Following a Unit Two (2) Reactor scram, plant conditions are:
Steam Flow 3.5 X 10 lbm/hr
RPV Level 155 inches and rising steadily
APRMs Downscale
Control Rods 10 rods failed to insert
Level set 170 inches
RFPs 2 in operation
The operator should immediately:
A. trip the Main Turbine
Following a reactor scram on Unit Two, plant conditions are:
Reactor water level +230", rising, N027A/B
Reactor pressure 700 psig, steady
Drywell ref leg temp 195°F
Per the Reactor Scram Procedure (EOP·01-RSP). MSIVs must be closed if RPV level cannot be maintained below the elevation of the main steam lines. At this level,
N027A/B will indicate:
D. 240"
240 inches using Reactor water level at MSL graph and using ref leg area temp below
200 deg line, 245 could be chosen misreading divisions for level on graph, 250 could be chosen using wrong ref leg area temp line or is used if RPV pressure is below 60psig, 255 (254) is actual elevation.
Following a Unit Two (2) Reactor scram, plant conditions are:
Steam Flow 3.5 X 10 lbm/hr
RPV Level 155 inches and rising steadily
APRMs Downscale
Control Rods 10 rods failed to insert
Level set 170 inches
RFPs 2 in operation
The operator should immediately:
D. trip the Main Turbine
Following a Group 1 isolation and a reactor scram, the operating crew is performing the Reactor Scram Procedure, EOP-01-RSP.
Plant conditions are:
Reactor water level 195 inches, slowly rising (N004s)
Reactor pressure 800 – 1000 psig, controlled by SRV’s
Drywell pressure 1.0 psig, slowly rising
Suppression pool temp 94° F, slowly rising
Suppression pool level -27.5”, slowly rising
The operating crew is required to enter EOP-01-RVCP and execute concurrently with the scram procedure if:
B. Suppression Pool temperature rises to 111° F
Following a reactor scram on Unit 1, plant conditions are:
Reactor water level +210”, rising
Reactor pressure 700 psig, steady
Drywell ref leg temp 195F
Per the guidance of the scram Procedure (EOP-01-RSP), MSIVs must be closed if Reactor water as indicated on level instruments N027A/B level rises to:
A. 240”
Which one of the following Scram Immediate Operator actions has a different setpoint between Unit One and Unit Two?
C. Placing the reactor mode switch to Shutdown.
During execution of EOP-01-RVCP on Unit Two, emergency depressurization becomes required due to low reactor water level. The operator places the control switches for 7 ADS valves to Open and observes that only 4 ADS valves have opened. The operator is then directed to place additional SRV switches to open until 7 ADS/SRVs are open. No additional ADS/SRVs can be opened.
Reactor pressure is currently 600 psig, lowering. What action, if any, is required?
B. Enter the alternate emergency depressurization procedure.
Unit Two was operating at rated power. Both Reactor Feedpumps tripped. HPCI and RCIC both failed. CRD flow has been maximized and SLC is injecting demin water to stabilize RPV level.
What action can be performed, and is required to control containment parameters?
D. Defeat drywell cooler LOCA lockout per SEP-10.
PCCP DW/T leg directs operating available drywell coolers defeating LOCA logic if necessary. Drywell cooler LOCA lockout logic can be defeated per SEP-10 if drywell coolers have tripped due to low level and actual LOCA conditions do not exist in the drywell. PCCP PC/P directs venting drywell per OP-10, but this cannot be done with drywell pressure >1.7 psig. Suppression chamber spray is also directed by PCCP PC/P, but cannot be done with drywell pressure <2.7 psig. Venting per SEP-01 is not performed until pressure approaches PCPL-A (or hydrogen is detected).
Unit1 Plant conditions:
Reactor shutdown.
Reactor pressure: 925 psig.
1A CRD pump is running.
No other injection available.
Reactor water level is -75 inches and slowly lowering
Primary Containment parameters are normal
Under the above listed conditions, the operating crew should:
A. Emergency Depressurize the RPV
Following a large line break in Unit Two (2) Primary Containment, plant conditions are:
Reactor Water level -50", steady
Reactor Pressure 10 psig
Core Spray Pump 2A Injecting at 5500 gpm
Core Spray Pump 2B Unavailable
RHR Loop 2A Injecting (LPCI) at 17,000 gpm
RHR Loop 2B Unavailable
Suppression Pool Temperature 145 F and rising
What action is required by EOP-01-RVCP for RHR Loop 2A?
C. Throttle LPCI flow to 11,500 gpm, close the heat exchanger bypass valve, operate RHR SW at a minimum flow rate of 8000 gpm.
Unit One plant conditions:
Reactor is shutdown (all rods in)
Reactor pressure is 1000 psig
RCIC is injecting to the RPV
No other injection Is available
Reactor water level is -35 inches and lowering
Drywell reference leg area temperature is 290°F
What action is required?
C. Wait until RPV level drops to LL4, then perform emergency depressurization.
Level is currently above TAF (TAF is -42.5" using caution 1 correction graphs). Emergency depressurization is normally performed when level drops below TAF if a High volume system (condensate, RHR, or core spray) is available. Since no high Volume system is available, ED is not performed until LL4. Steam cooling would be performed if no injection available, with RCIC injecting. ED is performed even though RCIC would be lost (most likely transition to SAMG if no other sources are made available).
Following a large line break in Unit Two primary containment, plant conditions are:
Reactor Water level -50 inches, steady
Reactor Pressure 10 psig
Core Spray Pump 2A Injecting at 5500 gpm
Core Spray Pump 2B Unavailable
RHR Loop2A Injecting (LPCI) at 17,000 gpm
RHR Loop2B Unavailable
Suppr pool temp 148°F
What action is required by EOP-01-RVCP for RHR loop 2A?
