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0. Biennial Written Prep > EOP Week 4 > Flashcards

EOP Week 4 Flashcards

Deck Covers: E-2, ECA-2.1, FR-S.1, FR-S.2

1
Q

While in E-2 (Faulted Steam Generator Isolation) what actions are taken if ALL steam generators are faulted

A
  • Go to ECA-2.1 (Uncontrolled Depressurization of ALL SGs)
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2
Q

While in E-2 (Faulted Steam Generator Isolation) what actions are taken if Secondary Radiation levels (SG or SG PORV) are NOT normal

A
  • Go to E-3 (Steam Generator Tube Rupture)
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3
Q

While in E-2 (Faulted Steam Generator Isolation) what actions are taken if subcooling, heat sink, RCS pressure, and Pzr Level are satisfactory

A
  • Go to ES-1.1 (SI Termination)
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4
Q

While in E-2 (Faulted Steam Generator Isolation) what actions are taken if subcooling, heat sink, RCS pressure, and Pzr Level are NOT satisfactory

A
  • Go to E-1 (Loss of Reactor or Secondary Coolant)
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5
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) what actions are taken if Secondary Radiation levels (SG or SG PORV) are NOT normal

A
  • Go to E-3 (Steam Generator Tube Rupture)
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6
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) what actions are taken if RCS pressure is LESS THAN 300#

A
  • Go to E-1 (Loss of Reacotr or Secondary Coolant)

LB LOCA in progress

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7
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) what actions are taken if RWST Level is LESS THAN 30%

A
  • Go to ES-1.3 (Transfer to Cold Leg Recirculation)
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8
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) what actions are taken if RCS pressure is GREATER THAN 300# AND Accumulators DO NOT need to be isolated

A
  • Loop in the procedure until Pressurizer Level is satisfactory THEN reduce ECCS flow
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9
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) what actions are taken once ECCS flow has been reduced and RHR is placed in service for cooldown

A
  • Cooldown the RCS at LESS THAN 100 deg F per 60 minutes until less than 200 deg F
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10
Q

What are the Major Action Categories of E-2 (Faulted Steam Generator Isolation)

A
  • Check Main Steam Isolation
  • Check for at least one Non-Faulted SG
  • Identify and Isolate Faulted SG
  • Check for SGTR
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11
Q

What is the time critical action associated with E-2 (Faulted Steam Generator Isolation)

A
  • Isolate AFW to Faulted SG within 30 minutes of Reactor Trip
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12
Q

For a Steam Line Break upstream of the MSIVs what is the expected plant response

A
  • MSIVs close and depressurization continues
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13
Q

For a Steam Line Break downstream of the MSIVs what is the expected plant response

A
  • MSIVs close and depressurization stops (NO SI)
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14
Q

For a Feedwater break upstream of the FW Isolation check valves what is the expected plant response

A
  • Check valves seat and depressurization stops (NO SI)
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15
Q

For a Feedwater break downstream of the FW Isolation check valves what is the expected plant response

A
  • Check valves seat due to AFW, but depressurization continues
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16
Q

From E-2 (Faulted Steam Generator Isolation) what is the sequence of procedures that will be entered if NO SI is required

A
  • E-0 -> ES-0.1

Since there’s no SI you transition to ES-0.1 after immediate action steps are verified by US

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17
Q

From E-2 (Faulted Steam Generator Isolation) what is the sequence of procedures that will be entered if SI is ACTUATED

A
  • E-0 -> E-2 -> E-1 (if SG isn’t blown down) -> ES-1.1
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18
Q

With no operator action taken, what is the difference in plant response between a small and intermediate/large steam line break

A
  • Small break - MFW maintains SG lvls (NO Rx Trip)

- Large break - Rx Trip will occur after approx. 5 mins

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19
Q

While in E-2 (Faulted Steam Generator Isolation) AFTER RCS temperature stabilizes WHY is AFW periodically reduced

A
  • To maintain SG levels within band due to lowering decay heat levels
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20
Q

What are the important assumptions are made in the UFSAR Steamline break analysis

A
  • Most reactive rod stuck out
  • Return to criticality in part of the core
  • ECCS injecting through ONE CCP at 2400 ppm will restore subcriticality
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21
Q

During a Steamline break WHY is it important to control AFW flow

A
  • Prevent SG from drying out
  • Minimize RCS cooldown
  • Prevent SG overfill
  • Control RCS temperature after SG blowdown complete
22
Q

When mitigating a Steamline break, after transition is made to E-1 (Loss of Reactor or Secondary Coolant), if SG pressure is still lowering but attempts have been made to isolate the SG is transition back to E-2 (Faulted SG Isolation) required

A
  • No, the intent of the RNO is satisfied since isolation was attempted in E-2
23
Q

While in ECA-2.1 (Unctonrolled Depressurization of All Steam Generators) when can transition to E-2 (Faulted Steam Generator Isolation) be made?

