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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
  • p-10
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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
Manual Containment Spray actuation: - Setpoint - Coincidence - Interlock
- N/A - 1/1 per Train - None
26
Containment Pressure High High Containment Spray actuation: - Setpoint - Coincidence - Interlock
- 2.8 psig - 2/4 Pressure Channels - None
27
Containment Isolation Phase A actuation signals
- Manual | - SI
28
Containment Isolation Phase B actuation signals
- Manual | - CTS
29
Steam Line Isolation actuation signals w/ setpoints and coincidences
- 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)
30
Feed Water Isolation actuation signals w/ setpoints and coincidences
- 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
31
What starts the CEQ fans w/ setpoints and coincidences
- Containment Pressure High (1.0 psig on 2/3 Pressure Channels) - 5 min delay U1 - 2 min delay U2
32
What are the safety related functions of the Reactor Protection System
- Keep fuel within DNBR | - Limit RCS Pressure w/in design
33
What are the non-safety related functions of the Reactor Protection System
- Initiate Turbine trip from a Reactor Trip | - Status and Alarm Conditions
34
What is the function of OTDT & what are the inputs
- Protects from DNB | - Inputs from dT, Tave, AFD, and Pressurizer Pressure
35
What is the function of OPDT & what are the inputs
- Protects from kW/ft | - Inputs from dT and Tave
36
What are the Safety Limits
- 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
37
Loss of 4kV Bus Voltage MDAFP start signal: - Setpoint - Coincidence - Interlock
- 94 (93) V - 2/3 on EITHER T11A/T11D bus - None
38
Loss of 4kV Bus Voltage MDAFP Valve repositioning signal: - Setpoint - Coincidence - Interlock
- 94 (93) V - 2/3 on BOTH T busses in the same train - None
39
AMSAC MDAFP start signal: - Setpoint - Coincidence - Interlock
- Feedwater Flow <25% - 3/4 flow channels - C20
40
Low Low Steam Generator Water Level MDAFP start signal: - Setpoint - Coincidence - Interlock
- 5 (22) % Level - 2/3 level channels on 1 Steam Generator - None
41
Loss of Both Main Feedpumps MDAFP start signal: - Setpoint - Coincidence - Interlock
- Feedpump Turbine Stop Valves Closed - 2/2 limit switches madeup (1 from each MFP) - Only Available w/ switch in AUTO
42
RCP Bus Undervoltage TDAFP start signal: - Setpoint - Coincidence - Interlock
- 88 V - 1/2 on 2 RCP busses - On time delay
43
SG Water Level Low Low TDAFP start signal: - Setpoint - Coincidence - Interlock
- 5 (22) % Level - 2/3 level channels on 2 Steam Generators) - None
44
AMSAC TDAFP start signal: - Setpoint - Coincidence - Interlock
- Feedwater Flow <25% - 3/4 flow channels - C20
45
Loss of Voltage Load Shed signal: - Setpoint - Coincidence - Interlock
- 94 (93) V - 2/3 on ANY T bus - 2 sec Delay
46
Degraded Bus Voltage signal: - Setpoint - Coincidence - Interlock
- 113 V - 2/3 on EITHER T11A/T11D - 2 min Delay
47
RWST Sequence signal: - Setpoint - Coincidence - Interlock
- VCT Level < 2.5% - 2/2 Level Channels (QLC-451/2) - Either IMO-910/911 full open before QMO-451/452 closes
48
Which Pressurizer Pressure Channels are used for SI
- Channels 1-3
49
Which Containment Pressure Channels are used for SI
- Channels 2-4
50
Which Containment Pressure Channels are used for CTS
- Channels 1-4
51
When is P4 active (On) and what is the function
- 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
52
When is P4 inactive (Off) and what is the function
- Either Reactor Trip or Bypass Breaker racked in and closed | - Prevents/Defeats manual block of SI
53
When is P6 active (On) and what is the function
- 1/2 Intermediate Range detectors >= 1E-10 amps - SR High Flux at SD alarm blocked clears - Permits manual block of SR High Flux Trip
54
When is P6 active (Off) and what is the function
- 2/2 Intermediate Range dectors < 6E-11 amps | - Prevents/Defeats manual block of SR High Flux Trip
55
When is P7 active (On) and what is the function
- 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)
56
When is P7 active (Off) and what is the function
- 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)
57