C. Throttle LPCI flow to 11,500 gpm, close the heat exchanger bypass valve, and operate RHR SW at a flowrate of 8000 gpm.
Step PC/L-44 of EOP-01-RVCP requires containment cooling requirements of the UFSAR be established. This step is reached since RPV level is below LL4. but above 2/3 core height with core spray injecting at least 4700 gpm. RVCP requires establishing these cooling requirements even if LPCI flow will be reduced. Since 11,500 gpm is required RHR flow rate with RHR Loop B unavailable. Drywell spray will not satisfy the requirements.
Unit 2 has scrammed due to a condensate header rupture. RCIC is injecting at 500 gpm; HPCI, SLC and CRD are unavailable. Reactor water level has dropped to +20”, but is currently +35” and slowly rising. ADS has been inhibited.
With NO indications of fuel failure, how should reactor pressure be controlled at this time?
A. Use SRV’s to maintain pressure below 1050 psig
Given the following plant conditions on Unit One:
Reactor water level -25 inches
Reactor pressure 55 psig
Vessel Injection 4500 gpm from RHR
In accordance with 0OI-37.4, Reactor Vessel Control Procedure Basis Document, which one of the following identifies the current status of Adequate Core Cooling and the operational implications of these conditions?
A. Adequate Core Cooling is met;
Clad temperatures are expected to remain between 1500° F and 1800° F.
B. Adequate Core Cooling is met;
Clad temperatures are expected to remain < 1500° F
C. Adequate Core Cooling is NOT met;
Clad temperatures are expected to exceed 1800° F
D. Adequate Core Cooling is NOT met;
Clad temperatures are expected to remain < 1800° F
B. Adequate Core Cooling is met; Clad temperatures are expected to remain < 1500° F
The conditions listed satisfy the ACC requirements for Steam Cooling with Injection.
If reactor water level were to drop below LL4, and RHR injection were maintained, ACC would not be meet. By maintaining this method of ACC, the core will generate sufficient steam to preclude any clad temperature from exceeding 1500F.
A reactor scram has occurred with the following plant conditions:
Which one of the following systems is available and allowed for use in accordance with RVCP to stabilize pressure below 1050 psig?
C. Main Steam Line Drains
With EHC tripped and the scram the bypass valves will not work; with Hi drywell pressure, the HPCI system will be running and cannot be put in pressure control with an initiation signal present. RCIC will not be able to be put in pressure control because HPCI has an initiation signal, which closes the reduntant CST return valve.
During a LOCA with a LOOP, the following plant conditions exist:
2B RHR pump Injecting and operating at its NPSH Limit
2B CS pump Injecting and approaching its NPSH Limits
All other ECCS Pumps Unavailable
Reactor Water Level 2/3 core height and steady
Which one of the following is the consequence of continued RHR operation outside its NPSH limit in accordance with 0OI-37.4, Reactor Vessel Control Procedure Basis Document, and also identifies the required procedure to maintain adequate core cooling in accordance with RVCP?
A. Long term operation is expected to cause RHR pump damage;
Line up CS to the CST per OP-18, Core Spray System Operating Procedure.
B. Immediate RHR pump damage is expected to occur;
Line up Alternate Coolant Injection per 0EOP-01-LEP-01.
C. Long term operation is expected to cause RHR pump damage;
Line up Alternate Coolant Injection per 0EOP-01-LEP-01.
D. Immediate RHR pump damage is expected to occur;
Line up CS to the CST per OP-18, Core Spray System Operating Procedure.
C. Long term operation is expected to cause RHR pump damage; Line up Alternate Coolant Injection per 0EOP-01-LEP-01.
From OI-37.4, Immediate and catastrophic failure is not expected if a pump is operated beyond the NPSH or vortex limit. The undesirable consequences of uncovering the reactor core could thus outweigh the risk of equipment damage.
Unit One is in an accident condition and is executing RVCP with the following conditions:
Reactor Water Level -60 inches
Reactor Pressure 800 psig
Reference Leg Temperature 208° F
Injection sources available None
Which one of the following identifies the required procedure(s) that is/are required to maintain adequate core cooling?
A. Below the minimum steam cooling water level
Enter STCP. Do not perform Emergency Depressurization.
B. Below the minimum steam cooling water level
Enter STCP and perform Emergency Depressurization.
C. Above the minimum steam cooling water level
Remain in RVCP. Do not perform Emergency Depressurization.
D. Above the minimum steam cooling water level
Remain in RVCP and perform Emergency Depressurization.
A. Below the minimum steam cooling water level
Enter STCP. Do not perform Emergency Depressurization.
Determines that level is less than LL4 and no injection sources, so STCP must be entered. When leaving RVCP, only the pressure leg is exited, and the level leg is executed concurrently with STCP.
Unit Two (2) has experienced a large break LOCA. All rods inserted normally and current plant conditions are:
Reactor Water level -50 inches, steady on the N037’s (huh?)
Reactor Pressure 5 psig
Core Spray Pump 2A injecting at 5500 gpm
Core Spray Pump 2B Unavailable
RHR Loop 2A injecting (LPCI) at 17,000 gpm
RHR Loop 2B Unavailable
Suppression Pool Temp 145 degrees, rising slowly
Drywell Pressure 5 psig
Drywell Temperature 330 degrees
Based on these conditions, what operator action is required by EOP-01-RVCP?
C. Throttle 2A LPCI loop flow to 11,500 gpm, close the heat exchanger bypass valve, operate RHR SW at a minimum flowrate of 8000 gpm.
