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RO31 ILT > Steam Generating/SGWLC/Blowdown > Flashcards

Steam Generating/SGWLC/Blowdown Flashcards

1
Q

What side of the SG are most of the FW J Tubes?

A
  • 80% are on the Hot Leg side of U-Tubes
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2
Q

What do the J tubes help to prevent?

A
  • Water Hammer when AFW initiates
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3
Q

What does the flow restrictor do on each MS outlet from the SG?

A
  • Provide plant protection, in case of MSLB, by decreasing steam flow rate to reduce RCS cooling rate.
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4
Q

What is P-14 permissive?

A
  • SG Hi HI Lvl at 67% on 1 SG (2/3)
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5
Q

What will P-14 permissive cause?

A
  • Turbine Trip
  • MFP Trip
  • FWI
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6
Q

What enables AMSAC?

A
  • > 40% Power (C-20, 2/2 Turbine first stage Impulse #)
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7
Q

What causes an AMSAC signal?

A
  • FW flow < 25% (3/4 Feed flow)
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8
Q

What will AMSAC actuate?

A
  • All 3 AFW Pumps

- Trips Main Turbine (30 Sec)

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9
Q

What does SG blowdown do for the SG?

A
  • Drain SG water from chemical and impurity sludge formation area to maintain SG chemistry & prevent sludge corrosive attack
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10
Q

When do DCR-310-340 (BD isolation valves) automatically isolate?

A
  • Phase A
  • High Rad: R-19 (Sampling)
  • High Rad: R-24 (Treatmnt)
  • High Level in Flash Tank
  • AFW Flow Conservation (MDAFP starts)
  • TDAFP Start
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11
Q

Where is the normal BD tank vented to?

A
  • Condenser A
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12
Q

Where do we drain both flash tanks to?

A
  • TRS Overflow via DRV-350
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13
Q

Can the high rad trip on the BD system valves isolating be overridden?

A
  • Yes, they can. Can be overridden in sample room
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14
Q

When do BD sample isolation valves (DCR-301-304) automatically close?

A
  • High Rad

- Phase A

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15
Q

What actuations does a high rad signal from R-19 cause? ***

A
  • Closes BD Isolation DCRs 310-340
  • Closes DRV-350 SGBD Flashtank to TRS
  • Closes BD Sampling DCRs 301-304
  • Override available
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16
Q

What actuations does a high rad signal from R-24 cause?

A
  • Trips SGBD Treatment Pump
  • Closes BD Isolation DCRs 310-340
  • Closes DRV-350 SGBD Flashtank to TRS
  • Closes BD Sampling DCRs 301-304
  • Override available
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17
Q

Control air header pressure is lowering at a fast rate. At 80 psi, the reactor is manually tripped, and header pressure continues to lower. What will happen to the air reg valves in the BD system if pressure continues to lower?

A
  • All air reg valves on BD system will isolate on loss of ctrl air
  • DRV-350/352
  • BD isolation valves
  • BD Flow Ctrl Valves
  • BD Sample Valves
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18
Q

What will cause a AFW Flow Conservation?

A
  • Both MFP Trips
  • AMSAC
  • Low-Low SG lvl
  • Load Shed
  • SI
19
Q

What is the cooling water to the BD Hx and flash tank quenching?

A
  • CHW
20
Q

What supplies cooling to the sample Hx?

A
  • CCW
21
Q

What are the BDFT level alarms?

A
  • High 75% alarms and closes BD isolation valves
  • Low 55% alarms and trips BD treatment pump
  • Low 53% alarms and closes DRV-350 (only in auto)
  • Extreme low 51.5% alarms
22
Q

What does SGWLC maintain?

A
  • SGWLC maintains SG Narrow Range level at 43.8% for all power levels.
23
Q

What plant protection functions do the SG # transmitters provide?

A
  • SG Steam Line Break Detection
  • SI Initiation
  • Main Steam Line Isolation
  • Low Steam # Alarms
24
Q

What is the dominant control for SG Level? ***

A
  • Level Dominant (43.8%)

- Steam Generator Level overrides Feed flow/Steam Flow mismatch over time, level is a lag signal*

25
Q

What causes a Steam Line Isolation (SLI)? ***

A
  • Cnt # High-High at 2.8# (2/4)
  • SG # low < 500# (1/1 on 2/4 SG)
  • High Stm flow with P-12 (1.42E6/1.6E6) (1/2) on 2 SG
26
Q

What is the definition of density compensation?