When is P8 active (On) and what is the function
- 3/4 Power Range Detectors <= 29% | - Permits auto block of Reactor Trip due to single loop low flow AND Turbine trip
58
When is P8 active (Off) and what is the function
- 2/4 Power Range Detectors > 29% | - Prevents/Defeats auto block of Reactor Trip due to single loop flow AND Turbine Trip
59
When is P10 active (On) and what is the function
- 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 ```
60
When is P10 active (Off) and what is the function
- 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 ```
61
When is P11 active (On) and what is the function
- 2/3 Pressurizer Pressure Channels < 1910 psig | - Permits manual block of Pressurizer Pressure Low SI
62
When is P11 active (Off) and what is the function
- 2/3 Pressurizer Pressure Channels >= 1910 psig | - Prevents/Defeats manual block of Pressurizer Pressure Low SI
63
When is P12 active (On) and what is the function
- 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
64
When is P12 active (Off) and what is the function
- 3/4 Loop Tave > 541 deg F | - Prevents/Defeats manual block of SI due to low steam line pressure
65
When is P13 active (On) and what is the function
- 2/2 Turbine Impulse Pressures < 10% | - Inputs to to P7
66
When is P13 active (Off) and what is the function
- 1/2 Turbine Impulse Pressures > 10% | - Input to P7
67
When is P14 active (On) and what is the function
- 2/3 SG NR Levels < 64% in ALL 4 SGs | - Allows MFW addition to SGs
68
When is P14 active (Off) and what is the function
- 2/3 SG NR Levels > 67% in AT LEAST 1 SG | - Prevents MFW addition by initiating FWI and tripping both MFPs and Main Turbine
69
When is C1 met and what is the function
- 1/2 IR detectors @ 18 (16) % | - Auto and Manual Rod Withdrawal Stop (Blocked above P10)
70
When is C2 met and what is the function
- 1/4 PR detectors at 103% | - Auto and Manual Rod Withdrawal Stop
71
When is C3 met and what is the function
- 2/4 OTDT at 3% < Trip Setpoint | - Auto and Manual Rod Withdrawal stop AND initiates Turbine Runback
72
When is C4 met and what is the function
- 2/4 OPDT at 3% < Trip Setpoint | - Auto and Manual Rod Withdrawal stop AND initiates Turbine Runback
73
When is C5 met and what is the function
- MPC-253 < 15% | - Prevents Auto Rod Withdrawal
74
When are C7A and C7B met and what are the functions
- 10% turbine load reject on MPC-254 (C7A) - 30% turbine load reject on MPC-254 (C7B) - Arms Steam Dumps
75
When is C8 met and what is the function
- 2/3 Oil Pressure Channels < 800 psig OR 4/4 Stop Valves at 1% - Turbine Trip Interlock for Steam Dumps
76
When is C9 met and what is the function
- 1 Circ water pump Breaker closed - CRID II energized - 3/3 Condenser Vacuum >= 20.6 in Hg - Unblocks Steam Dumps
77
When is C11 met and what is the function
- Control bank D at 229 steps | - Prevent Auto Rod Withdrawal
78
When is C20 met and what is the function
- 2/2 Turbine Impulse Pressures > 40% | - Enables AMSAC
79
What is the input into Pressurizer Level Program Control
- Auctioneered high Tave
80
How many gallons per % Level in the Pressurizer
- 75 gallons per % level
81
What happens at 17% Pressurizer Level and lowering
- All heaters are de-energized AND Letdown Orifice valves close to protect heaters
82
Why is NLI-151 (Pressurizer Level Cold Cal) used during cooldown
- Because actual level is lower than indicated on the hot cal channels and doesn't provide heater protection
83
What instrument inputs to LTOP Protection for NRV-152
- NPS-122 (Loop 1 WR) | - Even, Even, Odd
84
What instrument inputs to LTOP Protection for NRV-153
- NPS-121 (Loop 2 WR) | - Odd, Odd, Even
85
What is the normal PRT: - Temperature - Level - Pressure
- 100 deg F - 83 % level - 3 psig
86
Why are all backup heaters energized before a large dilution
- To promote boron equalization between the RCS and the Pressurizer
87
What are the dT limits for Aux Spray
- 320 deg F (TRM) - 302 deg F (QTI-451) - 290 deg F (QTI-60)
88
During cold shutdown why must PRT level remains less than 5% level
- To ensure sparger line are uncovered to aid in RCS draining
89
What is the minimum demand/flow achievable with QRV-251 in AUTO and what does this ensure
- QRV-251 stops at 23.5% demand/47 gpm in AUTO | - Prevents isolating seal injection