Unit Two (2) has experienced a reactor scram and group one isolation. Plant conditions are as follows, and the SCO is directing recovery actions in accordance with the Reactor scram procedure:
Reactor water level 195 inches, slowly rising (N004s)
Reactor pressure 800 – 1000 psig, controlled by SRVs
Drywell pressure 1.0 psig, slowly rising
Suppression pool temp 94°F, slowly rising
Suppression pool level -27.5”, slowly rising
Which of the following conditions would require the crew to enter EOP-01-RVCP and execute it concurrently with the Scram Procedure?
D. Suppression pool temperature rises to 110°F.
Unit Two was operating at rated power. DC distribution panel 12A tripped resulting in loss of both Recirc pumps. Following a manual scram, conditions are:
APRM indications 16%
Blue scram lights 137 illuminated
RWM display 124 rods not full in
What method per EOP·01-LEP-02, Alternate Control Rod Insertion, should be
performed and could be successful?
C. Insert control rods using RMCS.
ARI circuitry is powered from DC panel 12Aand is energize to initiate. The scram blue lights indicate the scram valves are open; therefore, venting the scram air header will not be effective. Since scram valves are open, the scram pilot solenoids are already de-energized so placing test switches to test would also be ineffective. RMCS is available to insert rods and is directed by LEP-02.
During an ATWS on Unit Two, plant conditions are:
Reactor power Range 1 IRM
Control rods 8 still withdrawn
RPV water level +170 inches
RPV pressure 950 psig
Suppr pool level -27 inches
Suppr pool temp 164°F
SLC tank level 5%, lowering
Emergency Depressurization is:
A. required and must be performed immediately.
Unsafe region of HCTL plotting reactor pressure vs. suppression pool temp using the -2.5 ft line (-30 inches) which is line immediately below current pool level. This requires ED per the RC/P leg of EOP-01 (either RVCP or LPC). ED is not deliberately delayed to achieve more favorable conditions.
During an ATWS, EOP-01· LPC is being executed. Plant conditions are:
Reactor power 8%
Suppr pool temp 112°F
RPV water level +85"
MSIVs Open
BPVs Failed closed
RPV pressure 800·1000mpsig.controlled by SRVs
SLC Injecting, tank level 48%
Why does LPC direct the operator to continue to lower RP Water level?
C. Reduce the heat input to primary containment.
On high power ATWS (above 2%), level is always deliberately lowered to 2 feet below the feedwater spargers (+90") to place the spargers in the steam space of the downcomer. This provides steam heating of water injected through the feed spargers (FW/HPCI/RCIC) to reduce core inlet subcooling and minimize possibility of THI (large scale core oscillations). When level reaches 90" or APRM are downscale, then Table 3 is evaluated to determine if further lowering of level is required to minimize challenges to primary containment. Since level is +85", SPT is above 110°F, and APRMs are >2%, continued lowering of level is required to reduce heat input to containment. Once HSBW injected (32%), level is restored to normal band to promote boron mixing
During an ATWS event on Unit Two, SLC initiation is required. Plant conditions are as
follows:
SLC is unavailable
CRD is unavailable
RCIC is injecting with a CST suction
HPCI is injecting with a suppression pool suction
Which one at the following methods is preferred to inject boron?
A. RCIC using submersible pump.
Submersible pump is preferred over gravity drain provided power is available to pump (approx 25 gpm with pump, approx 8 gpm with gravity drain). Whichever system is used, the hose connection is made to the suction line coming from the CST. If the suction is from the suppression pool there is no flow past the point in the system where the connection is made, so LEP-03 requires a suction from the CST. RCIC is also preferred due to the lower flow rate.
During an ATWS on Unit One, plant conditions upon entry into EOP-01-LPC are:
Reactor power 5%
Reactor water level +170 inches
Reactor pressure 948, steady (controlled by EHC)
SRVs All closed
Drywell pressure 0.5 psig
Injection to the vessel is terminated and prevented as required by EOP-01-LPC. As RPV level lowers, APRM downscales are received at +125 inches. EOP-01-LPC directs reactor water level control band no higher than:
C. +90 inches, and no lower than LL4.
Water level is being deliberately lowered to reduce level 2 feet below the feedwater spargers. This preheats injected feedwater to reduce core inlet subcooling and minimize potential for large scale core oscillations. Once APRMs are downscale, the SRO would exit the terminate and prevent step and evaluate Table 3. With APRMs downscale (and no heat input to primary containment) Table 3 allows establishing a level band. Since level was not deliberately lowered due to Table 3, LPC directs a level band of +90 to LL4 even though core oscillations would not occur below 2% (basis for exiting terminate and prevent step) it would be preferable to maintain above TAF to maintain adequate core cooling by submergence.
During an ATWS on Unit 2, plant conditions upon entry into EOP-01-LPC are:
Injection to the vessel is terminated and prevented as required by EOP-01-LPC. As RPV level lowers, APRM downscales are received at +110 inches.
The maximum RPV level control band range, (highest level to lowest level), for these conditions is:
D. +90 inches to LL4
The unit is in an ATWS with the following conditions:
SLC Tank 30% and lowering
Reactor Water Level Being maintained 60 to 90 inches
Reactor Power APRMs downscale
Which one of the following choices completes the statement below in accordance with LPC?
Hot Shutdown Boron Injection Weight ___________ been injected and RPV water level _________ required to be raised at this tank level.
A. has
is
B. has
is not
C. has not
is
D. has not
is not
A. has
is
HSBW is 32% in the SLC tank; with level at 30% it has been injected. The flowcharts have you wait until HSBW has been injected and then directs level to be raised to provide mixing.
