EOPS

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skrappie1
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107766
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EOPS
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2016-10-17 22:31:34
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EOP NOTE CARDS
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  1. Indications of an excess steam demand event
    • containment high range monitors are not rising and do not corroborate the containment area monitors
    • PCS subcooling rise
    • S/G pressure falling
  2. Indications of a S/G tube rupture
    • steam plant activity > alarm setpoint or rising
    • unexplained rise in S/G level in one S/G
    • unexplained feed flow mismatch between S/Gs
    • unexplained loss of PCS inventory
  3. Design Basis Accident
    • containment structure shall withstand:
    • -total energy contained in the water of the PCS and released into the containment via a double-ended break of the largest primary coolant pipe coincident w/ a loss of offsite power
  4. Safety Function Hierarchy
    • reactivity control
    • maintenance of vital auxiliaries-electric
    • PCS inventory control
    • PCS pressure control
    • core heat removal
    • PCS heat removal
    • containment isolation
    • containment atmosphere
    • maintenance of vital auxiliaries-water
    • maintenance of vital auxiliaries-air
  5. Safety Function
    any condition or action needed to either prevent core damage or to minimize radiation releases to the general public. If all safety function acceptance criteria are satisfied, the safety function is preserved
  6. EOP-8.0, "Loss of offsite power/forced circulation recovery", entry conditions
    • 1. EOP 1.0 "Standard Post Trip Actions" has been performed
    • OR
    • The event initiated from a lower mode when Shutdown Cooling System is not initially in service.

    • 2. Plant conditions indicate that a loss of offsite power or a loss of forced circulation has occured as indicated by any or all of the following:
    • -Low flow RPS trip
    • -miscellaneous transformer alarms
    • -miscellaneous breaker trip alarms
    • -Diesel Generator auto start
    • -low PCP motor current
    • -PCP trouble or trip alarms
    • -Condenser vacuum alarm
    • -buses 1A and 1B low voltage
    • OR
    • A station blackout has occurred and at least one vital 2400V bus has been restored
    • OR
    • Single phase natural circulation is to be utilized for PCS heat removal and at least one of the following 4160V buses is energized:
    • -bus 1A
    • -bus 1B
  7. EOP 8.0, "Loss of Offsite Power/Forced Circulation Recovery", exit conditions.
    • 1. The diagnosis of a loss of offsite power or a loss of forced circulation is NOT confirmed.
    • OR
    • 2. Any of the Safety Function Status Check Sheet acceptance criteria are NOT satisfied AND corrective actions to restore the safety function are NOT effective.
    • OR
    • 3. The Loss of Forced Circulation Recovery procedure has accomplished its purpose by satisfying ALL of the following:
    • -at least one 4160VAC bus feeding the PCPs is energized.
    • -ALL Safety Function Status Check Sheet acceptance criteria are being satisfied.
    • -PCS conditions are being controlled and maintained.
    • -GOP-9.0 or other TSC/PRC approved procedure can be implemented.
  8. When does EOP-8.0, "Loss of Offsite Power/Forced Circulation Recovery", direct reopening CCW containment isolation valves?
    • When all of the following conditions exist:
    • -The following CCW Containment Isolation valves are closed due to a CHP signal:
    • --CV-0910
    • --CV-0911
    • --CV-0940
    • -Containment pressure is less than 35 psia and NOT rising
    • -"COMPONENT CLG SURGE TANK T-3 HI-LO LEVEL" (EK-1172) is NOT alarming
    • -Instrument Air pressure is greater than 85 psig
    • -CCW flow to and from the Containment has been isolated less than ten minutes
    • -At least one CCW pump is operating
  9. What is the EOP-8.0, "Loss of Offsite Power/Forced Circulation Recovery", SI pump throttling criteria?
    • Based on the Average of Qualified CETs, PCS subcooling meets ONE of the following:
    • -At least 25oF subcooled for non-degraded Containment conditions.
    • -Greater than the minimum subcooling curve on EOP Supplement 1 for degraded Containment conditions
    • Corrected PZR level is greater than 20% (40% for degraded Containment) and controlled. REFER TO EOP supplements 9 and 10.
    • At least one S/G is available for PCS heat removal with corrected level being maintained or being restored to between 60% and 70%. REFER TO EOP supplement 11.
    • Operable RVLMS channels indicate greater than 102 inches above the bottom of the fuel alignment plate (621'8"). -4 green lights
  10. What instruments are used to determine spay nozzle differential temperature in EOP-8.0 "Loss of Offsite Power/Forced Circulation Recovery"?
    • PZR Vapor Phase Temperature, TI-0101
    • Spray line temperature, TIA-0103 or TIA-0104 (use the lowest temperature if using main sprays)
    • Charging line temperature, TI-0212 (if using Auxiliary Spray)
  11. What is required when spray nozzle differential temperature is greater than 200oF, per EOP 8.0 "Loss of Offsite Power/Forced Circulation Recovery"?
    Record each occurrence of PZR spray operation with a differential temperature (PZR vapor phase temperature minus spray temperature) greater than 200oF in the Reactor Logbook.
  12. How is natural circulation flow verified for EOP-8.0 "Loss of Offsite Power/Forced Circulation Recovery"?
    • Core differential temperature less than 50oF (Average of Qualified CETs minus Tc)
    • Loop Ths and Loop Tcs constant or lowering
    • Average of Qualified CETs at least 25oF subcooled
    • Difference between Loop Th and Average of Qualified CETs is less than or equal to 15oF.
  13. What are indications of PCS voiding per EOP 8.0 "Loss of Offsite Power/Forced Circulation Recovery"?
    • Indicated Charging and Letdown flows do NOT correspond to PZR level trend.
    • PZR level rising significantly faster than trend expected from Auxiliary Spray Flow.
    • Core differential temperature (Average of Qualified CETs -Tc) or Loop differential temperature (Th-Tc) rising for same secondary steaming and Auxiliary Feed rates.
    • Any operable PCS temperature indication is less than 25oF subcooled.
    • Operable RVLMS indicates voiding in the Reactor Vessel.
  14. When does EOP-8.0, "Loss of Offsite Power/Forced Circulation Recovery", direct void elimination actions to be performed?
    • If PCS voiding is indicated AND ANY of the following exist:
    • -PCS pressure reduction is inhibited
    • -PCS heat removal is inhibited
    • -The Shift Supervisor directs void elimination.
  15. What conditions(Shutdown Cooling System entry conditions) must be met to transfer from EOP-8.0, "Loss of Offsite Power/Forced Circulation Recovery", to GOP-9, "Plant Cooldown From Hot Standby/Shutdown" or other TSC/PRC approved procedure for going on Shutdown Cooling?
    • PZR level is greater than 36% AND controlled
    • Average of Qualified CETs is at least 25oF subcooled
    • PCS pressure is less than 270psia as read on ANY of the following instruments:
    • -PI-0104 (C-02)
    • -PI-0105B (C-02)
    • -PI-0105A (C-12)
    • Average of Qualified CETs AND Loop Ths are less than 300oF
    • Shutdown Cooling System monitoring equipment power is available from Y-01
    • -OR
    • -Alternate measures for loss of Y-01 are established per ONP-17 "Loss of Shutdown Cooling"
    • LTOP is operable
    • The following valves have power available
    • -OR
    • -Containment access is acceptable for manual valve operation:
    • --MO-3015 (MCC-1)
    • --MO-3016 (MCC-2)
  16. What is degraded containment?
    Containment is considered degraded when containment temperature has exceeded 175oF or containment pressure has exceeded 3 psig.
  17. Why does containment need to be less than 35psia to restore CCW to containment?
    Prevents releasing the contents of containment through the CCW system.
  18. Why during EOP-8.0, "Loss of Offsite Power/Forced Circulation Recovery ", do you close both MSIVs, MSIV bypass valves, and all S/G blowdown valves if you don't have at least 1 cooling tower pump and at least 1 condensate pump operating?
    This prevents overpressurizing the Main Condenser in the event that you have lost Condenser cooling water.
  19. What is the PCP start criteria per EOP supplement 3 "Starting Primary Coolant Pumps"?
    • Bus 1A or 1B energized
    • Y-01 energized (power for bearing temperature and other PCP status indicators)
    • At least one S/G is available for removing heat (feed flow and steam flow) from the PCS.
    • Single phase natural circulation has been established for the preceding 20 minutes in the loop selected for the first PCP restart.
    • Pressurizer level as corrected in EOP Supplements 9 and 10 is between
    • -42-57% and controlled for the first PCP started.
    • -42-85% and controlled for subsequent PCP starts.
    • Saturation pressure using Pressurizer water phase temperature is greater than the Minimum Pressure for PCP Operation curve for the existing PCS temperature. REFER TO EOP Supplement 1, "Pressure Temperature Limit Curves."
    • Average of Qualified CETs is at least 25oF subcooled from EOP Supplement 1, "Pressure Temperature Limit Curves,""Upper Portion" curve.
    • CCW to PCPs has NOT been interrupted longer than ten minutes AND CCW is supplying the selected PCP.
    • At least one of the following PCP Controlled Bleedoff paths is open:
    • -PCP Controlled Bleedoff Stop Valve, CV-2191
    • -PCP Controlled Bleedoff Isolation Valves:
    • --CV-2083
    • --CV-2099
    • Positive indication of PCP Controlled Bleedoff Flow is evident for the PCP to be started (Panel C-11 recorders REC-C11-02 and REC-C11-03).
    • No more than one seal failed on the selected PCP.
    • At least one Oil Lift Pump for the selected PCP is available.
  20. What are the PCS heatup and cooldown rates?
    • </=170oF 20oF/HR 40oF/HR
    • c/d limited to 20F/HR after soak
    • >170oF</=250oF 40oF/HR 40oF/HR
    • >250oF<350oF 40oF/HR with MO-3015/3016 open 60oF/HR with MO-3015/3016 closed 60oF/HR
    • >/=350oF 100oF/HR 100oF/HR

