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Systems > Test 1 - Print Reading, Fuel Bundle Assembly, RPV Internals, Intro to Tech Spec, RPV Instrumentation, Primary Containment > Flashcards

Test 1 - Print Reading, Fuel Bundle Assembly, RPV Internals, Intro to Tech Spec, RPV Instrumentation, Primary Containment Flashcards

1
Q

What is barrier fuel?

A

A layer of iron enhanced Zirc on the inner clad. Minimizes damage from PCI

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2
Q

What do water rods(water channel) do?

A

Limits magnitude of Void Coefficient. Enhance moderation in center of bundle. Non-boiling area

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3
Q

Describe Gd

A

Gadolinium is a burnable poison that allows higher excess Keff.

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4
Q

Describe a fuel pellet

A

Sintered UO2 with 4 – 4.5% enrichment; chamfered edges

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5
Q

How can you verify the position of a fuel bundle?

A
  1. Serial # - readable from center 2. Channel fastener – on central corners secures channel to assembly 3. ID Boss – points towards center 4. Spacer buttons – adjacent to control rods maintain wide-wide gap 5. Cell to cell symmetry. Heights even across all bundles
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6
Q

How is 2/3 core height protection achieved?

A

2/3 core height protected by shroud and jet pumps; jet pump riser does not protect 2/3 core height

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7
Q

What do finger springs do?

A

Controls/minimizes amount of bypass flow (primary purpose) Bypass flow (10% core flow)—cools under vessel instrumentation, neutron monitoring, control rod blade mechanisms in bypass region between fuel channels Maintain bypass flow relatively constant as fuel channel creep (bowing) occurs.

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8
Q

How is adequate flow maintained through all bundles?

A

Flow/Core orifices located in the fuel support pieces and minimize flow variation caused by changes to two phase flow resistance

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9
Q

List, in order, from RPV top to bottom penetrations (from instrument zero):

A

i. MSL tap (273”) ii. Steam Separator turnaround point (200-220”) iii. Recirc Discharge/Jet Pump Suction (-188.44”) iv. Recirc Suction (-205.5”)

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10
Q

What is the primary function of the shroud?

A

provide for a floodable region

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11
Q

What does the Fission Gas Plenum Area do?

A

Captures fission product gases not contained within ceramic fuel pellet and allows for thermal expansion. Non Areva fuel has Zr Hydrogen Getter.

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12
Q

What does the Lower Tie-Plate do?

A

• Has vortex eliminator to limit moderator turbulence. • Has 2 bypass holes to allow core bypass flow. • Directs coolant flow through assembly.

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13
Q

Which component supports the weight of the fuel during fuel moves?

A

Upper tie plate. Supports weight during fuel moves. Load chain transmits weight to upper tie plate during fuel handling ONLY when assembly hanging by bail handle.

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14
Q

What are 4 types of fuel damage?

A

• Debris induced fretting (DIF) caused by FME • Crud induced localized corrosion (CILC)—crud burst (SCRAM) settles out in low flow area which weakens cladding • Pellet-Clad interaction (PCI) “dog boning” • Manufacturing defects

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15
Q

Coolant activity spikes during power transients, Step increases in coolant noble gas activity (Kr, Xe), Increasing SJAE readings, and Increases in Xe138/Xe133 ratio are indications of what?

A

Fuel damage

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16
Q

What components support the weight of the fuel bundle?

A

Fuel bundle, Fuel Support Piece, CRD Guide Tube, CRD Housing, Stub tube, J-weld to RPV bottom head, Vessel skirt

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17
Q

What does the lower core plate support?

A

Peripheral fuel bundles

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18
Q

What is the RPV inventory/inch? What is the total mass of the fluid in the core during cold shutdown?

A

150 gal/inch 620,000 lbm

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19
Q

How does steam quality change through the RPV?

A

10-13% exiting core 95% exiting steam separators 99.75% exiting steam dryers

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20
Q

Explain the 3 flowpaths of natural circ

A

• Primary Loop: Up through core, down to downcomer, through jet pumps, under core plate,  back to core • Secondary Loop: Flow through bypass region • Third Loop: down through cold peripheral bundle, below core plate, up through hot bundle

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21
Q

What RPV level is required for natural circulation?

A

200-220” Steam separator turnaround

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22
Q

Explain the difference between carryover and carryunder

A

Carryover: Moisture entrained in steam caused by high vessel level; affects turbine/radiation levels Carryunder: Steam entrained in downcomer liquid caused by low vessel level; affects NPSH for jet pumps and recirc pumps

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23
Q

What is 100% core flow?

A

• 77 Mlbm/hr total core flow

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24
Q

What is the limit for unidentified drywell leakage and where does it collect?

