AOP1 Flashcards
1
Q
State entry conditions for OS1201.04 - RCS Valve Stem Leak
A
Abnormal RCDT level or run times on RCDT pumps
Computer alarms associated with a high stem leakoff condition
2
Q
State entry conditions for OS1202.04 - Rapid Boration
A
Inadequate SDM
Unexplained or uncontrolled reactivity addition
Failure of two or more rods to insert fully shutdown or reactor trip
3
Q
State entry conditions for OS1210.05 - Dropped Rod
A
DRPI dropped rod bottom light lit
Rod Deviation alarm
4
Q
State when AOPs can be used in parallel with EOPs
A
AOPs may be used in parallel with EOPs provided AOP actions do not interfere with EOP strategy, intent or TCAs
This should be generally avoided
5
Q
State major actions of RCS leak
A
Check if Pressurizer level can be maintained
- adjust charging or letdown
- Trip and SI if PZR level can’t be maintained >7% with 1 CCP
Determine appropriate procedure step transition
Isolate potential RCS leakage sources
Check for RHR leakage
Isolate leakage from Letdown or Charging
6
Q
State E-Plan entry from RCS leakage
A
MU4:
RCS unidentified or pressure boundary leakage >10GPM for 15min
- OR -
RCS identified leakage >25GPM for 15min or longer
- OR -
Leakage from the RCS to a location outside containment >25GPM for 15min or longer
7
Q
State the major actions on OS1201.07 - Pressurizer Level Channel or failed controllers
A
Identify the failure
Compensate for failure
Restore system alignment back to normal
Review TS requirements
8
Q
State the major actions of OS1201.06 - PZR Pressure Channel failed
A
Mitigate the effects of failure
Identify the failure
Realign Pressurizer Pressure Channels
Verify TS compliance
9
Q
State the major actions of OS1211.01 PR NI failure
A
Check if PR failed high Bypass the failed PR channel Verify proper P-10 indication Verify TS compliance Defeat affected PR NI inputs Restore rod control to AUTO
10
Q
State what is required if P-10/13 is not in its required state
A
Restore P-10/13 w/in 1 hour
- OR -
Initiate plant shutdown as required per T.S. 3.0.3
11
Q
State Major actions of dropped rod
A
Stabilize the plant Evaluate conditions for dropped rod recovery Notify I&C Recover the dropped rod Restore the controls to normal
12
Q
State the difference between a dropped rod and a misaligned rod
A
A dropped rod reaches the bottom of the core
A misaligned to only drops partially into the core
13
Q
State what must be done if the reactor is made subcritical from a dropped rod
A
Shutdown the plant to MODE 3.
The rod will be recovered during the subsequent reactor startup
14
Q
State the major action for a misaligned Rod
A
Validate misaligned Rod Stabilize Plant Conditions Verify TS Compliance Notify SM and RE Check Rod Control Status Perform Rod Realignment Restore control to normal
15
Q
State what must be done if more than one control rod is misaligned >48 steps
A
Trip the reactor
Go to E-0
16
Q
State Alert and Danger Values for RCP shaft vibes
A
Alert: 15 mils and increasing at 1 mil/hr
Danger: 20 mils
17
Q
State Alert and Danger Values for RCP Frame vibes
A
Alert: 3 mils and increasing at 0.2 mils/hr
Danger: 5 mils
18
Q
State actions for stopping an RCP with power < P-8
A
Place affected SG FRV in manual
Feed SG to 60 to 70% NR level
Defeat affected loop Delta-T and Tave inputs
Stop affected RCP
19
Q
State Rx trip for #1 seal and temp
A
1 seal leak off flow <1 GPM
- AND -
Temp increasing
Trip the Rx
20
Q
State the Rx trip for #1 seal, total seal flow and temp
A
#1 seal >6 GPM - AND - Total <8 GPM - AND - Temp increasing Trip the Rx
21
Q
State the Rx trip for total seal flow
A
> 8 GPM
Trip the Rx
22
Q
State the Rx trip for motor bearing or winding temp
A
Motor bearing >/= 195F
- OR -
Winding >/= 302F
Trip the Rx
23
Q
State the conditions for total loss of seal cooling and actions
A
RCP seal injection <6 GPM
- AND -
No Thermal barrier cooling pump running
Then: trip the Rx
24
Q
State the Rx trip for RCP seal inlet temp
A
RCP seal inlet temp >230F
Trip the Rx
25
State basis for 230F to seal inlet temp
Ensures that the RCP has stopped rotating by the time seal water heats up to 230F to ensure that the SDS is not damaged
DO NOT REESTABLISH COOLING FLOW
26
State Temp Rx must be cooled to and why on an RCS high activity
<500F to prevent lifting an ASDV incase of a primary to secondary leak
27
State major actions of an inadvertent phase A
```
Verify Containment Isolation is not required
Charge to seals only
Check if letdown can be established
Realign PCCW system Valves
Restore systems as Required
Reset CVI
Determine if Plant operation can continue
Verify Normal Component Positions
```
28
How do we verify that a rod is trippable
If no rod stops are present
- AND -
The IN/OUT rod demand light does not lite with rod motion requested,
THEN the control failure is electrical in nature and rods are verified trippable
29
State what must be done if SDM is less than the requirement in the COLR
Immediately and continue boration equivalent to 30 gpm at a boron concentration greater than equal to the limit specified in the COLR until the required SDM is restored
30
Why do we maintain AFD within the limits
This assures that the design limits on peak local power density and minimum DNBR are not exceeded and the consequences of any non-LOCA event would be within specified acceptance criteria
