operation AND Either 1 additional RHR loop Operatble OR 2 SGs Operable
  • Restore Immediately
160
Q

In Mode 5 with Loops NOT Filled how many RCS Loops are required operable AND what action is required if NOT met

A
  • 2 RHR loops operable AND 1 in operation

- Restore Immediately

161
Q

In Modes 1-3 how many ECCS Trains must be operable

A
  • 2 trains

- IF less than 100% flow THEN LCO 3.0.3

162
Q

In Mode 4 how many ECCS Trains must be operable AND what action is required if NOT met

A
  • 1 train

- Restore Immediately

163
Q

In Mode 6 with greater than 23 ft of water how many RHR loops are required AND what action is required if NOT met

A
  • One RHR loop operable AND in operation

- Restore Immediately

164
Q

In Mode 6 with less than 23 ft of water how many RHR loops are required AND what action is required if NOT met

A
  • Two RHR loops operable AND one in operation

- Restore Immediately

165
Q

With level greater than 23 ft during refueling how long can the required RHR train be removed for service AND what stipulations are there

A
  • Required loop can be removed for less than 1 hour per 8 hour period
  • No operations are permitted that would cause RCS dilution
166
Q

Under what conditions is RVLIS Narrow Range Used

A
  • No RCPs running
167
Q

Under what condtions is RVLIS Wide Range Used

A
  • With RCPs running
168
Q

Under what conditions is RVLIS Upper Plenum Used

A
  • No RCPs running

- Used for fill & vent using RCP bump method

169
Q

What are the inputs to the Subcooling meters

A
  • Auctioneered Hi CETC OR WR RTD

- Auctioneered LO RVLIS pressure

170
Q

Why is RVLIS pressure used for the subcooling meters

A
  • Because it’s located outside of Containment (Mild Environment)
171
Q

If RCS Tave is less than 541 deg F what action is required

A
  • Be in M2 w/ Keff <1 in 30 minutes
172
Q

If RCS Tave is less than 539 deg F what action is required

A
  • Immediately place Rx in subcritical condition
173
Q

What are the RCS heatup and cooldown limits

A
  • 60 deg F/hr heatup

- 100 deg F/hr cooldown

174
Q

What is the required action if an RCS heatup OR cooldown limit is exceeded in M1-4

A
  • Restore to within 30 minutes

- Due to brittle fracture concerns

175
Q

What is the required action if an RCS heatup OR cooldown limit is exceeded M5

A
  • Restore immediately

- Due to brittle fracture concerns

176
Q

During power changes, when is an Iodine sample required

A
  • If the power change is greater than 15% in 1 hour
177
Q

If an RHR pump trips at low temperatures what is the effect on Letdown flow

A
  • Letdown flow is reduced immediately from the loss of pump discharge pressure
178
Q

During a cooldown why is 600 gpm RHR flow sent to L2 & L3 Hot legs

A
  • To keep L3 subcooled during pressurizer outsurge
179
Q

During the recirculation phase of an accident, which train of RHR provides suction to the SI pumps

180
Q

During the recirculation phase of an accident, which train of RHR provides suction to the CCP pumps

181
Q

In order to open ICM-305/306 (RHR Suction from the Recirc Sump), what interlocks must be met

A
  • IMO-310/320 (RHR suction from RWST) CLOSED
182
Q

In order to open IMO-340/350 (RHR to CCP/SI Suction), what interlocks must be met

A
  • ICM-305/306 (RHR suction from Recirc Sump) OPEN

- IMO-262 OR IMO 263 (SI Recirc to RWST) CLOSED

183
Q

In order to open IMO-330/331 (RHR to Upper Spray), what interlocks must be met

A
  • ICM-305/306 (RHR suction from Recirc Sump) OPEN
184
Q

In order to open IMO-310/320 (RHR Suction from RWST), what interlocks must be met

A
  • ICM-305/306 (RHR suction from Recirc Sump) CLOSED
  • IMO-340/350 (RHR to CCP/SI) CLOSED
  • IMO-330/331 (RHR to Upper Spray) CLOSED
185
Q

What interlock enables the RWST Lo-Lo Level RHR trip at 9%

A
  • IMO-310/320 OPEN
186
Q

What provides the open signal for ESW to CTS Hx valves to OPEN

A
  • ICM-305/306 OPEN
187
Q

What interlock must be met in order to open IMO-128/ICM-129

A
  • NPS-122 < 411 psig (L1 WR Press) for IMO-128

- NPS-121 < 411 psig (L2 WR Press) for ICM-129

188
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a 10% manual runback

A
  • 114.9 (121.7) MW @ 100 MW/min
189
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a 20% manual runback