90
What action is required with regards to the BAT during emergency boration
- Must be manually shifted to FAST speed
91
What do the CCP ELO valves (QMO-225/226) do on an SI
- 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
92
If shutdown margin IS NOT within COLR limits what action must be taken
- Borate to restore within 15 minutes
93
Why is Charging flow kept slightly higher than Letdown flow during normal at power operations
- To account for seal leakoff flow
94
Generally speaking, what functions are associated with QLC-451
- VCT Makeup Functions
95
Generally speaking, what functions are associated with QLC-452
- VCT Divert Functions
96
What happens at 87% VCT level on QLC-451/452
- Trip open divert AND alarm (QLC-451) | - Divert full open (QLC-452)
97
What happens at 78% VCT level on QLC-451/452
- Nothing (QLC-451) | - Divert starts opening (QLC-452)
98
What happens at 24% VCT level on QLC-451/452
- Makeup secured (QLC-451) | - Nothing (QLC-452)
99
What happens at 14% VCT level on QLC-451/452
- Auto makeup starts AND low level alarm (QLC-451) | - Nothing (QLC-452)
100
What happens at 7% VCT level on QLC-451/452
- Nothing (QLC-451) | - Low level alarm (QLC-452)
101
What happens at 2.5% VCT level on QLC-451/452
- VCT Low Low Level Alarm (QLC-451/452) | - RWST Sequence on 2/2
102
What flow path does QRV-303 Letdown Divert Valve fail to
- Fails to VCT
103
What are the inputs to the Steam Dump controller in Tave Mode while on the "Load Rejection Controller"
- Auctioneered Tave-Tref
104
What are the inputs to the Steam Dump controller in Tave mode while on the "Turbine Trip Controller"
- Auctioneered Tave-547
105
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
- Group 1 (5 deg delta) - Group 2 (9 deg delta) - Group 3 (13 deg delta)
106
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
- Group 1 (0 deg delta) | - Group 2 (10 deg delta)
107
What temperature is T no load
- 547 deg F
108
How many groups of Steam Dump Valves are available below "Low Tave" when the controller has been taken to "Bypass Interlock"
- One Group available below 541 deg F
109
What pressure is being controlled with the Steam Dump Controller in "Steam Pressure Mode"
- Bypass Header UPC-101
110
What are the ECCS Design Acceptance Criteria
- Peak clad temperature ,2200 deg F - Max clad oxidation <17% - H2 generation <1%
111
At what pressure does the CCP start to inject during an accident
- 2300 psig
112
At what pressure does the SI start to inject during an accident
- 1600 psig
113
At what pressure do the accumulators start to inject during an accident
- 600 psig
114
At what pressure does the RHR start to inject during an accident
- 200 psig
115
At what flow rate does the CCP inject during an accident
- 150-550 gpm
116
At what flow rate does the SI inject during an accident
- 400-600 gpm
117
At what flow rate does the RHR inject during an accident
- 4500 gpm
118
What is acceptable volume range for the Accumulators
- 921-971 cuft
119
What is acceptable pressure range for the Accumulators
- 585-658 psig
120
What is acceptable boron concentration range for the Accumulators
- 2400-2600 ppm
121
What interlocks must be met in order to start an RCP
- Bearing Lift Pump Motor Start Closed | - Bearing Lift Oil Pressure > 510 psig
122
What is the flow rate up through the #1 RCP seal
- 3 gpm
123
What is the flow rate up through the #2 RCP seal
- 3 gph
124
What is the flow rate up through the #3 RCP seal
- 100 cc/hr
125
Where does #1 RCP seal return go
- Seal Water Hx to the CCP suction/VCT
126
Where does #2 RCP seal flow go
- RCP standpipe/RCDT
127
Where does #3 RCP seal flow go
- RCDT
128
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
- Trip the RCPs - Within 2 minutes - Prevent damaging bearings
129
If at power what must be done if an RCP trips
- Trip the reactor
130
What do the Incore NIs do
- Determine magnitude/location of fuel burnup - Identify misaligned rods - Perform flux profiles/QPTR
131
What type of detectors are the Source Range NIs
- BF3 Proportional
132
What type of detectors are the Intermediate Range NIs
- Compensated Ion Chamber
133
What would your Intermediate Range NIs read if they are over compensated
- IR would give a false LOW indication
134