A

≤ 5 gpm unidentified averaged in 24 hours. Collected in the DWFDs. 8 hour limit.

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25
Q

RCS Tech Spec leakage limits?

A

a. No pressure boundary LEAKAGE; b. ≤ 5 gpm unidentified LEAKAGE averaged over the previous 24 hour period; c. ≤ 25 gpm total LEAKAGE averaged over the previous 24 hour period; and d. ≤ 2 gpm increase in unidentified LEAKAGE within the previous 24 hour period in MODE 1.

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26
Q

How much pressure boundary leakage is allowed?

A

None. M3 in 12, M4 in 36.

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27
Q

What is typical value for bypass flow at 100%?

A

• 7.7 Mlbm/hr bypass flow

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28
Q

What is typical value for driving flow at 100% power?

A

• 36 Mlbm/hr recirc. Flow (Driving Flow)

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29
Q

What is typical value for steam flow at 100% power?

A

• 12.8 Mlbm/hr steam flow

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30
Q

What is typical value for feedwater flow at 100% power?

A

12.75 Mlbm/hr

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31
Q

What are SLMCPR limits for Unit 1?

A

1.08 TLO 1.11 SLO

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32
Q

What are SLMCPR limits for Unit 2?

A

1.07 TLO 1.09 SLO

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33
Q

What is power limited to when pressure < 785psig OR core flow <10%?

A

≤23% RTP

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34
Q

What is Rated thermal Power

A

2923MWt

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35
Q

What actions are required by Tech Specs if a safety limit is violated?

A

Restore limit AND insert all insertable control rods within 2 hours

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36
Q

What actions are required by 10CFR50.36 if a safety limit is violated?

A

Notify NRC Prepare Report to NRC Operation may not be resumed until authorized by NRC

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37
Q

What is SL RPV pressure?

A

1325 psig steam dome pressure (1375 psig bottom head pressure)

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38
Q

What is SL RPV level?

A

Reactor vessel water level shall be greater than the top of active irradiated fuel.

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39
Q

Where is TAF (from instrument zero)? Where is BAF (from instrument zero)?

A

-8.44” -158”

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40
Q

Increased carryunder can result in less what?

A

NPSH for recirc pumps

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41
Q

What is a hazard of operating with an inoperable/broken jet pump?

A

potential loss of core reflood capability in event of a LOCA (jeopardize 2/3 core height) and increase blowdown area

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42
Q

How many fuel assemblies are there in each Brunswick core? How many Control Rods?

A

560 137

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43
Q

How many fuel assemblies are supported by the lower core plate?

A

12 (peripheral assemblies only)

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44
Q

What contributes to Pellet-clad interaction induced fuel failures?

A

-rapid power increases -increased fuel exposure increasing concentrations of Iodine and Cadmium

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45
Q

Define ACTIONS per Tech Specs

A

ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

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46
Q

Define AVERAGE PLANAR LINEAR HEAT GENERATION RATE (APLHGR) per Tech Specs

A

The APLHGR shall be applicable to a specific planar height and is equal to the sum of the heat generation rate per unit length of fuel rod for all the fuel rods in the specified bundle at the specified height divided by the number of fuel rods in the fuel bundle at the height.

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47
Q

Define CHANNEL CALIBRATION per Tech Specs

A

A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, display, and trip functions, and shall include the CHANNEL FUNCTIONAL TEST. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is calibrated.

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48
Q

Define CHANNEL CHECK per Tech Specs

A

A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

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49
Q

Define CHANNEL FUNCTIONAL TEST per Tech Specs

A

A CHANNEL FUNCTIONAL TEST shall be the injection of a simulated or actual signal into the channel as close to the sensor as practicable to verify OPERABILITY, including required alarm, interlock, display, trip functions, and channel failure trips. The CHANNEL FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total channel steps so that the entire channel is tested.

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50
Q

Define CORE ALTERATION per Tech Specs

A

CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. The following exceptions are not considered to be CORE ALTERATIONS: a. Movement of source range monitors, local power range monitors, intermediate range monitors, traversing incore probes, or special movable detectors (including undervessel replacement); and b. Control rod movement, provided there are no fuel assemblies in the associated core cell. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

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51
Q

Define CORE OPERATING LIMITS REPORT (COLR) per Tech Specs

A

The COLR is the unit specific document that provides cycle specific parameter limits for the current reload cycle. These cycle specific limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

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52
Q

Define DOSE EQUIVALENT I-131 per Tech Specs

A

DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcuries/gram) that alone would produce the same dose as the quantity and isotopic mixture of I-131, I-132, I-133, I-134, and I-135 actually present. The dose conversion factors used for this calculation shall be those listed in Federal Guidance Report (FGR) 11, “Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion,” 1989 and FGR 12, “External Exposure to Radionuclides in Air, Water, and Soil,” 1993.