An ATWS has occurred on Unit One with the following plant conditions:
Reactor Water Level 130 inches (stable)
Injection Systems CRD
Reactor Power APRM downscale lights are illuminated
Control Rods 19 rods failed to insert
SRVs All closed
Suppression Pool Temp. 92° F
Which one of the following choices completes the statement below in accordance with LPC?
Reactor Recirculation pumps ____________ required to be tripped and the SLC Pumps
____________required to be started.
A. are not
are not
B. are not
are
C. are
are not
D. are
are
A. are not
are not
Per the Q leg of LPC, If power is > than 2%, then both recirc pumps are tripped. If the reactor cannot be
shutdown before the torus reaches 110°, then SLC is initiated.
An event on Unit One has resulted in the following plant conditions:
Reactor pressure: 1000 psig
Reactor Water Level 120 inches
Control Rods All unknown
APRMs Downscale
Drywell pressure: 3 psig
Supp. Pool pressure: 2 psig
Supp. Pool water temp: 150°F
Supp. Pool water level: -4 feet
Which one of the following identifies the status of the Heat Capacity Temperature limit
(HCTL), and also identifies the required procedure for reactor pressure control?
A. HCTL has been exceeded;
RVCP pressure control leg.
B. HCTL has been exceeded;
LPC pressure control leg.
C. HCTL has NOT been exceeded;
RVCP pressure control leg.
D. HCTL has NOT been exceeded;
LPC pressure control leg.
B. HCTL has been exceeded;
LPC pressure control leg.
Unit 2 has just experienced a reactor scram due to a small break LOCA inside the Primary Containment in which six control rods failed to fully insert.
Plant conditions are as follows:
Reactor power indication: IRMs inserted, on range 2 and slowly decreasing
Drywell pressure: 3.1 psig
Reactor pressure: 800 psig
Reactor water level: +190 inches and steady
Six control rod positions: between 08 and 32
After entry into EOP-01-RSP, the required operator actions are:
A. Enter EOP-01-LPC and execute concurrently with EOP-02-PCCP.
B. Exit EOP-01-RSP, perform EOP-01-LEP-02, and execute EOP-01-LPC, EOP-02-PCCP, EOP-01-RVCP concurrently.
C. Commence a normal shutdown to the Main Condenser and exit to GP-05.
D. Enter EOP-01-RVCP to control reactor pressure and level and execute it concurrently with EOP-01-RSP.
Look this up!
Following a large line break in the drywell, H2/02 monitors have been placed in service. Plant conditions:
Drywell hydrogen 2.5% (ERFIS)
Drywell oxygen 3.5% (ERFIS)
Torus hydrogen 1.4% (ERFIS)
Torus oxygen 3.5% (ERFIS)
Torus level -36 inches
EOP-02-PCCP directs venting and purging of Primary Containment:
B. within ODCM release rate limits, venting from the torus is preferred.
PCCP does not authorize purge operation above ODCM limits until directed to initiate CAD per OP24 when oxygen exceeds 4%. Torus venting is preferred to minimize off-site release rates due to scrubbing of iodine. Torus venting is unavailable if torus level is above +6 ft.
A steam leak in the drywell results in the following plant conditions:
Drywell pressure 5.0 psig
Suppr chamber pressure 4.0 psig
Drywell average temp 295°F
Suppr pool level -21 inches
Drywell spray:
C. should not be initiated since Reactor Building to torus vacuum breakers may open.
Drywell spray is directed before drywell temperature reaches 300°F or when suppression chamber pressure reaches 11.5 psig but only if the torus to drywell vacuum breakers are not submerged and in the safe region of DWSIL. Suppression chamber to drywell vacuum breakers are at +21 inches (not -21 inches). Since conditions are in the unsafe region of the drywell spray initiation limit, initiation of spray may cause negative pressure and de-inert the drywell by opening Reactor Building to torus vacuum breakers.
During accident conditions, suppression pool level has dropped below -6.5 feet.
Which one of the following identifies the required action for HPCI, including the basis for the action, in accordance with PCCP and 0OI-37.8, Primary' Containment Control Procedure Basis Document?
A. Terminate HPCI irrespective of adequate core cooling to prevent primary containment overpressurization.
B. Terminate HPCI irrespective of adequate core cooling to prevent exceeding Heat Capacity Temperature Limit.
C. Maintain HPCI operation if required to maintain adequate core cooling because core cooling takes priority over primary containment integrity.
D. Maintain HPCI operation if required to maintain adequate core cooling because the turbine exhaust flowrate is within the capacity of containment vent system.
A. Terminate HPCI irrespective of adequate core cooling to prevent primary containment overpressurization.
Per the PCCP, steps SP/L-26 and 27, if suppression pool level cannot be maintained above -6.5 feet then
secure HPCI irrespective of ACC. Per OI-37.8, the bases for these steps is to prevent primary
containment failure due to overpressurization.
Following a small steam line break in the drywell, plant conditions are as follows:
Drywell Pressure 20.8 psig
Drywell Average Air Temp. 292° F
Torus Pressure 19.0 psig
Reactor Pressure 675 psig
Reactor Water Level 100 inches
HPCI System Unavailable
RCIC System Started at LL2 and injecting
Which one of the following identifies the current status of the ADS Initiation Timer and
what operator action must be taken in accordance with PCCP?
ADS Initiation Timer ______ started;
Before Drywell Average Air temperature reaches 300°F, ___________.