A
  • converts volumetric flow rate of steam to mass flow rate for input into SGWLC circuit. (Left 2 Channels ctrl SG lvl)
27
Q

Where do we measure SG Level?

A
  • SG Downcomer
28
Q

What is swell caused by? ***

A
  • an increase in steam flow (which will cause an increased indication of SG lvl in the downcomer due to decreased SG #) (More intense boiling)
29
Q

What is shrink caused by?

A
  • reduction in steam flow (which will cause an decreased indication of SG lvl in the downcomer due to a rise in SG#) (Less intense boiling)
30
Q

In MODES 1 and 2, the reactor is critical and thus has the potential to produce maximum THERMAL POWER. Thus, to ensure that the assumptions of the accident analyses remain valid, all RCS loops are required to be OPERABLE and in operation in these MODES to prevent ________ and _________.

A
  1. DNB

2. Core Damage

31
Q

What constitutes an OPERABLE RCS Loop?

A
  • An OPERABLE RCS loop consists of an OPERABLE RCP in operation providing forced flow for heat transport and an OPERABLE SG
32
Q

With the plant in MODE 3 and the CRDM’s energized, how many RCS loops are required to be operable?

A
  • When in MODE 3 with CRDM’s energized, 2 RCS loops shall be OPERABLE
33
Q

What is the maximum permissible RCS to SG leakage? (TS 3.4.13)

A
  • 150 gpd primary to secondary LEAKAGE through any one steam generator (SG)

Basis: Limit release to atmo outside ctmnt based on 10CFR100

34
Q

If the steam flow indication fails high to your flow controller, what will happen the FRV?

A
  • The FRV will go open because Feed Flow will want to match Steam Flow
35
Q

If the steam flow indication fails low to your flow controller, what will happen the FRV?

A
  • The FRV will go closed because Feed Flow will want to match Steam Flow
36
Q

If the feed flow indication fails low to your flow controller, what will happen the FRV?

A
  • The FRV will go open because Feed Flow will want to match Steam Flow
37
Q

If the feed flow indication fails high to your flow controller, what will happen the FRV?

A
  • The FRV will go closed because Feed Flow will want to match Steam Flow
38
Q

With the plant in MODE 3 and the CRDM’s are not energized, how many RCS loops are required to be operable?

A
  • When in Mode 3 with CRDMs not energized, 2 RCS loops shall be OPERABLE with one in operation
39
Q

What, with respect to RCS Loops, is required to be operable in Mode 4? (TS 3.4.6)

A
  • Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

Basis:
Accidental boron dilution event

40
Q

What does TS 3.4.7 (RCS Loops Mode 5) require?

A
  • One residual heat removal (RHR) loop shall be OPERABLE and in operation,
    AND
  • a. One additional RHR loop shall be OPERABLE;
    OR
    b. The secondary side water level of at least two steam generators (SGs) shall be above the lower tap of the SG wide range level instrumentation by ≥ 420 inches.

Basis:
Accidental boron dilution event

41
Q

What will happen if either the SG Lvl Ctrlr or SG Flow Ctrlr is lost?

A
  • The RU will instantly go to manual to maintain the FRV at its current position
42
Q

What will happen if SG RU Ctrlr is lost?

A
  • The SG Flow Ctrlr takes over
43
Q

Unit 1 was operating at 100% power when a loss of main feedwater occurs to a single SG due to the failure of the controlling feedwater flow instrument.

A valid indication on the affected SG “Flows / Level / Pressure” recorder for this failure would be a rapidly lowering SG level and a?

A
  • high feedwater flow indication on the feedwater flow pen.
44
Q

What will cause a FWI?

A
  • SG High-High level (P-14) (67% NR 2/3 on 1 SG)
  • SI
  • Rx trip (P-4) with low Tavg (Tavg < 554°F on 2/4 loops)

RO31 ILT (56 decks)

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