    RED H/U BLUE C/D
  21. What are the EOP-7.0 "Loss of All Feedwater Recovery" entry conditions?
    • 1. EOP-1.0, "Standard Post Trip Actions," has been performed.
    • OR

    • The event initiated from a lower mode when the Shutdown Cooling System
    • is NOT initially in service.


    • 2. Plant conditions indicate that a loss of all feedwater has occurred as
    • indicated by ANY or all of the following:

    • a. Lowering Steam Generator water level or low S/G level alarm.
    • b. Main Feedwater Pump trip.
    • c. Low Main Feedwater Pump flow (or high flow with line break).
    • d. Low Main Feedwater Pump suction pressure.
    • e. Low Main Feedwater Pump discharge pressure.
    • f. AFAS/FOGG subsystem trip.
    • g. Auxiliary Feedwater Pumps fail to operate.
    • h. No Auxiliary Feedwater to both Steam Generators.
    • i. Low Auxiliary Feedwater Pump suction pressure.
    • j. Low Auxiliary Feedwater Pump discharge pressure.
    • k. AFW Pump trip.
  22. What are the EOP-7.0 "Loss of All Feedwater Recovery" exit conditions?
    • 1. The diagnosis of a loss of all feedwater is NOT confirmed.
    • OR
    • 2. ANY of the Safety Function Status Check Sheet acceptance criteria are
    • NOT satisfied
    • AND corrective actions to restore the safety function are NOT effective.
    • OR
    • 3. The Loss of All Feedwater Recovery procedure has accomplished its
    • purpose by satisfying ALL of the following:
    • • ALL Safety Function Status Check Sheet acceptance criteria are
    • being satisfied.
    • • Shutdown Cooling System entry conditions are satisfied
    • OR
    • Plant cooldown is NOT required and maintaining existing plant
    • conditions is desired
    • • An appropriate approved plant procedure can be implemented.
  23. Why during EOP-7.0 "Loss of All Feedwater Recovery" do we trip the PCPs?
    A Loss of All Feedwater results in a reduction of the ability of the Steam Generators to remove heat from the PCS. Since natural circulation heat removal is adequate to remove the decay heat generated in the core, the PCPs are stopped to eliminate their heat input to the PCS.
  24. Why during EOP-7.0 "Loss of All Feedwater Recovery" do we limit the feed flow to <300 gpm for any S/G with level <-84%?
    Because feeding to a dry S/G may cause significant S/G tube bundle damage.
  25. Per EOP-7.0 "Loss of All Feedwater Recovery", what do we consider a dry S/G?
    Level less than -125%.
  26. Per EOP-7.0 "Loss of All Feedwater Recovery", what is the preferred sources for S/G inventory replenishment?
    • a. Auxiliary Feedwater from T-2.
    • b. Main Feedwater from the Condenser.
    • c. Condensate Pump from the Condenser.
    • d. Auxiliary Feedwater from Service Water via P-8C.
    • e. Auxiliary Feedwater from Fire Water via P-8A or P-8B.
  27. Why during EOP-7.0 "Loss of All Feedwater Recovery" do we isolate T-2, condensate storage tank, from the hotwell?
    Prevents draining the contents of T-2, condensate storage tank, to the hotwell in the event that we will use T-2 as a source of inventory. It also prevents us from rejecting the contents of the hotwell back to T-2 in the event that we will not use T-2 as a makeup source.
  28. When during the performance of EOP-7.0 "Loss of All Feedwater Recovery" do we go to once through cooling?
    • IF ANY of the following conditions exist:
    • -BOTH S/G levels are below -84% AND are NOT being restored
    • - Tc rises uncontrollably 5oF or greater,
  29. What are the EOP-4.0 "Loss of Coolant Accident Recovery" entry conditions?
    • 1. EOP-1.0, "Standard Post Trip Actions," has been performed.
    • OR
    • The event initiated from a lower mode when the Shutdown Cooling System
    • is NOT initially in service.