A. has;
Drywell Spray is required
B. has not;
Drywell Spray is required
C. has;
Emergency Depressurization is required
D. has not;
Emergency Depressurization is required
B. has not;
Drywell Spray is required
The conditions required to start the ADS timer have not been meet. (LL3 / 45 inches)
The conditions listed require entry into PCCP. Per the direction of PCCP, before drywell average air temperature reaches 300F, spray the drywell.
Which one of the following is the primary containment pressure limit and the required action before this limit is reached in accordance with PCCP?
A. 62 psig
Vent primary containment irrespective of offsite release rate.
B. 62 psig
Vent primary containment only if offsite release rate do not exceed aDCM limits
C. 70 psig
Vent primary containment irrespective of offsite release rate
D. 70 psig
Vent primary containment only if offsite release rate do not exceed aDCM limits
C. 70 psig Vent primary containment irrespective of offsite release rate
The calculated peak containment pressure is 49.4 psig which is increased by 25% to
establish the drywell design pressure of 62 psig. The PCPL-A graph shows this limit is 70 psig.
Conditions on Unit Two have degraded to where the Drywell Air Temperature is 340° F.
Which one of the following identifies the components whose enviromental qualification
is affected by this temperature in accordance with 001-37.8, Primary Containment
Control Procedure Basis Document?
A. SRV solenoids
From the Bases document: Temperature should not be allowed to exceed the SRV maximum qualification temperature of 340° F.
Which one of the following is the suppression pool level when a manual reactor scram is first required including the required action in accordance with PCCP?
A. -5.5 feet
Anticipation of Emergency Depressurization is required.
B. -5.5 feet
Emergency Depressurization is required
C. -6.5 feet
Anticipation of Emergency Depressurization is required.
D. -6.5 feet
Emergency Depressurization is required
B. -5.5 feet
Emergency Depressurization is required
A manual scram has to be inserted before level drops below the downcomer vent openings. The reactor is not permitted to remain at pressure if suppression of steam discharged from the reactor cannot be assured.
An event on Unit One has resulted in the following plant conditions:
Reactor pressure: 1000 psig
Reactor Water Level 120 inches
Control Rods All unknown
APRMs Downscale
Drywell pressure: 3 psig
Supp. Pool pressure: 2 psig
Supp. Pool water temp: 150°F
Supp. Pool water level: -4 feet
Which one of the following identifies the status of the Heat Capacity Temperature limit
(HCTL), and also identifies the required procedure for reactor pressure control?
1. HCTL has been exceeded;
RVCP pressure control leg.
2. HCTL has been exceeded;
LPC pressure control leg.
3. HCTL has NOT been exceeded;
RVCP pressure control leg.
4. HCTL has NOT been exceeded;
LPC pressure control leg.
2. HCTL has been exceeded;
LPC pressure control leg.
While operating at power, the Unit Two RWCU line breaks downstream of the outboard isolation valve. Both inboard and outboard isolation valves fail to close. Plant conditions:
Reactor Building 20 ft temperature is 135°F
Reactor Building 50 ft temperature is 205°F
South CS Am Flood Level Hi alarm sealed in
South CS Am Flood Level Hi Hi alarm sealed in
The reactor has been manually scrammed. What actions are required to reduce the
leak rate in Secondary Containment, and how do conditions in Secondary
Containment affect Reactor level instruments N026NB?
C. Commence a cooldown not to exceed 100°F/hour. N026NB cannot be used to determine Reactor water level since Reactor Building 50 ft is above 140°F.
Two areas are above max safe, 50 ft is above max safe for temperature and CS room is above max safe for water level. Two areas above max safe require emergency depressurization if they are above max safe in the same table. Since temperature and water level are different tables, ED is not required; a cooldown is since a primary system is discharging and max normals have been exceeded. N026NB cannot be used when 50 ft (not 20 ft) temperature exceeds 140°F.
Following an event on Unit 2, the following conditions exist:
Reactor Pressure 1000 psig
Reference leg area temp 185°F
Control Rods All Rods Fully inserted
South CS Room Radiation 5 R/hr
MSR Drain Tank Radiation 7 R/hr
SOUTH CS RM FLOOD LEVEL HI HI Alarming (UA-12 1-3)
HPCI RM FLOOD LEVEL HI HI Alarming (UA-12 1-5)
Reactor water level -60” slowly lowering (N037)
-50” slowly lowering (N036)
There are no injection systems available with a primary system leaking into the secondary containment.
Why should the reactor be emergency depressurized?
D. More than one secondary containment area is above the Maximum Safe Operating Water Level.
An unisolable ateam leak on Unit 2 RCIC caused temperatures in South RHR to rise to 300°F. Following initiation of RHR room coolers, South RHR Room teperature drops to 200°F.
Engineering reports that the EQ envelop has been exccded for temperature on the Reactor Building 20’ elevation.
What actions are required?
B. Insert a manual scram, then perform emergency depressurization.
OI-37.9 R.1 page 38
If the maximum safe operating temperature is exceeded in an area and then later clears, and is subsequently followed by another area exceeding maximum safe operating temperature, action for two areas exceeding maximum safe operating temperature should be taken.
Which one of the following statements identifies the reason SCCP directs emergency depressurization based on temperature in accordance with 0OI-37.9, Secondary Containment Control Procedure Basis Document?
The reason the emergency depressurization is performed due to secondary containment temperature is to:
C. prevent damage to equipment required for safe shutdown.
The MSOT values are the area temperatures above which equipment necessary for the safe shutdown of the plant will fail. These area temperatures are utilized in establishing the conditions which reactor depressurization is required. The criteria of more than one area specified in this step identifies the rise in reactor building parameters as a wide spread problem which may pose a direct and immediate threat to secondary containment integrity, equipment located in the RB, and continued safe operation of the plant.