31
State major actions for Rod or Rod bank failure to move or stop moving
Stabilize Plant Power Level
Try to determine Cause of Rod Control Failure
Check if Rod control is restored
32
State what happens if an urgent failure alarm is reset, without correcting the cause of the alarm
A group of control rods may drop
33
State what must occur if 1 CRDM coil fuse is replaced
Replace both fuses to prevent premature failure of the remaining fuse
34
State what must happen if 1 or more full-length rod is immovable due to friction or mechanical interference
Determine SDM per T.S. 3.1.1.1 within 1 hr and be in hot standby within 6 hr
35
State what must be done if rod motion can not be stopped
Trip the Reactor
36
State major actions for loss of MPCS
```
Determine if Plant Computer Available
Mitigate loss of Computer Functions
Monitor reactor Power to Ensure that Power Level of an 8hr shift will not exceed 3648MW
Check for Loss of an IRTU
Restore Normal Computer functions
Restore Plant Calorimetric Functions
Restore Normal Plant Conditions
```
37
State Major Steps for Loss of Vital PP A-D
Stabile the Plant
Dispatch NSO to restore instrument bus
Restore letdown
Restore valid inputs
38
State SSPS response to a loss of PP-1A or 1B
Slave relays have lost power
Safeguards equipment must be manually aligned
SSPS power supplies must be reset upon re-energization
39
State Major Steps for Loss of Vital PP-E/F
Dispatch NSO to restore bus
Manually control affected systems
Verify RDMS in service
Power restoration may isolate PCCW to WPB and Containment
40
State how loss of PP-1E affects Charging and Letdown
CS-HCV-182 fails open
| CS-HCV-189 fails closed
41
State what will cause a CVI
```
COP rad monitor 2/2 in either train
Manipulator crane rad monitor
Any S signal
Phase A (T)
Manual CVS
```
42
State the major actions for PZR level Inst Failure
Identify the failure
Compensate for the failure
Restore system alignment back to normal
Review tech specs
43
State major actions for PR NI failure
```
Verify load is stable and place rod control in MANUAL
Bypass the failed channel ROD STOP
Restore Tave
Bypass the failed power Range Channel
Verify P-10
Verify Tech Spec Compliance
Defeat PR NI inputs
Restore rod control to AUTO
```
44
State what must be done if P-10 is not in its required state
Restore P-10 w/in 1 hour
- OR -
SD the unit per T.S. 3.0.3
45
State Turbine Runback/Setback major steps
```
Verify turbine load decreasing
Verify rod motion inward
Verify S/G pressure <1150#
Verify S/G levels trending to 50%
If RIL Lo-Lo alarms, and not restored within 30 min, then verify SDM and restore if needed
Monitor Steam Dumps
After turbine load stabilizes, check AFD
```
46
State Turbine Runback/Setback Rx trip Criteria
turbine load can not be reduced
S/G pressure >1150#
S/G level cannot be maintained >20%
47
State why Tref may not reflect actual pressure when Steam Dumps are in service
SD bypasses PT-505, the input to Tref, so Tref is not representative
48
State why MGB must be opened if GSC flow is lost and conductivity is >0.5 micormhos
GSC water will act as conductor and could result in a phase to phase fault
49
State basis for AFD limits
The limits assures that peak local power density and minimum DNBR are not exceeded
50
State Turbine trip below P-9 major steps
```
Verify SG pressure <1150
Place rods in manual
Verify turbine trip
Verify S/G levels trending to 50%
Stabilize RCS temperature with Steam Dumps
Reduce power to <20%
```
51
State Rx trip criteria for Turbine trip below P-9
Trip Rx if:
Turbine will not trip
S/G pressure >1150
S/G level cannon be maintained >20% and <90.8%
52
State we can't run indefinitely on SD above 20% power
SD groups 2, 3, and 4 could damage the condenser due to the condenser tubes not being shielded
53
State the cause of feedwater flow instability when power is less than 25% w/o feedwater heating
Water entering the SG is not preheated and Flow and SG NR level instability may result
54
State major steps of high turbine vibrations
```
Monitor
Lower Load
Verify MGB closed
Consult with engineering
Trip Rx if needed
```
55
State RX trip criteria for TG high Vibes
Above P-9
- if >800 rpm, >11 mils sustained
Below P-9
- If > 800 RPM, >11 mils sustained
- If <800 RPM, >8 mils sustained
in all cases if >14 mils break vacuum
56
State why TG has a 3 second turbine trip delay
This is a design feature and prevents transient conditions from tripping the TG
57
State why VAR loading should be reduced prior to reducing load
reducing VAR loading can reduce the torques angle of the shaft, and may be effective in reducing vibration
58
State why running the TG at low speeds can be bad
Long duration operation at low speeds can result in heating of the last stages of the LP turbines. this can cause expansion which may lead to blade-nozzle contact
59
State why we don't operate the TG at critical speeds
There are elevated vibrations at these speeds
60
State the major steps for TG system oil leak
```
Check for fire condition
Check for catastrophic failure
Determine location of oil leak
Reduce power and S/D plant
Isolate oil source, purge main generator H2, respond to spill
```
61
State the basis for movable control assembly T.S.