    • 2. Plant conditions indicate that a LOCA has occurred as indicated by ANY of the following:
    • a. Abnormal Pressurizer level change (low or high)
    • b. Pressurizer pressure low for existing plant conditions
    • c. SIAS automatically activated
    • d. Standby Charging Pumps start
    • e. CHP or CHR alarms
    • f. Containment pressure, temperature or humidity high
    • g. Containment Sump level rising
    • h. Quench Tank level, temperature, or pressure high
    • I. Volume Control Tank level dropping
  30. What are the EOP-4.0 "Loss of Coolant Accident Recovery" exit conditions?
    • 1. The diagnosis of a LOCA is NOT confirmed.
    • OR
    • 2. ANY of the Safety Function Status Check Sheet acceptance criteria are
    • NOT satisfied
    • AND corrective actions to restore the safety function are NOT effective.
    • OR
    • 3. The Loss of Coolant Accident Recovery procedure has accomplished its
    • purpose by satisfying ALL of the following:
    • a. ALL Safety Function Status Check Sheet acceptance criteria are being satisfied
    • b. Shutdown Cooling entry conditions are satisfied
    • OR
    • The break has been isolated
    • OR
    • The PCS is in long term cooling
    • c. An appropriate approved plant procedure can be implemented
  31. Per EOP-4.0 "Loss of Coolant Accident Recovery", at what temperature do we trip the first and second primary coolant pumps?
    • When Tc <450oF only three PCPs are allowed to be running.
    • When Tc <300oF only two PCPs are allowed to be running.
  32. Why during EOP-4.0,"Loss of Coolant Accident Recovery", do you makeup to the SIRWT if the leak is outside of containment?
    Because you would lose your makeup source if the SIRWT swaps suctions at 2%.
  33. During EOP-4.0, "Loss of Coolant Accident Recovery", when can containment spray pumps be secured?
    • Containment spray pumps may be secured when all of the following conditions are satisfied:
    • -Containment pressure < 3 psig
    • -Containment spray operation not required for:
    • --containment ambient cooling
    • --HPSI subcooling
    • -NOTE: These conditions must be met prior to securing the last containment spray pump
    • --containment spray operation not needed for iodine removal as determined by chemistry or ALL of the following:
    • ---containment high range gamma monitors read <1800 R/hr
    • ---containment isolated per EOP supplement 6
    • ---less than 1 hour has elapsed since the reactor has tripped
  34. What are the minimum HPSI flow post-RAS per EOP-Supplement 4?
    • Condition                             Flow (gpm)
    • Subcooling I/S                      Total flow 760

    • Subcooling I/S with Hot Leg Injection
    •                                            Total flow 620
    •                                      cold legs total 300 
    •                                         hot leg total 325
  35. What conditions must be met per EOP-4, "Loss of Coolant Accident Recovery", prior to going on shutdown cooling?
    NOTE:  If degraded containment you must look at EOP Supplement 1 SDC entry window for degraded containment.