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53
Q

Define EMERGENCY CORE COOLING SYSTEMS (ECCS) RESPONSE TIME per Tech Specs

A

The ECCS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its ECCS initiation setpoint at the channel sensor until the ECCS equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

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54
Q

Define ISOLATION INSTRUMENTATION RESPONSE TIME per Tech Specs

A

The ISOLATION INSTRUMENTATION RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its isolation initiation setpoint at the channel sensor until the isolation valves receive the isolation signal (e.g., de-energization of the MSIV solenoids). The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

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55
Q

Define LEAKAGE per Tech Specs

A

LEAKAGE shall be: a. Identified LEAKAGE 1. LEAKAGE into the drywell, such as that from pump seals or valve packing, that is captured and conducted to a sump or collecting tank; or 2. LEAKAGE into the drywell atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; b. Unidentified LEAKAGE All LEAKAGE into the drywell that is not identified LEAKAGE; c. Total LEAKAGE Sum of the identified and unidentified LEAKAGE; and d. Pressure Boundary LEAKAGE LEAKAGE through a nonisolable fault in a Reactor Coolant System (RCS) component body, pipe wall, or vessel wall.

56
Q

Define LINEAR HEAT GENERATION RATE (LHGR) per Tech Specs

A

The LHGR shall be the heat generation rate per unit length of fuel rod. It is the integral of the heat flux over the heat transfer area associated with the unit length.

57
Q

Define LOGIC SYSTEM FUNCTIONAL TEST per Tech Specs

A

A LOGIC SYSTEM FUNCTIONAL TEST shall be a test of all required logic components (i.e., all required relays and contacts, trip units, solid state logic elements, etc.) of a logic circuit, from as close to the sensor as practicable up to, but not including, the actuated device, to verify OPERABILITY. The LOGIC SYSTEM FUNCTIONAL TEST may be performed by means of any series of sequential, overlapping, or total system steps so that the entire logic system is tested.

58
Q

Define MINIMUM CRITICAL POWER RATIO (MCPR) per Tech Specs

A

The MCPR shall be the smallest critical power ratio (CPR) that exists in the core. The CPR is that power in the assembly that is calculated by application of the appropriate correlation(s) to cause some point in the assembly to experience boiling transition, divided by the actual assembly operating power.

59
Q

Define MODE per Tech Specs

A

A MODE shall correspond to any one inclusive combination of mode switch position, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

60
Q

Define OPERABLE-OPERABILITY per Tech Specs

A

A system, subsystem, division, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, division, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

61
Q

Define REACTOR PROTECTION SYSTEM (RPS) RESPONSE TIME per Tech Specs

A

The RPS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RPS trip setpoint at the channel sensor until de-energization of the scram pilot valve solenoids. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

62
Q

Define SHUT DOWN MARGIN (SDM) per Tech Specs

A

SDM shall be the amount of reactivity by which the reactor is subcritical or would be subcritical assuming that: a. The reactor is xenon free; b. The moderator temperature is 68°F; and c. All control rods are fully inserted except for the single control rod of highest reactivity worth, which is assumed to be fully withdrawn. With control rods not capable of being fully inserted, the reactivity worth of these control rods must be accounted for in the determination of SDM.

63
Q

Define STAGGERED TEST BASIS per Tech Specs

A

A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

64
Q

Define THERMAL POWER per Tech Specs

A

THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

65
Q

Define TURBINE BYPASS SYSTEM RESPONSE TIME per Tech Specs

A

The TURBINE BYPASS SYSTEM RESPONSE TIME consists of two components: a. The time from initial movement of the main turbine stop valve or control valve until 80% of the turbine bypass capacity is established; and b. The time from initial movement of the main turbine stop valve or control valve until initial movement of the turbine bypass valve. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured.

66
Q

What automatic level actions come from narrow range level instruments?

A

High level trips and LL1

67
Q

What #’s are the Narrow Range Detectors and what range do they measure?

A

N004, N017, N042 They measure from 150”-210”

68
Q

What #’s are the Wide Range Detectors and what range do they measure?

A

N024, N025, N026, N031 They measure from 0”-210”

69
Q

What #s are the Shutdown Range Detectors and what range do they measure?

A

N027A and N027B They measure from 150”-550”

70
Q

What #’s are the Fuel Zone Detectors and what range do they measure?

A

N036 and N037(with a R615 Recorder) They measure from -150” to +150”

71
Q

What conditions are the Narrow Range Instruments calibrated in and are the reference legs compensated?