What would your Intermediate Range NIs read if they are under compensated
- IR would give a false HIGH indication
135
What type of detectors are the Power Range NIs
- Uncompensated Ion Chamber
136
What type of detectors are the Gammametrics NIs
- Fission Chamber
137
What is the tech spec limit for QPTR
- 1.02
138
Describe how QPTR is calculated
- Max upper vs AVERAGE of all Upper | - Max Lower vs AVERAGE of all Lower
139
If AFD IS NOT in target band what actions are required
- Above 90% power -> restore within 15 mins | - If you cannot restore w/in 15 mins then be less than 50% within 15 mins (30 mins total)
140
What are the inputs to Rod Control
- Auctioneered High Tave - Auctioneered High PRNI - MPC-253
141
During restoration of a mis-aligned rod, why is an urgen failure generated in the other banks of rods in that power cabiner
- All lift coil disconnect switches are open for that entire group
142
How fast do the shutdown rod banks move
- 62 steps per minute | - No indication of S/D banks C & D
143
How fast do the control banks move in MANUAL
- 48 steps per minute
144
How fast do the control banks move in AUTO
- 8-72 steps per minute
145
At what temperature error (Tave - Tref) do Rods start to move
- 1.5 deg F
146
At what speed do rods move in AUTO with a temperature error between 1.5 deg F and 3.0 deg F
- 8 steps per minute
147
At what speed do rods move in AUTO with a temperature error between 3.0 deg F and 5.0 deg F
- Increases linearly from 8 steps to 72 steps per minute
148
At what temperature error (Tave - Tref) do Rods stop moving
- 1 deg F
149
What does the Variable Gain Unit do for Rod Control
- Increases the output at low power | - Reactivity changes at low power have a smaller effect on power than at high power
150
What does the Mismatch Rate Comparator do for Rod Control
- Provides faster response to transient conditions - Rate of change vs. Turbine 1st stage press AND NIs - Rate eventually decays away
151
What must be done with 1 rod out of the ARM (Allowable Rod Misalignment)
- Borate to SDM within 1 hour AND lower power to 75% within 2 hours
152
What must be done with more than 1 rods out of the ARM (Allowable Rod Misalignment)
- Borate to SDM within 1 hour OR be in M3 in 6 hours
153
What is the definition of Mode 1
- Keff >= 0.99 | - > 5% RTP
154
What is the definition of Mode 2
- Keff >= 0.99 | - <= 5% RTP
155
What is the definition of Mode 3
- Keff < 0.99 | - >= 350 deg F
156
What is the definition of Mode 4
- Keff < 0.99 | - 200 deg F < Tave < 350 deg F
157
What is the definition of Mode 5
- Keff < 0.99 | - <= 200 deg F
158
In Mode 4 how many RCS Loops are required operable AND what action is required if NOT met
- 2 RCS OR RHR loops with 1 in operation | - Restore Immediately
159
In Mode 5 with Loops Filled how many RCS Loops are required operable AND what action is required if NOT met
- 1 RHR loop operable and in Operation AND Either 1 additional RHR loop Operatble OR 2 SGs Operable - Restore Immediately
160
In Mode 5 with Loops NOT Filled how many RCS Loops are required operable AND what action is required if NOT met
- 2 RHR loops operable AND 1 in operation | - Restore Immediately
161
In Modes 1-3 how many ECCS Trains must be operable
- 2 trains | - IF less than 100% flow THEN LCO 3.0.3
162
In Mode 4 how many ECCS Trains must be operable AND what action is required if NOT met
- 1 train | - Restore Immediately
163
In Mode 6 with greater than 23 ft of water how many RHR loops are required AND what action is required if NOT met
- One RHR loop operable AND in operation | - Restore Immediately
164
In Mode 6 with less than 23 ft of water how many RHR loops are required AND what action is required if NOT met
- Two RHR loops operable AND one in operation | - Restore Immediately
165
With level greater than 23 ft during refueling how long can the required RHR train be removed for service AND what stipulations are there
- Required loop can be removed for less than 1 hour per 8 hour period - No operations are permitted that would cause RCS dilution
166
Under what conditions is RVLIS Narrow Range Used
- No RCPs running
167
Under what condtions is RVLIS Wide Range Used
- With RCPs running
168
Under what conditions is RVLIS Upper Plenum Used