Unit Two has a line break with the following annunciators in alarm:
SOUTH CS RM FLOOD LEVEL HI
SOUTH RHR RM FLOOD LEVEL HI
SOUTH CS RM FLOOD LEVEL HI-HI
SOUTH RHR RM FLOOD LEVEL HI-HI
Which one of the following identifies the leak location and also identifies whether or not the Technical Specifications (TS) cooldown rate is required to be maintained?
Pipe break on the ____________.
TS cooldown rate __________ required to be maintained.
A. HPCI Turbine Steam Supply Line in the Steam Tunnel.
is
B. HPCI Turbine Steam Supply Line in the Steam Tunnel.
is not
C. RHR Service Water line above the RSDP.
is
D. RHR Service Water line above the RSDP.
is not
C. RHR Service Water line above the RSDP. is
First, determine that the leak has to be from the RHR and this is not a primary system. Then based on having two areas at max safe the operator should NOT ED cooldown would be within the TS limit.
Unit Two (2) is in Mode 1 when the HPCI Room Flood Level High alarm is received.
An AO sent to the HPCI room reports:
- HPCI room water is 6 inches and rising
- North RHR room water is 4 inches and rising through a leak in the watertight door
- The leak appears to be from the HPCI Torus suction line
Attempts to isolate the leak have failed and HPCI and North RHR Room water levels continue to rise with the following plant conditions:
- HPCI Room water level is 14 inches and rising
- North RHR Room water level is 12 inches and rising
Which one of the following describes actions required by the Emergency Operating Procedures?
Scram the Reactor:
B. or perform a Plant Shutdown per GP-05.
Suppression pool water does not fit the description of having come from a primary system as a reduction in reactor pressure does not result in a frduction in suppression pool water leak rate. (0OI-37.9)
Unit Two is operating under accident conditions with the following plant conditions due to a steam leak on HPCI:
Reactor Water Level -20 inches
Reactor Pressure 900 psig
Injection sources available HPCl only
Offsite Release Alert declared
HPCI Room Temperatures 140°F
Suppression Pool Temperature 130° F
Which one of the following identifies the required HPCI operation action in accordance with RRCP and also identifies the reason for taking the action?
A. HPCI should be left running
It is required to be operated by the EOP's
B. HPCI should be isolated
It should have isolated on room high temperature
C. HPCI should be left running
Steam leak detection was overridden per RVCP
D. HPCI should be isolated
To prevent damage to the HPCI pump due to high suppression pool temperatures
A. HPCI should be left running
It is required to be operated by the EOP's
RRCP normally has the operators isolate a primary system discharging except if it is needed to maintain adequate core cooling. With level below top of active fuel and required for EOP's this is the case. If there was a valid PCIS signal then this should not prevent the operator from making sure that the isolation occurs.
A fuel bundle was dropped in the spent fuel pool and 0AOP-5.0, Radioactive Spills, High Radiation, and Airborne Activity, has been entered.
The following alarms are received:
AREA RAD REFUEL FLOOR HIGH (UA-03 3-7)
PROCESS RX BLDG VENT RAD HI (UA-03 4-5)
RX BLDG ROOF VENT RAD HIGH (UA-03 2-3)
Which one of the following predicts the plant response and also identifies the required procedure implementation?
A. Secondary Containment has automatically isolated;
Execute 0AOP-5.0 and RRCP concurrently.
B. Secondary Containment has automatically isolated;
Execute RRCP and Exit 0AOP-5.0.
C. Secondary Containment has NOT automatically isolated;
Execute 0AOP-5.0 and RRCP concurrently.
D. Secondary Containment has NOT automatically isolated;
Execute RRCP and Exit 0AOP-5.0.
C. Secondary Containment has NOT automatically isolated;
Execute 0AOP-5.0 and RRCP concurrently.
Following a dual unit loss of off-site power, a line break in the Unit Two drywell results in the following plant conditions:
RPV water level Below TAF
RPV pressure 150 psig
RHR Loop A One pump Injecting @ 10,000 gpm
RHR Loop B Pumps tripped
Core Spray Neither available
SLC Pumps Injecting boron
Which of the following alternate coolant injection systems is available and can be aligned to inject with current plant conditions?
A. Service water.
Service water injection is available since RHR loop B pumps are tripped. Fire protection is not available since pressure is too high. Demin water not available since pumps are from common buses (de-energized due to dual unit LOOP). LPCI X-tie cannot be used since RHR Loop A is injecting.
Unit Two was operating at rated power. DC distribution panel12A tripped resulting in
loss of both Recirc pumps. Following a manual scram conditions are:
APRM indications 16%
Blue scram lights 137 illuminated
RWM display 124 rods not full in
What method per EOP-Ol-LEP·02. Alternate Control Rod Insertion, should be
performed and could be successful?
B. Insert control rods using RMCS.
ARI circuitry is powered from DC panel 12A and is energize to initiate. The scram blue lights indicate the scram valves are open; therefore, venting the scram air header will not be effective. Since scram valves are open, the scram pilot solenoids are already de-energized so placing test switches to test would also be ineffective. RMCS is available to insert rods and is directed by LEP-02.
During a low water level condition, the reactor operator is performing CRD system flow maximization per SEP-09. CRD parameters:
Two pumps running
FCV A in service and full open
Pressure control valve full open
Charging water header pressure 1150 psig
The reactor operator should direct an AO to increase system flow by throttling the Charging Water Header Isolation Valve (F034) in the:
B. open direction. Charging water header pressure indication will decrease.
Throttling open F034 will provide additional flow to the RPV because the scram inlet valve will be open providing a path from the charging header through the open scram valve and up through the CRDM (same path as cooling water). Since charging header pressure is sensed upstream of F034 (basically pump discharge), the header indication basically follows the pump curve. A lower limit is placed on this pressure to prevent pump runout (Note SEP-09 simply directs the operator to throttle the valve and not to throttle open the valve since the valve would have to be throttled closed if chargingheader pressure is too low.)