This T.S. ensures that acceptable power distribution limits are maintained, the minimum SDM is maintained and the potential effects of rod misalignment on associated accident analyses are limited. operability of the control rod position indicators in required to determine control rod positions and thereby ensure compliance with the control rod alignment and insertion limits.
62
State major actions for a continuous rod insertion
```
Verify secondary plant parameters
Check Rod Control System
Check for a failed power range channel
Check for a failed RCS NR temp
Check for failed PT-505
Check Tave/Tref Matched (W/IN 1F)
Verify T.S. compliance
Notify I&C
```
63
State major actions for Condenser tube sheet leak
```
Notify Chemistry
Isolate CO Spill to CST
Verify CST levels
Validate Salt Water intrusion
Align CPS if leak rate is less than 0.01 GPM
Evaluate if Rx trip is required
Evaluate continued plant operation
```
64
State basis for starting a CST fill as soon as possible
Seabrook is challenged with a low margin CST volume
65
State why we can only isolate 1 Condenser water box at a time
for power operation CW must be aligned to more than 1 water box
66
State the SUFP caution when running it for a tube leak
SUFP may trip on low suction pressure is CST level decreases below 310,000 gallons
67
State Rx trip criteria for a condenser tube sheet leak
IF CO pump discharge cation conductivity >1 micromho
- AND -
Valid salt water intrusion exists
Trip the Rx
68
State major actions for Loss of Condenser vacuum
```
Verify all mechanical vacuum pumps running
With Condenser vacuum lowering
- lower TG output to 360 MWe
- Check CW system
- Check steam seal pressure >3#
- Locate source of vacuum loss
Notify chemistry
```
69
State the basis for why SDs are blocked at 25"Hg
This is the minimum vacuum that support SD
70
State the basis for not starting a tripped CW pump
This could cause severe water hammer
71
State Rx trip criteria for loss of vacuum
TG output = 360MWe
- AND -
vacuum can not be maintained > 25" Hg
72
State Rx trip criteria for < 2 CW pumps running
If 1 or no CW pumps are running
Trip the Rx
Close MSIVs after E-0 step 4
73
State major actions for GSC high conductivity
Evaluate conductivity
Verify proper Deionizer operation
Check for a leaking Heat exchanger
Monitor GSC Conditions
74
State Rx trip criteria for GSC high conductivy
```
Inlet conductivity >9.9 micromho/cm
- And -
Outlet conductivity >9.9 micro mho/com
- AND -
Power > P-9
Trip the Rx
```
75
State Rx trip criteria for GSC high conductivity with chemistry involvement
```
If inlet or outlet >9.9 micromho/cm
- AND -
Chemistry confirms >9.9
- AND -
Power > P-9
Trip the Rx
```
76
State major actions for CW system malfunction if it is due to a Lube Water issue
Verify CW lube water is running
Verify CW lube inlet valve to running CW pumps
Adjust Lube water flows
Stop CW pump is 3 are running and flows not sat
77
State Rx trip criteria for loss of CW lube water
```
if Lube water flows are 1/2 sat
- AND -
Two CW pumps are running
THEN
Trip the Rx
Stop the affect CW pumps
Close MSIVs
```
78
State Rx trip criteria for lowered Lube water flows
```
if lube water flows are less than sat values
- AND -
Flows can not be restored to within 20min
- AND -
Two CW pumps are running
THEN
Trip the Rx
Stop the affected CW pumps
Close MSIVs
```
79
State major actions for CW malfunction due to a fouled screens
```
Operate CW screens in fast
Transfer SW to CT for sand/silt
Reduce screen fouling by:
- Screen wash
- Opening CW-V-40
- Decrease plant load
Check vacuum >25" and reduce load if needed
If CW screens are fouled - monitor CW pump discharge valves
```
80
State the basis for for TG should not go below 360MWe
Below this value a plant trip is required due to buffeting the last stage LP turbine buckets
81
State major actions of SGTL
Determine if plant shutdown is required
Initiate boration
Depressurize RCS to minimize RCS subcooling
Identify and isolate affected SG
Cooldown RCS to target temp
Prepare for plant CD using appropriate post-SG tube leak procedure
82
State Rx trip criteria for SGTL with PRZ <7%
With charging maxed and both charging pump running
Trip Rx and actuate SI
This is now a SGTR
83
State actions if VCT level can not be maintained >15%