A
  • Per the FOP if ANY SG pressure boundary is restored, except while performing SI termination
24
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) why would you not transition to E-2 (Faulted Steam Generator Isolation) during SI termination or FR-H.1 (Response to Loss of Secondary Heat Sink)

A
  • Because doing so would require introducing AFW to a potentially dried out SG and cause thermal shock
25
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) why is AFW flow lowered to 25k PPH.

(As opposed to isolating AFW to ALL SGs)

A
  • To prevent dryout of all SGs to minimize thermal shock
26
Q

During a Steamline break what SI actuation signals could cause an SI due to the steamline break

A
  • Low SG Pressure (500#)
  • SG dP (100#)
  • Low Pressurizer Pressure (1775#)
  • Containment Pressure Hi (1#)
27
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) why would you NOT stop RCPs

A
  • With RCPs running RCS cooldown is limited due to enhanced mixing
28
Q

While in ECA-2.1 (Uncontrolled Depressurization of All Steam Generators) why SHOULD you stop RCPs

A
  • If a SBLOCA is in progress (i.e., RCS less than 1300# w/ SI OR CCP flow)
29
Q

What are the immediate action steps of FR-S.1 (Response to ATWS)

A
  • Check Rx Trip
  • Manually Actuate AMSAC
  • Check Turbine Trip
30
Q

What are the RNO actions in FR-S.1 (Response to ATWS) if the Reactor IS NOT tripped

A
  • Manually trip reactor

- If reactor WILL NOT trip, manually insert control rods

31
Q

What are the RNO actions in FR-S.1 (Response to ATWS) if the Turbine IS NOT tripped

A
  • Manually trip turbine
  • If turbine WILL NOT trip, manually actuate ATWS runback on HMI
  • If turbine load CAN NOT be reduced, trip all SG stop valves closed AND verify SV dump valves closed
32
Q

What is the purpose of initiating a manual turbine trip in FR-S.1 (Response to ATWS) if the turbine CAN NOT be VERIFIED tripped

A
  • Prevents excessive RCS cooldown
33
Q

What is the purpose of manually actuating an ATWS runback on the turbine HMI in FR-S.1 (Response to ATWS) if the turbine WILL NOT TRIP

A
  • Conserves SG water levels
34
Q

What is the definition of an ATWS

A
  • A common cause failure which prevents control rods from being inserted into the core in response to an anticipated transient
35
Q

What is the RPS design basis

A
  • Maintain DNBR

- Maintain RCS below design pressure

36
Q

How is RCS Pressure boundary challenged during an ATWS

A
  • Rising RCS Pressure
37
Q

How is Fuel cladding challenged during an ATWS

A
  • Lowering DNBR
38
Q

How is Containment challenged during an ATWS

A
  • Uncontrolled RCS depressurization

Need to check CVI

39
Q

Should RCPs be tripped during an ATWS if WR power is greater than 5% and WHY

A
  • No

- Forced circulation provides core cooling and tripping RCPs could challenge fuel integrity

40
Q

Is BOL or EOL worse for an ATWS and WHY

A
  • BOL

- Less reactivity feedback

41
Q

During an ATWS why is RCS pressure checked to ensure it is less than Prz PORV setpoint

A
  • To maintain the ability to emergency borate
42
Q

What is the minimum AFW flow rate that is maintained during an ATWS

A
  • 450k pph until SG NR level is greater than 13%
43
Q

What is the major complication an SI poses during an ATWS

A
  • SI generates a FWI and trips the MFPs

Undesirable due to excessive core heat production compared to RCS heat removal. If RTB won’t open SI can’t be reset

44
Q

What are the potential causes of a loss of Subcriticality during an ATWS

A
  • Dilution
  • Cooldown
  • Rods not fully inserted
45
Q

What are the boration paths and WHEN are they used during an ATWS

A
  • Emergency Boration to CCP suction (1st choice)

- If NO SI, then to CCP via RWST OR normal boration to CCP

46
Q

How do the Reactor Trip Breaker trip coils trip the Reactor Trip Breaker

A
  • ENERGIZE to trip
47
Q

How do the Reactor Trip Breaker UV Coils trip the Reactor Trip Breaker

A
  • DE-ENERGIZE to trip coil
48
Q

How do the Reactor Trip Breaker shunt coils trip the Reactor Trip Breaker

A
  • ENERGIZE to trip coil
49
Q

Do the Reactor Trip Breaker BYPASS breakers have shunt coils

50
Q

If you are in FR-S.1 (Response to ATWS) what color is the Subcriticality CSFST

A
  • RED or ORANGE
51
Q

If you are in FR-S.2 (Response to Loss of Core Shutdown) what color is the Subcriticality CSFST

52
Q

Is adequate SDM required to exit FR-S.2 (Response to Loss of Core Shutdown)

A
  • NO, but boration is expected to continue after transition to other procedures to ensure SDM

0. Biennial Written Prep (12 decks)

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