    • PCS pressure must be lower than 270 psia and stable or lowering.
    • Pressurizer level control must be greater than 36% (greater than 40% for degraded Containment) and controlled.
    • PCS subcooling as indicated by the Average of Qualified CETs must be greater than 25oF.
    • PCS temperature as indicated by the Average of Qualified CETs and Loop THs must be < 300oF.
    • PCS activity level has been determined by the TSC to be acceptable for circulation outside Containment.
    • Containment Spray Pumps must be not in use for the Containment Atmosphere Safety Function
    • SDC System monitoring equipment must have power available (Y-01)
    • LTOP operable.
    • Power to the following Shutdown Cooling Return Valves is available:
    • - MO-3015 (MCC-1)
    • - MO-3016 (MCC-2)
    • -OR
    • -Access to Containment is acceptable for manual valve operation.
  36. During EOP-7.0 "Loss of All Feedwater" during cooldown you are limited on PZR cooldown rates and PZR spray differential temperature. What are the limits and why?
    • Limits are in place to prevent damage to the PZR or spray nozzle.
    • Limited to 200oF/hr cooldown and 350oF differential temperature (PZR vapor temp-spray temp)
  37. What are the mitigating strategies for EOP-4.0 "Loss of Coolant Accident Recovery"?
    • Lower pressure to lower leakage
    • Optimize SI and throttle when throttle criteria is met
    • Establish S/G heat removal for subcooling and S/G coupling
    • Commence a rapid, controlled cooldown
    • Secure Containment Spray when criteria met
    • Prepare for and verify RAS actuation
  38. What are the mitigating strategies for EOP-7.0 "Loss of All Feedwater Recovery"?
    • Secure PCPs and conserve S/G inventory
    • Determine best FW option:
    • -AFW from T-2
    • -Main FW
    • -Condensate Pump
    • -AFW via SW/FPS
    • Re-establish FW or initiate once through cooling
  39. What are the mitigating strategies for EOP-8.0 "Loss of Offsite Power/Forced Circulation Recovery"?
    • Ensure D/Gs load and sequence
    • Emergency Borate
    • Start available air compressors
    • Ensure MSIVs closed (condensor protection)
    • Stabalize PCS Temp/Press using ADVs and aux spray
    • Verify Natural Circulation
  40. What conditions are required per EOP-4.0 "Loss of Coolant Accident Recovery" to initiate hot leg injection?
    • IF the elapsed time from event initiation (EOP Entry) is 5.5 hours AND Shutdown Cooling will NOT be in service prior to 6.5 hours after event initiation (EOP Entry) AND ANY of the following conditions are satisfied:
    • -Based on the Average of Qualified CETs, PCS subcooling meets ONE of the following:
    • --Less than 25oF subcooled for non-degraded Containment conditions
    • --Less than the minimum subcooling curve on EOP Supplement 1 for degraded Containment conditions
    • -Corrected PZR level is less than 20% (40% for degraded Containment) (Refer to EOP Supplements 9 and 10)
    • -Operable RVLMS channels indicate less than 102 inches above the bottom of fuel alignment plate
  41. What is the plant response with no operator action to a loss of forced circulation?
    • Reactor will trip due to low flow
    • Turbine and generator will trip due to the reactor trip
    • MFPs will (with 4160 VAC still available) ramp to minimum speed
    • S/G pressures will rise and eventually control >/= 900 psia by the TBV
    • PCS flows will lower as flywheel energy depletes
    • PZR pressure will lower
    • Tave will stabalize at 535oF (ADVs/TBV)
    • After 10-15 minutes, delta T = 17oF and natural circulation will have been established
    • S/G levels will raise to the high level override
  42. What safety functions are directly challenged in an uncomplicated loss of forced circulation event?
    None
  43. What are the prioritized steaming paths for EOP-8.0 "Loss of Forced Circulation"?
    • TBV
    • ASDV
    • P-8B
    • Hogger (not enough for 1st two hours post trip)
  44. What would cause the PZR to empty on a Primary Coolant Pump start?
    Collapsing steam voids
  45. Why during EOP-8.0 "Loss of Forced Circulation" must PCS boron be 50 PPM greater than the required concentration?
    To offset any outsurge from the PZR that is low in boron
  46. Why during EOP-8.0 "Loss of Forced Circulation Recovery" do we verify 20 minutes have elapsed since natural circulation has established prior to starting the first PCP?
    20 minutes of natural circulation prevents a slug of unborated water (condensate from steam that was generated in the core) from being transported to the core when the PCP is started.
  47. What is the reason we verify PZR level is between 42-57% and controlled for first PCP restart and 42-85% for additional pump starts during EOP-8.0 "Loss of Forced Circulation Recovery"?
    assures the PZR will not empty on a PCP start, due to voids in the PCS, the 85% assures protection against overpressurization
  48. What is the preferred water source order for EOP-7" Loss of All Feedwater Recovery"?
    • P-8A/C from T-2
    • P-8B from T-2
    • Main Feed from the Hotwell
    • Condensate Pumps from the Hotwell
    • P-8C from Service Water
    • P-8A/B from Fire Water
    • PORV-HPSI Once thru Cooling
  49. What would happen if a loss of all feedwater were to occur with no operator actions?
    • S/Gs will boil dry
    • This causes the PCS temperatures to rise rapidly to saturation conditions
    • When PCS saturation pressure rises to the setpoint of the PZR safeties, PCS inventory will be lost out of the safeties.
    • If this PCS inventory loss continues at this high pressure, the only method of injection into the core is through CVCS (charging pumps) as this pressure is above the HPSI shutoff head.
    • Thus core uncovery and core damage may occur.
  50. During EOP-7.0 "Loss of All Feedwater Recovery" will the rate of change of level vary during S/G fill activities? Why or Why not?
    Yes, the diameter of the S/G varies with elevation.
  51. What PCS pressure must we be below for once through cooling to be successful?
    approximately 1300 psia in order for the HPSI pumps to inject water, prior to that all we have is charging pumps for makeup.
  52. What pressure must the S/Gs be below in order to feed with a condensate pump?
    approximately 500 psia
  53. Per EOP-7.0 "Loss of All Feedwater" what level must be maintained in the condenser hotwell to provide adequate NPSH to the Condensate pumps when feeding to the S/Gs with a condensate pump?
    • 20% provides adequate NPSH
    • 40% is required by procedure
  54. Per EOP-7.0 "Loss of All Feedwater" how far open do we initially position the MFRV bypass valves when feeding with a condensate pump?
    Initially 10% open
  55. Per EOP-7.0 "Loss of All Feedwater" what flowrate are we limited to when feeding to the S/Gs with a condensate pump until we are at the desired levels? Why?
    • Initially limited to <300gpm to each S/G
    • The S/Gs are rated for a number of cycles of feeding using 32oF feedwater with the secondary side dry and at 600oF, provided initial feedwater flow is less than 300 gpm per S/G for up to eight cycles
  56. When is a Steam Generator considered dry per EOP-7.0 "Loss of All Feedwater"?
    • -125%
    • Feedwater flow restoration to a dry S/G (level less than -125%) may cause significant S/G tube bundle damage.
  57. What value is feedwater flow limited to when commencing feeding with any S/G level less than -84% per EOP-7.0 "Loss of All Feedwater"?
    Limit feed flow to less than 300 gpm for any S/G with level less than -84%.
  58. Per EOP-7.0 "Loss of All Feedwater" at what level can we start feeding the S/Gs with service water or firewater?
    • -75%
    • The value of -75% wide range level was chosen to allow the start of lake water flow into available S/Gs early enough to recover S/G levels prior to levels falling below the level for once through cooling (-84%).
  59. Per EOP-7.0 "Loss of All Feedwater", what is the required minimum flow from the AFW pumps?
