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0. Biennial Written Prep > Pre-Test Review (No RQ-C-KNOW) > Flashcards

Pre-Test Review (No RQ-C-KNOW) Flashcards

(186 cards)

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1
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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2
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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3
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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4
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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5
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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6
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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7
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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8
Q

AMSAC MDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Feedwater Flow <25%
  • 3/4 flow channels
  • C20
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9
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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10
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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11
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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12
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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13
Q

AMSAC TDAFP start signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • Feedwater Flow <25%
  • 3/4 flow channels
  • C20
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14
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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15
Q

Degraded Bus Voltage signal:

  • Setpoint
  • Coincidence
  • Interlock
A
  • 113 V
  • 2/3 on EITHER T11A/T11D
  • 2 min Delay
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16
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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17
Q

Which Pressurizer Pressure Channels are used for SI

A
  • Channels 1-3
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18
Q

Which Containment Pressure Channels are used for SI

A
  • Channels 2-4
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19
Q

Which Containment Pressure Channels are used for CTS

A
  • Channels 1-4
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20
Q

What is the input into Pressurizer Level Program Control

A
  • Auctioneered high Tave
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21
Q

How many gallons per % Level in the Pressurizer

A
  • 75 gallons per % level
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22
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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23
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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24
Q

What instrument inputs to LTOP Protection for NRV-152

A
  • NPS-122 (Loop 1 WR)