Swap to RWST from VCT
| Trip Rx
84
State the T.S. limit on secondary activity
0.1 microCi/gm DEI
85
State major actions for Spill response
```
Isolate the spill
Contain the spill area
Refer to ER 1.1
Perform notifications
Clean up spill
```
86
State spill response regulatory notification requirements
Petroleum >25gal involving groundwater
- <1 hr notify NHDES, National response center, USCG
Harmful to sanitary system
- Immediately notify Seabrook Wastewater Treatment
Hazardous material
- < 15min notify National Response center
- < 1hr, notify NHDES, USCG, NHEM, Town of Seabrook
Radiological spills
- Notify Groundwater Radioactive assessment personnel
Events involving news release or other government agencies
- < 4hr, notify NRC
87
State Severe weather that would cause a plant SD
hurricane with >74mph winds
88
State major actions for Secondary transient
Stabilize the plant
Check HD, MFP, CO pumps
Check FW heater status
89
State what system may isolate and why if CO-E-23C isolates
SB isolation may occur on flash tank high pressure due to loss of condensing action
90
State Rx trip criteria for a seismic event
Rx parameters not stable
Two or more dropped rods
Turbine Parameters not stable
91
State the major steps of Degraded UHS
```
Determine correct procedure step
Check for ocean system failure
Check SCCW HX outlet temp
Verify TA sequence
Check if both trains of TA actuated
Restore SW to Secondary Loads if both trains on CT
Check for cause of CT failure
Determine if plant can remain at power
```
92
State how CT sprays and fans use are determined
Per attachment A:
Spray Water Return temp
AND
Ambient Temperature
93
State major action for a loss of a SG level controller
```
Check SG level Control
Realign SG level Instruments
Align SG Level Control
Verify Redundant Channel Bistables - Not Tripped
Verify TS
Verify ATWS
```
94
State which channel failure will require manual FRV bypass control
519, 529, 539, or 549
95
State major actions for SG FF/SF failure
Check SG level control
Realign control instruments
Align SG level control
Check for failure of SG pressure Instrument
96
State major actions for loss of PT-507/508
```
Check Condenser SD system
Restore Main Feed pump Speed Control
Check Secondary Plant stable
Check third condensate pump not running
initiate repairs
```
97
State major actions for Rapid Down Power
```
Prepare for Down Power
Set up/ Commence negative reactivity addition
reduce load while controlling the plant
Use Att. E to align the plant
Stabilize at final power
```
98
State major strategies for PCCW malfunction
```
Determine appropriate section
Component PCCW flow status
PCCW system integrity
Thermal Barrier system integrity status
PCCW system cooling
```
99
State why when isolating PCCW to the WPB the supply valve should be closed first
Closing the supply valve first prevents lifting the system relief
100
State why RCPs must be tripped W/IN 10 min of loosing PCCW
This prevents a locked rotor accident
101
State limit and consequence of PCCW N2 bottle low pressure
At 1700# the PCCW temp control valves are considered inoperable
102
State loss of letdown Rx trip critieria
If PZR cannot be maintained >7% with normal charging then:
Trip the Rx
Actuate SI
103
State major actions for Charging system failure
```
Check letdown
Monitor RCP seal and bearing Temp
Check Charging pump running
Check Seal Injection Flow
Check if Charging is intact
Re-establish Charging and letdown
```
104
State when a charging pump should not be restarted
If a charging pump was stopped due to inadvertent SI termination
- OR -
If RCP seal package has heated up to >230F, seal cooling should not be reestablished
105
State major steps for Security event
Land-based code red: shutdown
Land-based code yellow: alert personnel
Threat listed in Att A: confirm creditability
Cyber-based: check plant equipment
106
State major steps for a security code red
```
Close and dog CR door
Notify Site personnel
Activate ERO
Trip Rx and Stop B and D RCPs
CD with RHR
Place CBA in CRFRM
```
107
State how to declare Emergency from a Security event
Use the Security abnormal
| not ER 1.1
108
State why in SGTL we fill the affected SG to >25%
This is done for thermal stratification