    For P-8A and P-8B the required flow is 280 gpm (140 to each) at 985 psig to both steam generators or 280 gpm at 985 psig to one steam generator. For Pump P-8C, the required flow for the loss of feedwater event is 280 gpm (140 to each) at 900 psia to both steam generators or 280 gpm at 900 psia to one steam generator.
  60. What are the mitigating strategies of EOP-5.0 "Steam Generator Tube Rupture Recovery"?
    • Secure AFW to the affected S/G
    • Cooldown to <524oF and isolate affected S/G
    • Lower PCS pressure <940 psia
    • Throttle SIS
    • Commence a controlled cooldown
    • Monitor isolated S/G pressure
  61. What are the EOP-5.0 "Steam Generator Tube Rupture Recovery" entry conditions?
    • 1. EOP-1.0, "Standard Post Trip Actions," has been performed.
    • OR
    • The event initiated from a lower mode when the Shutdown Cooling System is NOT initially in service.
    • 2. Plant conditions indicate that a Steam Generator Tube Rupture has occurred as indicated by ANY of the following:
    • a. Rise in Condenser Off-Gas Monitor RIA-0631.
    • b. Rise in Steam Generator Blowdown Monitor RIA-0707.
    • c. Rise in Stack Gas Monitors:
    • • RIA-2325
    • • RIA-2326
    • • RIA-2327
    • d. Rise in Penetration/Fan Room Monitor RIA-5710.
    • e. Rise in Main Steam Line Monitors.
    • • RIA-2323
    • • RIA-2324
    • f. S/G sample analysis indicates high activity.
    • g. S/G Level rising.
    • h. Pressurizer level lowering.
    • i. Pressurizer pressure low (less than 2010 psia).
    • j. Feed flow, steam flow mismatched.
  62. What methods are available in order to maintain the isolated S/G <140% (110% for degraded containment) per EOP-5.0 "S/G Tube Rupture"?
    • Backflow
    • Blowdown to
    •   -radwaste
    •   -main condenser bypassing the blowdown demineralizers
    • Steam using the TBV
    • Steam using the ASDV'S
  63. During EOP-5.0 " Steam Generator Tube Rupture Recovery", where the affected S/G is isolated, what five means are available to cool the affected S/G to permit entry into SDC?
    • Backflow
    • Blowdown
    • Steaming to the Condenser
    • Ambient losses
    • Steam to the atmosphere
  64. During EOP-5.0 " Steam Generator Tube Rupture Recovery", why is it still important to isolate the affected S/G after both PCS and S/G system parameters are stable and controlled?
    Until the S/G is fully isolated, the release of radioactivity from the S/G to the secondary side, and potentially to the environment, continues.
  65. During EOP-5.0 " Steam Generator Tube Rupture Recovery", what control room indications may be used to diagnose which steam generator has a tube rupture?
    Main steam line monitors, S/G level indications, feed flow/steam flow.
  66. During EOP-5.0 " Steam Generator Tube Rupture Recovery", outside of the control room indications, what indications may be used to diagnose which S/G has a tube rupture?
    • Chemistry samples of both S/G blowdowns
    • Rad Pro surveys of the main steam lines
  67. How is a LOCA or PCS leak different from a SGTR?
    • Secondary radiation levels would not be affected during a LOCA
    • Containment radiation, pressure, temperature, humidity and sump levels are not affected during a SGTR
    • An inter-system LOCA would result in effects in that system, such as inventory changes, radiological changes, etc.
  68. Name at least two symptoms that are or could be the same and two different between a SGTR and an ESDE or Feed line break.
    • Similar
    • -PZR level lowering, PZR pressure lowering, Steam flow/feed flow mismatch.
    • Different
    • -T-ave lowering, lack of secondary radiation changes, loud noises on the secondary side, load changes on the turbine, subcooling rise, etc.
  69. What are the key parameters that should be monitored and trended during a SGTR event?
    • PZR level
    • PCS temperatures
    • S/G pressures
    • S/G levels
    • Off-gas radiation
    • Blowdown radiation
    • PZR pressure
    • Main steam line radiation
  70. Describe the response of the main steam line monitors, assuming a large SGTR in one of the S/Gs.
    The monitor on the affected S/G would begin rapidly rising immediately. The other monitor would rise after a few minutes, but only a small rise would be seen. When the reactor trips, the monitor on the affected S/G would rapidly lower to a value only slightly above the initial reading. The other monitor will stay only slightly elevated. Until isolated, both will lower slowly due primarily to dilution.
  71. What parameter trends from prior to a trip, during a SGTR event, would be useful to review to help identify and isolate the affected S/G?
    • Main steam line monitors
    • S/G levels
    • Feed/steam flow
  72. What automatic actions occur due to the Blowdown Monitor RIA-0707 high alarm?
    • Blowdown containment isolation valves CV-0770 and CV-0771 close
    • CV-0738, CV-0739, surface blowdown and recirc return valves close and cannot be opened until the alarm is cleared.
    • CV-0704, Blowdown to the Mixing Basin, closes and and cannot be opened until the alarm is cleared.
  73. What effect does power level have on the response of the radiation monitors, particularly the blowdown monitor, in the event of a SGTR?
    • At low power levels mixing in the tube bundle and recirculation to the down comer are reduced. Consequently, a leak will be less dilute at low-power levels resulting in a larger initial blowdown monitor indication than the same size leak at higher power levels.
    • However, at higher power levels the same increased mixing will make diluted steam generator leakage available to the blowdown line sooner than at low power levels.
  74. How does steam generator leak location affect the radiation monitor response, in particular the blowdown and off gas monitors?
    Leaks high in the tube bundle, away from the blowdown inlet line, may result in a delayed blowdown monitor response and accelerated response from the off gas monitor.
  75. How is the off gas monitor response affected by off gas flow rate?
    Higher off gas flow rates cause lower off gas monitor readings for the same size tube leak.
  76. What factors should be considered when establishing priorities for mitigating the consequences of a SGTR?
    • Maintaining primary system subcooling
    • Minimizing leakage between the primary and secondary system
    • Preventing or minimizing off site radioactive releases
    • Promptly isolating the ruptured S/G
    • Minimizing liquid radioactive waste
  77. If both main steam line monitors are not available, how would you identify the most affected S/G in a SGTR?
    • Trend S/G levels and feed flow
    • Have chemistry sample blowdowns
    • Have HP survey the main steam lines.
  78. What criteria must be satisfied prior to isolating the affected S/G during a SGTR?
    The affected S/G must be identified, and loop THs must be less than 524oF.
  79. What actions are taken during a S/G tube leak to minimize the extent of contamination on the secondary side?
    • Closing MSIVs after opening the MSIV bypass valve for the unaffected S/G
    • Isolating ADVs on the affected S/G
    • Isolating steam to P-8B from the affected S/G
    • Isolating vents on the flash tank and blowdown tank
    • Isolating condensate seal supply to both Heater Drain pumps
    • Aligning turbine building sump to the DWDT
    • Closing the steam dump drain traps
    • Supplying gland sealing steam from the plant heating boiler
    • Isolating feedpumps from the condenser
    • Isolating suction and condensate seal supply to the main feed pumps
    • Aligning heating boiler returns to T-2
    • Isolating main feed from the affected S/G
  80. What is the reason for the PCS pressure control criter of EOP-5.0 "Steam Generator Tube Rupture Recovery" which states to reduce and control PZR pressure within 50 psid of the affected S/Gs pressure?
    This is intended to minimize the transport of PCS inventory to the secondary side, and ensure that S/G inventory does not dilute PCS boron concentration.
  81. What two methods do we have to maintain pressure in the affected steam generator less than 940 psia per EOP-5.0 "Steam Generator Tube Rupture?
    If vacuum is greater than five inches use the TBV, and MSIV bypass valve to steam less than 900 psia.