On Unit Two, the SRO directs the RO to place drywell sprays in service per 0EOP-01-SEP-02, Drywell Spray Procedure.
During the execution of SEP-02, SW-V111, Conv SW to Vital Header Vlv, trips on magnetics and remains in the full closed position.
Which one of the following describes the impact this failure will have on RHR/Drywell Spray system and also identifies the required operator actions in accordance with SEP-02?
A. loss of cooling water to RHR Room Coolers only;
Open SW-V117, Nuc SW to Vital Header Vlv.
B. loss of cooling water to RHR Room Coolers only;
Open SW-V118, Vital Header Crosstie Vlv.
C. loss of cooling water to RHR Room Coolers and RHR Pump Seal Coolers;
Open SW-V117, Nuc SW to Vital Header Vlv.
D. loss of cooling water to RHR Room Coolers and RHR Pump Seal Coolers;
Open SW-V118, Vital Header Crosstie Vlv.
C. loss of cooling water to RHR Room Coolers and RHR Pump Seal Coolers; Open SW-V117, Nuc SW to Vital Header Vlv.
SEP-02 directs supplying cooling water to the vital header by opening either the SW-V111 valve or the SW-V117 valve. If one is unavailable or trips, the procedure will direct opening the other valve. Opening the SW-V118 is not an option provided in SEP-02. The loads supplied by the vital header include the RHR Room Coolers and the RHR Pump Seal Coolers.
During the execution of emergency operating procedures, the operator has restarted Reactor Building HVAC per 0EOP-01-SEP-04, Reactor Building HVAC Restart Procedure.
Which one of the following subsequent conditions would cause the Reactor Building Supply and Exhaust Isolation Dampers to reclose?
D. REACTOR BUILDING VENT EXHAUST TEMP HI alarm is received.
SEP-04 installs jumpers or operates switches to override all Secondary Containment isolations but temperature
During an ATWS, circuit alterations are performed per EOP-SEP-10, Circuit Alteration Procedure, to prevent a Group I Isolation from occurring.
Which one of the following Group I Isolation signals is defeated by this circuit alteration and how is the alteration physically accomplished?
A. Low Reactor Water Level;
Installing jumpers
B. Low Condenser Vacuum;
Installing jumpers
C. Low Reactor Water Level;
Bypass Switch
D. Low Condenser Vacuum;
Bypass Switch
A. Low Reactor Water Level;
Installing jumpers
The Gp 1 Isolation signal is defeated in these conditions to prevent a closure of the MSIVs as reactor water level is intentionally lowered to assist in controlling power. Jumpers must be installed. There is a bypass switch for the Low condenser vacuum, but it is not in SEP-10.
During an emergency on Unit Two, EOP·01-StCP, Steam Cooling, is entered with an initial pressure of 900 psig. Plant conditions are now.
RPV water level -65 inches
RPV pressure 775 psig, slowly lowering
SRVs All Closed
Drywell ref leg temp 290°F
Injection sources None available
What action is required'?
D. Establish a new pressure band of 675 to 775 psig.
Steam cooling requires a pressure band 100psig below the pressure at which theprocedure is entered (initial band is 800·900psig) if pressure cannot be stabilized and is rising, emergency depressurization is required. If pressure cannot be maintained in the band and drops below the low end, StCP directs establishing a new band 100psig below current pressure. Emergency depressurization is also required lf level drops belowLL5. Using caution1 correction graphs, level is below LL4 but above LL5.
During execution of Steam Cooling on Unit Two (2), an initial pressure banc was set at 750 to 850 psig. Plant conditions are now.
RPV water level -70 inches
RPV pressure 600 psig
SRVs All closed
Drywell ref leg temp 185°F
What action is required?
D. Establish a new pressure band of 500 to 600 psig
Steam Cooling procedure requires setting pressure band 100 psig below current pressure.
During a low reactor water level emergency on Unit One, the Reactor Vessel Control Procedure directs the operator to enter the Steam Cooling Procedure.
Which one of the following describes the reason Steam Cooling Procedure is performed?
The Steam Cooling Procedure utilizes steam cooling heat transfer _________ injection to maximize the time peak clad temperatures in the uncovered portion of the core do not exceed ________ °F.
A. with
1500
B. with
1800
C. without
1500
D. without
1800
D. without
1800
Steam Cooling is entered when level drops below the minimum steam cooling reactor water level (LL4) and no injection sources are available. LL4 calculations are based on peak clad temperature of 1500°F. Steam cooling is meant to delay emergency depressurization with no injection sources until peak clad temperature reaches 1800°F, the basis for the minimum zero injection reactor water level or LL5. Note that if entry into steam cooling is required, peak clad temperature has already reached 1500°F by definition of LL4 .
During a Station Blackout on Unit 2, HPCI and RCIC are not available. Plant conditions are:
RPV level is -70 inches
RPV pressure is 800 psig
EDG #2 is the only operating DG
EDG #4 is tripped on overcurrent
Drywell ref leg area temp is 295°F
Fire protection is reported to be aligned with the exception of the LPCI injection valve (E11-F015B).