A
  • 230 (240) MW @ 100 MW/min
190
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a Loss of Feed Pump

A
  • Goes to load target of 625 MW @ 600 MW/min in U1

- Goes to 90% @ 1000 MW/min then to 60% @140 MW/min in U2

191
Q

When is the Loss of Feed Pump turbine runback enables

A
  • Greater than 54.5% U1

- Greater than 60% U2

192
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for an OPDT/OTDT runback

A
  • 30 MW @ an average of 124 (134) MW/min

- 1 sec on (10X speed) 9.5 sec off

193
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for an ATWS

A
  • Load target of 1 MW @ 1389 MW/min
194
Q

How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a Power Load Unbalance runback

A
  • 30 MW @ 1389 MW/min in MW-OUT
195
Q

Where is SG water level measured

A
  • In the downcomer
196
Q

What is the SG normal level

197
Q

What causes SG water level SHRINK

A
  • Reduction is steam flow (i.e., Pressure rises, bubbles collapse)
198
Q

What causes SG water level SWELL

A
  • Increase in steam flow (i.e., Pressure lowers, bubbles expand)
199
Q

After a prolonged period of SF and FF mismatch where will SG water levels ultimately settle out (assuming no operator actions or automatic actions occur) AND why does this happen

A
  • 43.8 % BECAUSE SGWLC is level dominate

- Valves will move to reduce error but level will ultimately override error signal

200
Q

What will AUTO start an ESW pump

A
  • SI on either Unit
  • Load shed
  • Low header pressure 40 psig (switch in AUTO only)
201
Q

Which unit supplies control air for BOTH units ESW backwash strainer

202
Q

What will AUTO start a CCW pump

A
  • SI
  • Loadshed
  • Low discharge pressure on running pump 80 psig (switch in AUTO only)
203
Q

What is the flow range for a CCW pump (min flow - run out flow)

A
  • 3,000 - 9,000 gpm
204
Q

What actions occur in the CCW system on an SI

A
  • Letdown Hx Isolate
  • ESW to CCW Hx Throttles 5500 gpm
  • RHR Hx Outlet opens to 3000-3500 gpm
  • CCW Hx outlet opens (also on a LOOP)
205
Q

What do the Odd numbered Containment Radiation monitors (Train A) do during a CVI

A
  • Close the 100 series (inside containment) valves

- Trips the IR Purge Supply fan

206
Q

What do the Even numbered Containment Radiation monitors (Train B) do during a CVI

A
  • Close the 200 series (outside containment) valves
  • Trips Pressure Relief fan
  • Trips Upper & Lower Containment Purge Supply fans
  • Trips Upper & Lower Containment Purge Exhaust fans
  • Trips IR Purge Exhaust fan
207
Q

What are the Upper Containment tech spec temperature limits

A
  • 60-100 deg F
208
Q

What are the Lower Containment tech spec temperature limits

A
  • 60-120 deg F
209
Q

What are the Containment Pressure limits AND what is the required action if outside the limits

A
  • -1.5 to +0.3 psig

- Restore within 1 hour

210
Q

When is new fuel considered conditioned

A
  • After 72 hours of operation in the last 7 days
211
Q

When is fuel considered condition under “normal” operation

A
  • After 72 hours of operation in the last 30 days
212
Q

What is the power escalation rate limit below 50% power

A
  • There is no limit
213
Q

What is the power escalation limit above 50% with condition fuel

A
  • 10% per hour
214
Q

What is the power escalation limit above 50% with unconditioned fuel

A
  • 3% per hour
215
Q

How many steps per hour can rods be withdrawn between 50%-75% with unconditioned fuel

A
  • 3 steps per hour
216
Q

How many steps per hour can rods be withdrawn above 75% with unconditioned fuel

A
  • 6 steps per hour
217
Q

How many steps per hour can rods be withdrawn above 50% with conditioned fuel

A
  • There is no hourly limit (3 steps at a time until feedback is received)
218
Q