    If vacuum is less than five inches, you must unisolate 1 ASDV on the affected steam generator and steam it to less than 900 psia.
  82. In the event of a steam generator tube rupture, what are some possible sources of unmonitored release of radioactivity?
    • Hogging air ejector
    • P-8B exhaust
    • Gland sealing steam
    • Code safeties
    • ADVs
  83. What are the mitigating strategies of EOP-6.0 "Excess Steam Demand Event"?
    • Secure AFW to the affected S/G
    • Steam the intact S/G to within 50psid of the faulted S/G
    • Throttle SIS
    • Stabalize PCS temperature/pressure when faulted S/G boils dry
    • Secure containment spray to preclude RAS
  84. What are the EOP-6.0 "Excess Steam Demand Event" entry conditions?
    • 1. EOP 1.0, "Standard Post Trip Actions," has been performed.
    • OR
    • The event initiated from a lower mode when the Shutdown Cooling System
    • is NOT initially in service.
    • 2. Plant conditions indicate an Excess Steam Demand Event has occurred. ANY of the following may be present:
    • a. Loud noise indicative of a high energy steam line break.
    • b. Lowering PCS T . AVE
    • c. Steam flow/feed flow mismatch.
    • d. Rise in feedwater flow.
    • e. Possible rise in Containment temperature, humidity, and Containment Sump level, with no significant radiation level increase on Containment Hi Range radiation monitors (Containment Area Monitors may fail high due to high temperature and humidity conditions).
    • f. Low pressure in affected S/G(s) following MSIV closure.
    • g. Possible rise in reactor power.
  85. Why during EOP-6.0 "Excess Steam Demand Event", after PCPs are secured, must you steam with the least affected steam generator prior to the most affected S/G boiling dry?
    • Prevents lifting the code safeties
    • Prevents pressurized thermal shock rupture of the PCS
  86. Per EOP-6.0 "Excess Steam Demand Event" what is minimal acceptable spray flow when containment pressure is greater than or equal to 4.0 psig?
    • With RAS not present and:
    • -one CS pump running and atleast 1 open spray valves you must have 1425 gpm total flow
    • -2 or 3 spray pumps running and both spray valves open you must have 2850 gpm total flow
  87. Why during EOP-6.0 "Excess Steam Demand Event", if containment pressure is greater than or equal to 4psig, do we ensure atleast one containment air cooler accident fan is operating?
    to minimize the chances of a H2 explosion or burn due to the buildup of H2 pockets
  88. Per EOP-6.0 "Excess Steam Demand Event" what is the minimum containment water level to provide adequate NPSH to the ESS pumps?
    594'1"
  89. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if the Main Turbine did not trip?
    IF the plant was operating at power AND MSIVs are open, THEN trip the turbine at panel C-01 (preferred) OR CLOSE both MSIVs
  90. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if the Main Generator Breakers or the MOD did not open?
    OPEN generator breakers at panel C-01 OR JUMPER terminals #1 and #10 on relay 487U (Y phase)
  91. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if speed cannot be lowered on either MFP?
    IF speed can't be lowered, THEN TRIP the main feed pump.
  92. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if MFRV'S or bypass FRV's will not close?
    IF MFRVs AND bypass FRVs can't be closed, THEN TRIP the Main Feed Pumps, and close the associated Feed Reg Block Valve, if the block valve will not close trip both Condensate Pumps.
  93. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Buses 1C or 1D are not energized?
    • ENSURE D/G started for but NOT energized
    • ENSURE associated D/G Bkr CLOSED.
  94. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if no S/G has level between 5% and 70%, or FW is not available?
    • For low level, ENSURE >/= 165gpm to at least one S/G.
    • For high level, REDUCE feedwater flow to the affected S/G.
    • SECURE feedwater flow to one S/G with indications of an ESDE or SGTR.
  95. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if TAVE is not between 525o and 540oF?
    • IF TAVE:
    • ->540oF THEN use TBV(preferred) or ADVs to restore TAVE to the normal band
    • -<525oF THEN ENSURE FW flow NOT excessive AND return TAVE to normal band with TBV(preferred) or ADVs
  96. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if either S/G pressure is not between 800 to 970 psia?
    • IF either S/G press:
    • ->970 psia, RESTORE to <970 psia using TBV (preferred) or ADVs.
    • -<800 psia, ENSURE CLOSED TBV, ADVs and both MSIVs
    • -<500 psia, ENSURE CLOSED both MSIVs AND ENSURE CLOSED MFRV and "Bypass" FRV on the affected S/G only
  97. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if the Containment Area monitors are not clear or there is an unexplained rise?
    • IF, any two Containment Area Monitors are Trip 2 status, THEN:
    •   VERIFY EK-1126, "CIS INITIATED," OR PUSH left and right "High Radiation Initiate" pushbuttons
    •   CORROBORATE readings by comparing to Containment High Range Monitor readings (RIA-2321, RIA-2322)
  98. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if you don't have at least 1 condensate pump and 1 CT pump operating?
    CLOSE both MSIVs
  99. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Rx power is not lowering?
    • PUSH Rx Trip Pushbuttons C-02 and C-06
    • OPEN breakers 42-1 and 42-2
    • PLACE CRD Toggle Switches to OFF
  100. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if there is more than 1 full length control rod not fully inserted?
    Emergency Borate
  101. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Pzr Pressure is not 1650-2185 psia and trending 2010-2100 psia?
    • Operate Pzr Press Control Sys. OR manually operate Pzr Htrs and Sprays
    • -<1605 psia, VERIFY SIAS initiated (EK-1342) OR push "initiate" pushbuttons
    • -ENSURE available HPSI and LPSI pumps operating with loop isolation valves open
    • -<1300 psia, STOP two PCPs (one in each loop)
    • -< min pump operating limit-STOP all PCPs
  102. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Containment pressure is not <.85 psig for containment isolation?
    • IF >/= 4.0 psig:
    • VERIFY "CIS INITIATED" (EK-1126)
    • OR push left and right "High Radiation Initiate" pushbuttons
    • ENSURE closed MSIVs, MFRVs, Bypass FRVs and CCW isolation valves
    • VERIFY "SIAS INITIATED" (EK-1342)
    • OR push "Initiate" pushbuttons
    • ENSURE available HPSI and LPSI pumps are operating with loop isolation valves open
  103. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Containment temperature is not <125oF?
    • ENSURE all available CAC fans are running
    • OPEN CAC HI CAPs as capacity permits
  104. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Containment pressure is not <.85 psig for containment atmosphere?
    • ENSURE all available CAC fans running
    • OPEN CAC HI CAPs as capacity permits
    • IF >/= 4.0 psig:
    • -ENSURE all available CAC 'A' recirc fans operating
    • -ENSURE open all available containment spray valves
    • -ENSURE all available spray pumps are operating.
  105. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if at least 2 SW pumps are not operating?
    START available SW pumps
  106. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if either critical SW headers is <42 psig?
    • START available SW pumps
    • IF press <42 psig and NO SIAS,
    • -THEN ENSURE CLOSED CAC HI CAPs as necessary to raise SW hdr pressure to > 42psig.
    • IF press <42 psig and all CAC HI CAPs are closed, then ENSURE CLOSED CV-1359
  107. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if no CCW pumps are operating?
    START available CCW pumps.
  108. During EOP-1.0 "Standard Post Trip Actions" what are the contingency actions if Instrument air pressure is < 85 psig?
    • START available Instrument Air Compressors as necessary
    • IF FWP air supply available, then open Cross-Tie Valve as necessary
  109. What is the mitigating strategy for EOP-3.0 "Station Blackout Recovery"?
    • Minimize PCS inventory loss
    • Diagnosis of best option for restoring power:
    • - DG
    • - Safeguards/ Startup Power
    • - Backfeed (Segreto #1 line best)
    • Monitor station battery discharge current/strip loads
  110. What are the EOP-3.0 "Station Blackout Recovery" entry conditions?
    • 1. a. EOP-1.0, "Standard Post Trip Actions," has been performed.
    • OR
    • b. The event initiated from a lower mode when the Shutdown Cooling System is NOT initially in service.
    • 2. Plant conditions indicate that a Station Blackout electrical emergency has occurred as indicated by ANY or all of the following:
    • a. Loss of Control Room normal lighting
    • b. Extensive loss of various indications
    • c. Equipment "Loss Of Power" alarms
    • d. Tripped breaker indications on 4160 VAC and 2400 VAC Buses
    • e. Extensive loss of equipment power available indications
    • f. Bus 1C/1D Undervoltage or lockout alarm
    • g. Diesel Generators do NOT start or fail to load
  111. What are the EOP-3.0 "Station Blackout Recovery" exit conditions?
    • 1. The diagnosis of a Station Blackout is NOT confirmed.
    • OR
    • 2. ANY of the Safety Function Status Check Sheet acceptance criteria are NOT satisfied
    • AND corrective actions to restore the safety function are NOT effective.
    • OR
    • 3. The STATION BLACKOUT RECOVERY procedure has accomplished its purpose by satisfying ALL of the following:
    • a. At least one vital 2400 VAC bus and its associated equipment has been restored.
    • b. ALL Safety Function Status Check Sheet acceptance criteria are being satisfied.
    • c. An appropriate approved plant procedure can be implemented.
  112. When does EOP-3.0 "Station Blackout Recovery" direct tripping the operating Diesel Generator?
    • Jacket Water temperature is greater than or equal to 195F
    • Lube Oil temperature is greater than or equal to 200F
  113. What are the expected automatic actions associated with EOP-3.0 "Station Blackout Recovery"?
    • P-8B starts and delivers AFW to both S/Gs
    • PCS begins to heat up until the ADVs take control (should maintain ~535oF)
    • S/G code safeties cycle open and closed to maintain Tave <545oF if the ADVs are not working
    • PZR level slowly lowers due to PCP controlled bleedoff relieving to the PSDT
  114. During EOP-3.0 "Station Blackout Recovery", what are the options for recovery of an available power source?
    • S/G transformer 1-1
    • S/U transformer 1-2
    • D/G 1-1 (Bus 1C)
    • D/G 1-2 (Bus 1D)
    • Backfeed through the Main Transformer
  115. What are the EOP-9.0 "Functional Recovery Procedure" entry conditions?
    • 1. EOP-1.0, "Standard Post Trip Actions," has been performed.
    • OR
    • The event initiated from a lower mode when the Shutdown Cooling System is NOT initially in service.
    • 2. ANY of the following conditions may be present:
    • a. A Reactor trip with unusual concurrent symptoms and diagnosis of one event NOT immediately apparent.
    • b. Any conditions/symptoms which a licensed operator considers serious and for which other Emergency/Off-Normal Procedures can NOT be identified.
    • c. Actions from an in-use Optimal Recovery EOP do NOT result in acceptance criteria for in-use Optimal Recovery EOP Safety Function Status Check Sheet being satisfied.
    • d. An Optimal Recovery EOP step directs implementation of EOP-9.0, "Functional Recovery Procedure."
  116. What are the EOP-9.0 "Functional Recovery Procedure" exit conditions?
    • 1. The Functional Recovery procedure has accomplished its purpose by satisfying ALL of the following:
    • a. The acceptance criteria for ALL success paths in use are being satisfied.
    • b. An appropriate approved plant procedure can be implemented.
  117. Per EOP-9.0 "Functional Recovery Procedure", what is the minimum post RAS safeguards train flow?
    600 gpm in each operating train
  118. What is the value of HPSI shutoff head?
    1214 psia
  119. What are the SI pump throttling criteria per EOP-9.0 "Functional Recovery Procedure"? Why the difference?
    • Based on the Average of Qualified CETs, PCS subcooling meets ONE of the
    • following:
    • • At least 25F subcooled for non-degraded Containment conditions
    • • Greater than the minimum subcooling curve on EOP Supplement 1 for degraded
    • Containment conditions
    • b. Corrected PZR level is greater than 20% (40% for degraded Containment) and controlled. REFER TO EOP Supplements
    • 9 and 10.
    • c. At least one S/G is available for PCS heat removal with corrected level being maintained or being restored to between 60% and 70%. REFER TO EOP Supplement
    • 11.
    • d. Operable RVLMS channels indicate greater than 102 inches above the bottom of fuel alignment plate.
    • e. Reactivity control safety function is satisfied as defined in the acceptance criteria.