- No RCPs running | - Used for fill & vent using RCP bump method
169
What are the inputs to the Subcooling meters
- Auctioneered Hi CETC OR WR RTD | - Auctioneered LO RVLIS pressure
170
Why is RVLIS pressure used for the subcooling meters
- Because it's located outside of Containment (Mild Environment)
171
If RCS Tave is less than 541 deg F what action is required
- Be in M2 w/ Keff <1 in 30 minutes
172
If RCS Tave is less than 539 deg F what action is required
- Immediately place Rx in subcritical condition
173
What are the RCS heatup and cooldown limits
- 60 deg F/hr heatup | - 100 deg F/hr cooldown
174
What is the required action if an RCS heatup OR cooldown limit is exceeded in M1-4
- Restore to within 30 minutes | - Due to brittle fracture concerns
175
What is the required action if an RCS heatup OR cooldown limit is exceeded M5
- Restore immediately | - Due to brittle fracture concerns
176
During power changes, when is an Iodine sample required
- If the power change is greater than 15% in 1 hour
177
If an RHR pump trips at low temperatures what is the effect on Letdown flow
- Letdown flow is reduced immediately from the loss of pump discharge pressure
178
During a cooldown why is 600 gpm RHR flow sent to L2 & L3 Hot legs
- To keep L3 subcooled during pressurizer outsurge
179
During the recirculation phase of an accident, which train of RHR provides suction to the SI pumps
- West RHR
180
During the recirculation phase of an accident, which train of RHR provides suction to the CCP pumps
- East RHR
181
In order to open ICM-305/306 (RHR Suction from the Recirc Sump), what interlocks must be met
- IMO-310/320 (RHR suction from RWST) CLOSED
182
In order to open IMO-340/350 (RHR to CCP/SI Suction), what interlocks must be met
- ICM-305/306 (RHR suction from Recirc Sump) OPEN | - IMO-262 OR IMO 263 (SI Recirc to RWST) CLOSED
183
In order to open IMO-330/331 (RHR to Upper Spray), what interlocks must be met
- ICM-305/306 (RHR suction from Recirc Sump) OPEN
184
In order to open IMO-310/320 (RHR Suction from RWST), what interlocks must be met
- 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
What interlock enables the RWST Lo-Lo Level RHR trip at 9%
- IMO-310/320 OPEN
186
What provides the open signal for ESW to CTS Hx valves to OPEN
- ICM-305/306 OPEN
187
What interlock must be met in order to open IMO-128/ICM-129
- NPS-122 < 411 psig (L1 WR Press) for IMO-128 | - NPS-121 < 411 psig (L2 WR Press) for ICM-129
188
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a 10% manual runback
- 114.9 (121.7) MW @ 100 MW/min
189
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a 20% manual runback
- 130 (240) MW @ 100 MW/min
190
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a Loss of Feed Pump
- 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
When is the Loss of Feed Pump turbine runback enables
- Greater than 54.5% U1 | - Greater than 60% U2
192
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for an OPDT/OTDT runback
- 30 MW @ an average of 124 (134) MW/min | - 1 sec on (10X speed) 9.5 sec off
193
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for an ATWS
- Load target of 1 MW @ 1389 MW/min
194
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a Power Load Unbalance runback
- 30 MW @ 1389 MW/min in MW-OUT
195
Where is SG water level measured
- In the downcomer
196
What is the SG normal level
- 43.8%
197
What causes SG water level SHRINK
- Reduction is steam flow (i.e., Pressure rises, bubbles collapse)
198
What causes SG water level SWELL
- Increase in steam flow (i.e., Pressure lowers, bubbles expand)
199
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
- 43.8 % BECAUSE SGWLC is level dominate | - Valves will move to reduce error but level will ultimately override error signal
200
What will AUTO start an ESW pump
- SI on either Unit - Load shed - Low header pressure 40 psig (switch in AUTO only)
201
Which unit supplies control air for BOTH units ESW backwash strainer
- Unit 1
202
What will AUTO start a CCW pump
- SI - Loadshed - Low discharge pressure on running pump 80 psig (switch in AUTO only)
203
What is the flow range for a CCW pump (min flow - run out flow)
- 3,000 - 9,000 gpm
204
What actions occur in the CCW system on an SI