What does the Turbine being in MW-in do

A
  • Allows valves to move to maintain constant MW
219
Q

What does the Turbine being in MW-out do

A
  • Holds the valves in position (MWs may vary)
220
Q

What conditions will force a MFP to speed control

A
  • BOTH MS pressure transmitters fail
  • BOTH MFP Hdr pressure transmitters fail
  • MFP DP setpoint transmitter fails
  • Other MFP trips above 60% power
  • MFP Speed > 5220 (5300) rpm
221
Q

How is the dP auto target setpoint for MFPs determined

A
  • Based on the total steam flow from selected channels
222
Q

How is the actual dP for MFPs determined

A
  • Highest steam pressure

- Lowest feedwater pressure

223
Q

What is the tech spec minimum volume of the CST in gallons AND percent

A
  • 182,000 gal

- 44%

224
Q

What is the basis for the CST minimum volume

A
  • Maintain plant in hot standby for 9 hours on PORVs w/ LOOP
225
Q

What is the maximum and minimum flow for a MFP

A
  • 7M lbm/hr MAX

- 2M lbm/hr MIN (ELO capacity)

226
Q

What are the MFP hardwired trips

A
  • Manual
  • Reactor Trip
  • SI
  • Hi-Hi SG lvl (P14)
  • IOPS (110%)
  • Thrust Bearing Wear
227
Q

What are the MFP DCS trips

A
  • Condenser Vacuum Low (22.5 in Hg)
  • Overspeed (107%)
  • Lube Oil Pressure (4 psig, 5 sec delay)
  • Low Suction Pressure (180 psig, 5 sec delay)
  • Low Trip Header Pressure (800 psig)
228
Q

What are the EDG trips with an SI or LOOP w/ 250 VDC available

A
  • Generator Phase Differential
  • Electronic Overspeed (110%)
  • Manual push button
229
Q

If the EDG electronic governor fails high, what happens

A
  • Speed will rise and machine will be controlled by the mechanical governor
230
Q

Why is the EDG inoperable during testing

A
  • Because it will not generate a load shed signal
231
Q

What is the tech spec limit on EDG air receiver pressure

232
Q

What is the tech spec level range for the EDG fuel oil tank

A
  • 39,500 gal - 46,000 gal
233
Q

What is the tech spec limit for the EDG day tank

234
Q

Why is EDG load raised to 900-1100 KW after closing the output breaker

A
  • To prevent motoring of the EDG due to no-load conditions
235
Q

Why do extraction steam lines to feedwater and condensate heaters have check valves

A
  • To protect the turbine from overspeeding
236
Q

Which train of RATs does TR-5 supply

237
Q

Which train of RATs does TR-9 supply

238
Q

Why does transferring to EP require a dead bus transfer

A
  • Because EP is 30 deg out of phase
239
Q

What is the ampacity limit for EP

A
  • 600 amps per phase (Aluminum cables)
240
Q

What are the SDGs sized for

A
  • 1 train of RCS inventory control
241
Q

Describe is the degraded bus voltage sequence

A
  • 113 V on 2/3 indicator on T11A or T11D
  • 9 sec delay w/ SI or SG lo-lo, Load Shed
  • 99 sec, Auto transfer to RATs
  • 120 sec, Load Shed
  • 120 sec time delay to Load Shed w/o SI or SG Lo Lo
  • 9 sec time delay to Load Shed w/ SI or SG Lo Lo
242
Q

If a degraded bus voltage sequence occurs which busses are stripped

A
  • Both busses on the train that initiated the DBV
243
Q

Describe the Load Shed sequence

A
  • 94 (93) V on 2/3 indicators on ANY T bus
  • 2 sec delay
  • Trips bus feeders, loads, and starts EDG and sequences loads
244
Q

What initiates a Load Conservation and what does it do

A
  • LOOP w/ SI/CTS
  • Trips and locks out non-essential loads
  • Prevents restarting stripped loads until 75 sec timer or SI reset after 60 sec SI timer
  • Trips NESW pp
245
Q

What are the RCP Trip criteria from the FOP of RCP Malfunction

A
  • Complete loss of seal cooling
  • # 1 Seal leakoff temperature greater than 185 deg F AND loss of seal injection
  • # 1 Seal leakoff temperature greater than 200 deg F with lowering seal flows (leakoff or injection) OR rising bearing temperature
  • Lower bearing water temp greater than 225 deg F
  • Upper bearing water temperature greater than 200 deg F w/ low oil alarm
  • Vibes greater than 20 mils
  • # 1 Seal leakoff greater than 6 gpm
  • # 1 Seal leakoff less than 1 gpm

0. Biennial Written Prep (12 decks)

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