    EOP-9.0 RC-3 is counting on this boration from safety injection to safely shutdown the reactor, therefore you shouldn't throttle safety injection till you meet the reactivity control safety function.
  120. During EOP-9.0 "Functional Recovery Procedure", what criteria determines if IC-1(CVCS) is met?
    • a. PZR level is greater than 20%.
    • b. PCS subcooling is greater than or equal to 25oF based on the average of Qualified CETs.
    • c. Operable RVLMS channels indicate greater than 102 inches above the bottom of fuel alignment plate (621' 8").
  121. At what containment water level do we ensure the LPSI loop injection valves are open and their associated breakers are open?
    595.75'
  122. At what containment water level do we ensure the HPSI loop injection valves and their associated breakers are open?
    596.33'
  123. What is the minimum containment water level to provide adequate NPSH to the ESS pumps post RAS?
    594'1"
  124. During EOP-9.0 "Functional Recovery Procedure" how do you verify IC-2(Safety Injection) is satisfied?
    • a. IF RAS has NOT occurred, AND SI Pump throttling criteria NOT met, THEN ALL available Charging Pumps operating
    • b. IF SI Pump throttling criteria NOT met, THEN HPSI flow is within the requirements of EOP Supplement 4
    • c. IF RAS has NOT occurred AND PZR pressure is less than 200 psia, THEN LPSI flow is within the requirements of EOP Supplement 4
    • d. Operable RVLMS channels indicate greater than 11 inches above the bottom of fuel alignment plate (614' 0")
    • e. Containment water level is less than 595.75'
    •     OR
    •     All LPSI Injection Valves that had power available are open and associated breakers are open
    • f. Containment water level is less than 596.33'
    •     OR
    •    All HPSI Injection Valves that had power available are open and associated breakers are open.
    • g. Post-RAS HPSI Pump Subcooling requirements met. REFER TO EOP Supplement 42.
  125. What is the maximum containment water level for operation of pressurizer heaters?
    590'6"
  126. During EOP-9.0 "Functional Recovery Procedure" how do we verify PC-1 (Subcooled Pressure Control) is satisfied?
    PZR pressure within the limits of EOP Supplement 1.
  127. Per EOP-9.0 "Functional Recovery Procedure" what are the PORV closing criteria of PC-2?
    • • PZR pressure is less than 2100 psia
    • • PZR pressure is less than the maximum limits of EOP Supplement 1
    • • Success path HR-3, "Once-Through-Cooling," is NOT in use
    • • PORVs are NOT required open to reduce PZR pressure
  128. During EOP-9.0 "Functional Recovery Procedure" how do we verify PC-2 (PORVs) is satisfied?
    PZR pressure within the limits of EOP Supplement 1
  129. During EOP-9.0 "Functional Recovery Procedure" how do we verify PC-3 (Saturated Pressure Control) is satisfied?
    • a. IF RAS has NOT occurred, AND SI Pump throttling criteria NOT met, THEN ALL available Charging Pumps operating.
    • b. IF SI Pump throttling criteria NOT met, THEN HPSI flow is within the requirements of EOP Supplement 4.
    • c. IF RAS has NOT occurred AND PZR pressure is less than 200 psia, THEN LPSI flow is within the requirements of EOP Supplement 4.
  130. What methods do we have available during EOP-9.0 "Functional Recovery Procedure" to maintain the isolated S/G (SGTR) level less than 140% (110% for degraded containment)?
    • a. BACKFLOW the isolated S/G to the PCS as follows:
    • 1) LOWER PZR pressure using the following criteria
    • • less than the isolated S/G pressure.
    • • no greater than 50 psid
    • 2) WHEN the isolated S/G
    • level is less than 140% (110% for degraded containment conditions), THEN RAISE PZR pressure such that flow between the PCS and the S/G is minimized.
    • b. BLOWDOWN the isolated S/G to one of the following in order of preference:
    • 1) To the radwaste system REFER TO EOP Supplement 16.
    • 2) To the main condenser bypassing the blowdown demineralizers. REFER TO SOP-7, "Main Steam System."
    • c. STEAM the isolated S/G to the main condenser using the TBV.
    • d. STEAM the isolated S/G to atmosphere using the ASDVs.
  131. During a SGTR, while backflowing the most affected S/G to the PCS, how much of an effect will this have on PCS chemistry?
    For a 1% decrease in S/G level, there will be a 0.5% decrease in PCS boron concentration.
  132. What are the disadvantages of using feedwater and the blowdown system to cooldown the most affected S/G during a SGTR?
    • • Additional contamination of sections of the secondary system
    • • Generation of additional contaminated water in sections of the secondary system
    • • Increased probability of un-monitored airborne releases from existing secondary leaks
    • • Relatively slow cooldown rate. The S/G is drained to 30% level [top of the tube bundle] and refilled to 85% level [top of indicating range]
  133. What methods (in order of preference) are available for cooling the isolated S/G in the event of a SGTR?
    • Backflow from the S/G to the PCS
    • Cooldown via the blowdown system
    • Steaming to the condenser
    • Cooldown via losses to ambient
    • Steaming to the atmosphere
  134. During EOP-9.0 "Functional Recovery Procedure", how do we verify that HR-1 (PCS and Core Heat Removal Via S/G with SI NOT in operation) is satisfied?
    • a. At least one S/G has:
    •  (1) Level being maintained between 60% and 70% with feedwater available
    •   OR
    •  (2) Level greater than -84% and restoring to between 60% and 70%
    • b. IF PCPs are operating, THEN PCS loop delta T is less than 10°F
    • c. IF PCPs are NOT operating, THEN PCS loop delta T is less than 50°F
    • d. PCS subcooling is greater than or equal to 25°F based on the average of Qualified CETs
    • e. No voiding indicated on Operable RVLMS channels
  135. During EOP-9.0 "Functional Recovery Procedure", how do we verify that HR-2 (PCS/Core Heat Removal via S/G with SI operating) is satisfied?
    • a. At least one S/G has:
    •  (1) Level being maintained between 60% and 70% with feedwater available
    •  OR
    •  (2) Level greater than -84% and restoring to between 60% and 70%
    • b. Average of Qualified CETs NOT superheated.
    • c. IF RAS has NOT occurred AND SI Pump throttling criteria NOT met, THEN ALL available Charging Pumps operating.
    • d. IF SI Pump throttling criteria NOT met, THEN HPSI flow is within the requirements of EOP Supplement 4.
    • e. IF RAS has NOT occurred AND PZR pressure is less than 200 psia, THEN LPSI flow is within the requirements of EOP Supplement 4
  136. During EOP-9.0 "Functional Recovery Procedure", what are the criteria for securing from once through cooling?
    • • At least ONE S/G has level greater than or equal to -84% with feed and steam flow capability
    • • The Average of Qualified CETs temperature is less than the saturation temperature for the LTOP setpoint AND NOT rising
    • • Operable RVLMS channels indicate greater than 102 inches above the bottom of fuel alignment plate (621' 8").
    • • PORVs are NOT in use for PCS Pressure Control success path PC-2.
  137. During EOP-9.0 "Functional Recovery Procedure", how do we verify that HR-3 (PCS/Core Heat Removal via Once-Through-Cooling) is satisfied?
    • a. Average of Qualified CETs NOT superheated.
    • b. IF RAS has NOT occurred, AND SI Pump throttling criteria NOT met, THEN ALL available Charging Pumps operating.
    • c. IF SI Pump throttling criteria NOT met, THEN HPSI flow is within the requirements of EOP Supplement 4.
    • d. IF RAS has NOT occurred AND PZR pressure is less than 200 psia, THEN LPSI flow is within the requirements of EOP Supplement 4.
    • e. Pressurizer pressure less than 1214 psia or lowering.
  138. During EOP-9.0 "Functional Recovery Procedure", how do we verify that RC-1 (Control Rod insertion) is satisfied?
    • Condition 1:
    • a. Maximum of one full-length control rod NOT fully inserted
    • b. Rx power lowering and a negative Startup Rate
    • Condition 2:
    • a. Rx power is less than 10-6% and is constant or lowering on Wide Range Excore indication
    • OR
    • Rx power is less than 100 cps and is constant or lowering on Source Range excore indication
  139. During EOP-9.0 "Functional Recovery Procedure", how do we verify that RC-2 (Boration using CVCS) is satisfied?
    • Condition 1:
    • a. Borating at greater than 33 gpm
    • b. Rx power lowering and a negative Startup Rate
    • Condition 2:
    • a. Rx power is less than 10-6% and is constant or lowering on Wide Range Excore indication
    • OR
    • Rx power is less than 100 cps and is constant or lowering on Source Range excore indication
  140. During EOP-9.0 "Functional Recovery Procedure", how do we verify that RC-3 (Boration using SIS) is satisfied?
    • Condition 1:
    • a. Borating at greater than 33 gpm
    • b. Rx power lowering and a negative Startup Rate
    • Condition 2:
    • a. Rx power is less than 10-6% and is constant or lowering on Wide Range Excore indication
    • OR
    • Rx power is less than 100 cps and is constant or lowering on Source Range excore indication
  141. During EOP-9.0 "Functional Recovery Procedure", how do we verify that CI-1 (Automatic/Manual isolation) is satisfied?
    • Condition 1
    •   a. Containment pressure is less than 4.0 psig
    •    PIA-1814
    •    PIA-1815
    •  
    •   b. Containment Area Monitors indicate no unexplained rise in activity and alarms are clear:
    •    RIA-1805
    •    RIA-1806
    •    RIA-1807
    •    RIA-1808