- 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
What do the Odd numbered Containment Radiation monitors (Train A) do during a CVI
- Close the 100 series (inside containment) valves | - Trips the IR Purge Supply fan
206
What do the Even numbered Containment Radiation monitors (Train B) do during a CVI
- 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
What are the Upper Containment tech spec temperature limits
- 60-100 deg F
208
What are the Lower Containment tech spec temperature limits
- 60-120 deg F
209
What are the Containment Pressure limits AND what is the required action if outside the limits
- -1.5 to +0.3 psig | - Restore within 1 hour
210
When is new fuel considered conditioned
- After 72 hours of operation in the last 7 days
211
When is fuel considered condition under "normal" operation
- After 72 hours of operation in the last 30 days
212
What is the power escalation rate limit below 50% power
- There is no limit
213
What is the power escalation limit above 50% with condition fuel
- 10% per hour
214
What is the power escalation limit above 50% with unconditioned fuel
- 3% per hour
215
How many steps per hour can rods be withdrawn between 50%-75% with unconditioned fuel
- 3 steps per hour
216
How many steps per hour can rods be withdrawn above 75% with unconditioned fuel
- 6 steps per hour
217
How many steps per hour can rods be withdrawn above 50% with conditioned fuel
- There is no hourly limit (3 steps at a time until feedback is received)
218
What does the Turbine being in MW-in do
- Allows valves to move to maintain constant MW
219
What does the Turbine being in MW-out do
- Holds the valves in position (MWs may vary)
220
What conditions will force a MFP to speed control
- 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
How is the dP auto target setpoint for MFPs determined
- Based on the total steam flow from selected channels
222
How is the actual dP for MFPs determined
- Highest steam pressure | - Lowest feedwater pressure
223
What is the tech spec minimum volume of the CST in gallons AND percent
- 182,000 gal | - 44%
224
What is the basis for the CST minimum volume
- Maintain plant in hot standby for 9 hours on PORVs w/ LOOP
225
What is the maximum and minimum flow for a MFP
- 7M lbm/hr MAX | - 2M lbm/hr MIN (ELO capacity)
226
What are the MFP hardwired trips
- Manual - Reactor Trip - SI - Hi-Hi SG lvl (P14) - IOPS (110%) - Thrust Bearing Wear
227
What are the MFP DCS trips
- Condenser Vacuum Low (20"/20.3" 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
What are the EDG trips with an SI or LOOP w/ 250 VDC available
- Generator Phase Differential - Electronic Overspeed (110%) - Manual push button
229
If the EDG electronic governor fails high, what happens
- Speed will rise and machine will be controlled by the mechanical governor
230
Why is the EDG inoperable during testing
- Because it will not generate a load shed signal
231
What is the tech spec limit on EDG air receiver pressure
- 190 psig
232
What is the tech spec level range for the EDG fuel oil tank
- 39,500 gal - 46,000 gal
233
What is the tech spec limit for the EDG day tank
- 101.4 gal
234
Why is EDG load raised to 900-1100 KW after closing the output breaker
- To prevent motoring of the EDG due to no-load conditions
235
Why do extraction steam lines to feedwater and condensate heaters have check valves
- To protect the turbine from overspeeding
236
Which train of RATs does TR-5 supply
- Train B
237
Which train of RATs does TR-9 supply
- Train A
238
Why does transferring to EP require a dead bus transfer
- Because EP is 30 deg out of phase
239
What is the ampacity limit for EP
- 600 amps per phase (Aluminum cables)
240
What are the SDGs sized for
- 1 train of RCS inventory control
241
Describe is the degraded bus voltage sequence
- 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
If a degraded bus voltage sequence occurs which busses are stripped
- Both busses on the train that initiated the DBV
243
Describe the Load Shed sequence
- 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
What initiates a Load Conservation and what does it do
- 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

ILT Review Often (23 decks)

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