- Even, Even, Odd

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25
What instrument inputs to LTOP Protection for NRV-153
- NPS-121 (Loop 2 WR) | - Odd, Odd, Even
26
What is the normal PRT: - Temperature - Level - Pressure
- 100 deg F - 83 % level - 3 psig
27
Why are all backup heaters energized before a large dilution
- To promote boron equalization between the RCS and the Pressurizer
28
What are the dT limits for Aux Spray
- 320 deg F (TRM) - 302 deg F (QTI-451) - 290 deg F (QTI-60)
29
During cold shutdown why must PRT level remains less than 5% level
- To ensure sparger line are uncovered to aid in RCS draining
30
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
31
What action is required with regards to the BAT during emergency boration
- Must be manually shifted to FAST speed
32
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
33
If shutdown margin IS NOT within COLR limits what action must be taken
- Borate to restore within 15 minutes
34
Why is Charging flow kept slightly higher than Letdown flow during normal at power operations
- To account for seal leakoff flow
35
Generally speaking, what functions are associated with QLC-451
- VCT Makeup Functions
36
Generally speaking, what functions are associated with QLC-452
- VCT Divert Functions
37
What happens at 87% VCT level on QLC-451/452
- Trip open divert AND alarm (QLC-451) | - Divert full open (QLC-452)
38
What happens at 78% VCT level on QLC-451/452
- Nothing (QLC-451) | - Divert starts opening (QLC-452)
39
What happens at 24% VCT level on QLC-451/452
- Makeup secured (QLC-451) | - Nothing (QLC-452)
40
What happens at 14% VCT level on QLC-451/452
- Auto makeup starts AND low level alarm (QLC-451) | - Nothing (QLC-452)
41
What happens at 7% VCT level on QLC-451/452
- Nothing (QLC-451) | - Low level alarm (QLC-452)
42
What happens at 2.5% VCT level on QLC-451/452
- VCT Low Low Level Alarm (QLC-451/452) | - RWST Sequence on 2/2
43
What flow path does QRV-303 Letdown Divert Valve fail to
- Fails to VCT
44
What are the inputs to the Steam Dump controller in Tave Mode while on the "Load Rejection Controller"
- Auctioneered Tave-Tref
45
What are the inputs to the Steam Dump controller in Tave mode while on the "Turbine Trip Controller"
- Auctioneered Tave-547
46
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)
47
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)
48
What temperature is T no load
- 547 deg F
49
How many groups of Steam Dump Valves are available below "Low-Low Tave" when the controller has been taken to "Bypass Interlock"
- One Group available below 541 deg F
50
What pressure is being controlled with the Steam Dump Controller in "Steam Pressure Mode"
- Bypass Header UPC-101
51
What are the ECCS Design Acceptance Criteria
- Peak clad temperature ,2200 deg F - Max clad oxidation <17% - H2 generation <1%
52
At what pressure does the CCP start to inject during an accident
- 2300 psig
53
At what pressure does the SI start to inject during an accident
- 1600 psig
54
At what pressure do the accumulators start to inject during an accident
- 600 psig
55
At what pressure does the RHR start to inject during an accident
- 200 psig
56
At what flow rate does the CCP inject during an accident
- 150-550 gpm
57
At what flow rate does the SI inject during an accident
- 400-600 gpm
58
At what flow rate does the RHR inject during an accident
- 4500 gpm
59
What is acceptable volume range for the Accumulators
- 921-971 cuft
60
What is acceptable pressure range for the Accumulators
- 585-658 psig
61
What is acceptable boron concentration range for the Accumulators
- 2400-2600 ppm
62
What interlocks must be met in order to start an RCP
- Bearing Lift Pump Motor Start Closed | - Bearing Lift Oil Pressure > 510 psig
63
What is the flow rate up through the #1 RCP seal
- 3 gpm
64
What is the flow rate up through the #2 RCP seal
- 3 gph
65
What is the flow rate up through the #3 RCP seal
- 100 cc/hr
66
Where does #1 RCP seal return go
- Seal Water Hx to the CCP suction/VCT
67
Where does #2 RCP seal flow go
- RCP standpipe/RCDT
68
Where does #3 RCP seal flow go
- RCDT
69
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
70
If at power what must be done if an RCP trips
- Trip the reactor
71
What do the Incore NIs do
- Determine magnitude/location of fuel burnup - Identify misaligned rods - Perform flux profiles/QPTR
72
What type of detectors are the Source Range NIs
- BF3 Proportional
73
What type of detectors are the Intermediate Range NIs
- Compensated Ion Chamber
74
What would your Intermediate Range NIs read if they are over compensated
- IR would give a false LOW indication
75
What would your Intermediate Range NIs read if they are under compensated
- IR would give a false HIGH indication
76
What type of detectors are the Power Range NIs
- Uncompensated Ion Chamber
77
What type of detectors are the Gammametrics NIs
- Fission Chamber
78
What is the tech spec limit for QPTR
- 1.02
79
Describe how QPTR is calculated
- Max upper vs AVERAGE of all Upper | - Max Lower vs AVERAGE of all Lower
80
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 90% within 15 mins (30 mins total)
81
What are the inputs to Rod Control
- Auctioneered High Tave - Auctioneered High PRNI - MPC-253
82
During restoration of a mis-aligned rod, why is an urgent failure generated in the other banks of rods in that power cabinet
- All lift coil disconnect switches are open for that entire group
83
How fast do the shutdown rod banks move
- 62 steps per minute | - No indication of S/D banks C & D
84
How fast do the control banks move in MANUAL
- 48 steps per minute
85
How fast do the control banks move in AUTO
- 8-72 steps per minute
86
At what temperature error (Tave - Tref) do Rods start to move
- 1.5 deg F
87
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
88
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
89
At what temperature error (Tave - Tref) do Rods stop moving
- 1 deg F
90
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
91
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
92
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
93
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
94
What is the definition of Mode 1
- Keff >= 0.99 | - > 5% RTP
95
What is the definition of Mode 2
- Keff >= 0.99 | - <= 5% RTP
96
What is the definition of Mode 3
- Keff < 0.99 | - >= 350 deg F
97
What is the definition of Mode 4
- Keff < 0.99 | - 200 deg F < Tave < 350 deg F
98
What is the definition of Mode 5
- Keff < 0.99 | - <= 200 deg F
99
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
100
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
101
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
102
In Modes 1-3 how many ECCS Trains must be operable
- 2 trains | - IF less than 100% flow THEN LCO 3.0.3
103
In Mode 4 how many ECCS Trains must be operable AND what action is required if NOT met
- 1 train | - Restore Immediately
104
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
105
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
106