    •   c. ANY of the following:
    •     (1) Condenser Off Gas Monitor RIA-0631 indicates no unexplained rise in activity and alarm is clear
    •              AND
    •      Main Steam Line Monitors indicate no unexplained rise in activity and alarms are clear:
    •      RIA-2323
    •      RIA-2324

             OR

             (2) The S/G with the largest SGTR identified and isolated AND TH is less than 541°F 

    • Condition 2
    •   a. Each Containment penetration NOT in use for other safety functions has at least one isolation valve closed per EOP Supplement 6

    •   b. ANY of the following:
    •     (1) Condenser Off Gas Monitor RIA-0631 indicates no unexplained rise in activity and alarm is clear
    •             AND
    •           Main Steam Line Monitors indicate no unexplained rise in activity and alarms are clear:
    •              RIA-2323
    •              RIA-2324

    •     OR
    •     (2) The S/G with the largest SGTR identified and isolated AND TH is less than 541°F
  142. During EOP-9.0 "Functional Recovery Procedure", how do we verify that CA-1 (Containment Air Coolers Normal Mode) is satisfied?
    • Containment temperature is less than 125oF
    • Containment pressure is less than 0.85 psig
    • Containment Hydrogen concentration is less than 3%
  143. During EOP-9.0 "Functional Recovery Procedure", how do we verify that CA-2 (Containment Air Coolers Emergency Mode) is satisfied?
    • a. Containment Air Coolers (CACs) aligned as follows:
    •   V-1-3A operating
    •   VHX 1-3 high caps open (CV-0861/0864/0873)
    •   VHX 4 SW inlet closed (CV-0869)
    • b. Containment temperature less than 225°F
    • c. Containment pressure is less than 4.0 psig
    •   PIA-1814
    •   PIA-1815
    • d. Containment hydrogen concentration less than 3%
    • e. Containment water level is less than 596.62'
  144. During EOP-9.0 "Functional Recovery Procedure", how do we verify that CA-3 (Containment Spray) is satisfied?
    • a. Containment pressure is less than 70 psia.
    • b. Containment Cooling Option 1 or 2 in operation. REFER TO Table CA in this step.
    • c. Containment hydrogen concentration is less than 3%.
    • d. Containment water level less than 596.62'
  145. During EOP-9.0 "Functional Recovery Procedure", how do we verify that MVAA-1 (Instrument Air Compressors) is satisfied?
    Instrument Air header pressure is greater than 85 psig
  146. During EOP-9.0 "Functional Recovery Procedure", how do we verify that MVAA-2 (FWP Air Compressors) is satisfied?
    Instrument Air header pressure is greater than 85 psig
  147. During EOP-9.0 "Functional Recovery Procedure", what criteria determines if MVAE-DC-1(Battery Chargers/ Station Batteries) is met?
    • a. At least ONE of the following 125V DC bus trains energized:
    •   D11A, D11-1, and D11-2
    •   D21A and D21-1
    • b. 125V DC Bus D21-2 energized
    • c. At least three of four Preferred 120V AC Buses energized
    • d. IF greater than 30 minutes elapsed since the loss of battery chargers, THEN the discharge rate of each station battery less than or equal to the load limit specified in EOP Supplement 7 and 8
  148. During EOP-9.0 "Functional Recovery Procedure", what criteria determines if MVAE-AC-1(Offsite Power) is met?
    • a. At least one of the following 2400V AC bus energized including control power:
    •    Bus 1C
    •    Bus 1D
  149. During EOP-9.0 "Functional Recovery Procedure", what criteria determines if MVAE-AC-2(Diesel Generator) is met?
    • a. At least one of the following 2400V AC bus energized including control power:
    •    Bus 1C
    •    Bus 1D

    • CAUTION Each D/G is limited to the following load rating:
    •   • 2500 KW continuous
    •   • 2750 KW two hours per 24 hour period

     b. Operating D/G within load limits
  150. During EOP-9.0 "Functional Recovery Procedure", what criteria determines if MVAE-AC-3(Backfeeding Main Transformer) is met?
    • a. At least one of the following 2400V AC bus energized including control power:
    •    Bus 1C
    •    Bus 1D

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