The reactor should be emergency depressurized:
A. Immediately
During a Station Blackout on Unit 2, HPCI and RCIC were not available. 2D RHR Pump has tripped on over current. Plant conditions are:
RPV level is -70 inches
RPV pressure is 800 psig
EDG #2 is the only operating DG
EDG #4 is tripped on overcurrent
Drywell ref leg area temp is 290°F
At this time, HPCI is reported to be available.
What action is required?
C. Operate HPCI to restore water level
During execution of Steam Cooling on Unit 2, an initial pressure band was set at 750 to 850 psig. Plant conditions are now:
RPV water level -65 inches
RPV pressure 725 psig
SRV’s All Closed
Drywell ref leg temp 290°F
What action is required?
B. Establish a new pressure band of 625-725 psig
During an accident on Unit One, Reactor Flooding is in progress. Plant conditions are:
RPV water level Unknown
Suppr chamber press 10 psig
SRVs 5 open
ECCS All available pumps injecting
The reactor can be determined to have been flooded to at least the Top of Active Fuel when RPV pressure has been at least:
A. 60 psig for 58 minutes.
Minimum RPV flooding pressure requires RPV pressure to be at least 50 psig above suppression chamber pressure with at least 5 SRVs open. Minimum core flooding interval is used to determine how long it takes to flood to TAF with the flooding pressure established for worst possible conditions. 58 minutes is the interval with 5 SRVs open (27 minutes is interval for 7 SRVs which is how many valves are normally opened for emergency depressurization.
Unit One (1) has experienced an accident that resulted in a loss of all Reactor Water Level Instrumentation. The reactor has been shutdown for fifteen (15) hours.Conditions of the Reactor Flooding Procedure have been established that allow terminating all injection to the reactor vessel.The MAXIMUM time injection may be terminated without being able to determine Reactor Water Level is approximately:
D. 7 minutes.
During an accident on Unit Two (2), REACTOR FLOODING is in progress per 0EOP-01-RXFP. Plant conditions are:
RPV water level UnknownControl rods 1 rod @ 48, all others fully insertedSuppr chamber press 40 psigSRVs 7 openRPV injection All available injection maximized
Which one of the following represents a MINIMUM reactor pressure and time that will ensure the RPV has been flooded to the Top of Active Fuel (TAF)?
C. Reactor pressure no less than 90 psig for 27 minutes.
Unit Two (2) has experienced a reactor scram due to LOCA conditions in the Drywell. Presently, NO level indication is available and the Reactor Flooding Procedure is in progress. Plant conditions are:
All rods inSRVs are open 5Reactor Pressure 65 psigTorus Pressure 12.5 psigA & B loop RHR Injecting to the reactor
Per EOP-01-RXFP, Reactor Flooding Procedure, injection is required to be secured and reactor water level lowered:
A. when a level instrument is available, its reference legs are less than 212oF and no less than 58 minutes has elapsed with reactor pressure exceeding torus pressure by at least 50 pounds.
An accident is in progress on Unit Two (2) that resulted in a loss of all Reactor Water Level indication one (1) hour ago. The reactor has been shutdown for seven and a half (7.5) hours.
I&C has informed the SCO that instrumentation is now available and the SCO has ordered termination of all injecton to the RPV to verify proper level indication.
The maximum time (in minutes) that injection may by terminated without being able to determine Reactor Water Level is approximately:
C. 6 minutes
During an accident, Reactor Flooding is in progress. Plant conditions are:
RPV water level Unknown
Control rods Fully inserted
Suppression Chamber press 20 psig
Suppression Chamber level -8.1 ft
The operator is required to:
A. perform SAMG-01, Primary Containment Flooding Procedure
Minimum Reactor Flooding pressue requires RPV pressure at least 50 psig above suppression chamber pressure for the minimum core flooding intervalused to assure core filled to TAF with 5 SRVs open. Alternate depressurization paths are not addressed in EOP-01-RXFP; therefore, SAMG-01 is required.
During a Unit One ATWS. emergency depressurization becomes required. Plant conditions are:
Reactor power 3%
RPV water level Below LL4
RPV pressure 600 psig, lowering
SRVs Only 3 can be opened
MSIVs Open with LL3 jumpers installed
EHC fluid system Unavailable due to header rupture
HPCI Injection valve will not open
SLC Injecting with two pumps
Which of the following methods should be used to assist in depressurization of the reactor per EOP-01-AEDP?
D. Main steam line drains.
AEDP gives a list of systems to use to rapidly depressurize the reactor. RWCU blowdown mode is listed but cannot be used (SLC is injecting boron) due to dilution of boron. HPCI pressure control is listed. but cannot be used (even though HPCI unavailable for injection) because an initiation signal from low level prevents opening test return valves. Turbine bypass valves will not open due to the loss of EHC fluid pressure. Main steam line drains are available and the 1st choice under these conditions. RWCU recirc mode would also be available but would require defeating Ll2 and SLC isolation interlocks.
During a Unit Two (2) accident, fuel failure exists. Emergency Depressurization is required. Plant conditions are:
RPV water level <LL4MSIVs Closed by direction of RRCPRPV pressure 1100 psigRCIC Injecting to the RPVHPCI Injection valve will not openSRVs Cannot be opened, cycling on lift setpoint
The operating crew should enter EOP-01-AEDP and:
D. Bypass all Group 1 isolations, then rapidly depressurize to the Main Condenser.
During a Unit Two (2) ATWS, Emergency Depressurizion is required. Plant conditions are:
The operating crew should terminate and prevent injection, then:
B. Rapidly depressurize to the main condenser using bypass valves per AEDP.
During execution of Alternate Emergency Depressurization Procedure, what Group isolation(s) may be overridden per the guidance of EOP-01-AEDP to establish a flowpath to the Main Condenser through the MSIVs?