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
107
Under what conditions is RVLIS Narrow Range Used
- No RCPs running
108
Under what condtions is RVLIS Wide Range Used
- With RCPs running
109
Under what conditions is RVLIS Upper Plenum Used
- No RCPs running | - Used for fill & vent using RCP bump method
110
What are the inputs to the Subcooling meters
- Auctioneered Hi CETC OR WR RTD | - Auctioneered LO RVLIS pressure
111
Why is RVLIS pressure used for the subcooling meters
- Because it's located outside of Containment (Mild Environment)
112
If RCS Tave is less than 541 deg F what action is required
- Be in M2 w/ Keff <1 in 30 minutes
113
If RCS Tave is less than 539 deg F what action is required
- Immediately place Rx in subcritical condition
114
What are the RCS heatup and cooldown limits
- 60 deg F/hr heatup | - 100 deg F/hr cooldown
115
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
116
What is the required action if an RCS heatup OR cooldown limit is exceeded M5
- Restore immediately | - Due to brittle fracture concerns
117
During power changes, when is an Iodine sample required
- If the power change is greater than 15% in 1 hour
118
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
119
During a cooldown why is 600 gpm RHR flow sent to L2 & L3 Hot legs
- To keep L3 subcooled during pressurizer outsurge
120
During the recirculation phase of an accident, which train of RHR provides suction to the SI pumps
- West RHR
121
During the recirculation phase of an accident, which train of RHR provides suction to the CCP pumps
- East RHR
122
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
123
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
124
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
125
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
126
What interlock enables the RWST Lo-Lo Level RHR trip at 9%
- IMO-310/320 OPEN
127
What provides the open signal for ESW to CTS Hx valves to OPEN
- ICM-305/306 OPEN
128
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
129
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
130
How much is turbine load lowered (MW) AND at what rate rate does the load reduction occur for a 20% manual runback
- 230 (240) MW @ 100 MW/min
131
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
132
When is the Loss of Feed Pump turbine runback enables
- Greater than 54.5% U1 | - Greater than 60% U2
133
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
134
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
135
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
136
Where is SG water level measured
- In the downcomer
137
What is the SG normal level
- 43.8%
138
What causes SG water level SHRINK
- Reduction is steam flow (i.e., Pressure rises, bubbles collapse)
139
What causes SG water level SWELL
- Increase in steam flow (i.e., Pressure lowers, bubbles expand)
140
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
141
What will AUTO start an ESW pump
- SI on either Unit - Load shed - Low header pressure 40 psig (switch in AUTO only)
142
Which unit supplies control air for BOTH units ESW backwash strainer
- Unit 1
143
What will AUTO start a CCW pump
- SI - Loadshed - Low discharge pressure on running pump 80 psig (switch in AUTO only)
144
What is the flow range for a CCW pump (min flow - run out flow)
- 3,000 - 9,000 gpm
145
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)
146
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
147
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
148
What are the Upper Containment tech spec temperature limits
- 60-100 deg F
149
What are the Lower Containment tech spec temperature limits
- 60-120 deg F
150
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
151
When is new fuel considered conditioned
- After 72 hours of operation in the last 7 days
152
When is fuel considered condition under "normal" operation
- After 72 hours of operation in the last 30 days
153
What is the power escalation rate limit below 50% power
- There is no limit
154
What is the power escalation limit above 50% with condition fuel
- 10% per hour
155
What is the power escalation limit above 50% with unconditioned fuel
- 3% per hour
156
How many steps per hour can rods be withdrawn between 50%-75% with unconditioned fuel
- 3 steps per hour
157
How many steps per hour can rods be withdrawn above 75% with unconditioned fuel
- 6 steps per hour
158
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)
159
What does the Turbine being in MW-in do
- Allows valves to move to maintain constant MW
160
What does the Turbine being in MW-out do
- Holds the valves in position (MWs may vary)
161
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
162
How is the dP auto target setpoint for MFPs determined
- Based on the total steam flow from selected channels
163
How is the actual dP for MFPs determined
- Highest steam pressure | - Lowest feedwater pressure
164
What is the tech spec minimum volume of the CST in gallons AND percent
- 182,000 gal | - 44%
165
What is the basis for the CST minimum volume
- Maintain plant in hot standby for 9 hours on PORVs w/ LOOP
166
What is the maximum and minimum flow for a MFP
- 7M lbm/hr MAX | - 2M lbm/hr MIN (ELO capacity)
167
What are the MFP hardwired trips
- Manual - Reactor Trip - SI - Hi-Hi SG lvl (P14) - IOPS (110%) - Thrust Bearing Wear
168
What are the MFP DCS trips
- 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)
169
What are the EDG trips with an SI or LOOP w/ 250 VDC available
- Generator Phase Differential - Electronic Overspeed (110%) - Manual push button
170
If the EDG electronic governor fails high, what happens
- Speed will rise and machine will be controlled by the mechanical governor
171
Why is the EDG inoperable during testing
- Because it will not generate a load shed signal
172
What is the tech spec limit on EDG air receiver pressure
- 190 psig
173
What is the tech spec level range for the EDG fuel oil tank
- 39,500 gal - 46,000 gal
174
What is the tech spec limit for the EDG day tank
- 101.4 gal
175
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
176
Why do extraction steam lines to feedwater and condensate heaters have check valves
- To protect the turbine from overspeeding
177
Which train of RATs does TR-5 supply
- Train B
178
Which train of RATs does TR-9 supply
- Train A
179
Why does transferring to EP require a dead bus transfer
- Because EP is 30 deg out of phase
180
What is the ampacity limit for EP
- 600 amps per phase (Aluminum cables)
181
What are the SDGs sized for
- 1 train of RCS inventory control
182
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
183
If a degraded bus voltage sequence occurs which busses are stripped
- Both busses on the train that initiated the DBV
184
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
185
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
186
What are the RCP Trip criteria from the FOP of RCP Malfunction
- 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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