A

Calibration: NORMAL CONDITIONS • 1030 psig reactor pressure • Drywell temperature 158°F • Reactor building temperature 70°F All instruments are Uncompensated Reference legs inside the drywell.

72
Q

What conditions are the Wide Range Instruments calibrated in and are the reference legs compensated?

A

Calibration: HOT, but NORMAL • 1000 psig reactor pressure • Reference leg drywell temperature 200°F • Variable leg drywell temperature 135°F • Reactor Building temperature 90°F Compensated reference legs, except for instruments used on RTGB (N026)

73
Q

What conditions are the Shutdown Range Instruments calibrated in and what happens to the instruments during refueling?

A

Calibration: NORMAL SHUTDOWN CONDITIONS • Reactor pressure 0 psig • Drywell temperature 70°F • Rx Bldg temperature 70°F • For alternate, Drywell/RPV temp 85°F Alternate transmitters (7468) provided for instrument input for refueling operations per GP-06 (head removal). These are pressure instruments, not D/P. Reference leg piping is removed during vessel head disassembly

74
Q

What conditions are the Fuel Zone Instruments calibrated in and are the reference legs compensated?

A

Calibration: CASUALTY CONDITIONS. • Reactor pressure 0 psig • Drywell temperature 350°F • Reactor Building temperature 140°F • NO JET PUMP FLOW Density compensated reference legs • Indication uses output from master units on ECCS analog trip cabinets • These indications are not accurate if RR pumps are running

75
Q

What wide range instruments are least affected by LOCA and why?

A

N026A&B - most of the reference leg is in the reactor building

76
Q

What wide range instruments are most affected by HELB in the reactor building?

A

N026A&B most of the reference leg is in the reactor building

77
Q

What are the Power supplies for the Narrow Range Instruments and Recorders?

A

Power: Instrument loops from DFWCS UPS Panel V9(10)A Div. II DC Panel 3(4)B Recorder power UPS Panel V7(8)A Fail As Is (FAI)

78
Q

What are the Power supplies for the Wide Range Instruments and Recorders?

A

Power: 26A/B instrument loops from 120 VAC Emergency power 26A Panel 31(32)A (E5/E7) 26B Panel 1(2)B (E6/E8) Recorder power UPS Panel V7(8)A Fail As Is (FAI) Remote Shutdown panel uses N026B transmitter and transfers instrument loop power to Div II DC MCC 1(2)XDB

79
Q

What RPV level indications are available in the control room with a loss of all AC power?

A

N004A/B/C (narrow) N036 (fuel)

80
Q

What are the 4 Rx Safety Limits and when do they apply?

A
  1. With the Rx steam dome pressure < 785 psig OR core flow < 10%, Thermal Power shall be < or = 23% RTP. 2. With the Rx steam dome pressure > or = 785 psig AND core flow > or = 10%, MCPR shall be: Unit 1: 1.08 for two loop ops 1.11 for single loop ops Unit 2: 1.07 for two loop ops 1.09 for single loop ops 3. Rx water level shall be greater than top of active fuel. 4. Rx steam dome pressure shall be < or = 1325 psig.
81
Q

What actions must be taken if Rx Pressure goes over 1045#?

A

Restore w/in 15 minutes or in M3 in 12 hrs

82
Q

What actions must be taken if Rx steam dome Pressure goes over 1325#?

A

Rods in w/in 2 hrs

83
Q

How can you tell a RPV Flange Seal leak has occurred and what causes the alarm?

A

A-02, window 5-6 will annunciate. This is caused by a failure of the inner seal and is detected by a pressure switch at 600#.

84
Q

What is the purpose of RPV internals?

A

Properly distribute flow to the vessel Locate and support fuel assemblies Provide a volume to be flooded following a LOCA Facilitate Refueling Function as a radioactive material barrier

85
Q

What is the design basis for RPV internals?

A

Withstand loading and forces from operations and accidents NDT shifts are accounted for Floodable volume post LOCA Limit Deformation to ensure CRs and cooling systems can perform their functions Design shall ensure safety bases are satisfied

86
Q

What is the purpose of the Fuel Support Piece (elephants foot) and its orifice?

A

It ensures a more even flow distribution under high flow conditions. “Adequate flow NOT equal flow to all fuel bundles”

87
Q

What is Mode 1 used for and what are the requirements to be in it?

A

Mode 1 - Used for Power Operations Mode Switch - RUN Avg Coolant Temp - N/A Vessel Head Bolts - Tensioned

88
Q

What is Mode 2 used for and what are the requirements to be in it?

A

Mode 2 - Used for Start Up Mode Switch - Refuel OR S/U Hot Stby Avg Coolant Temp - N/A Vessel Head Bolts - Tensioned

89
Q

What is Mode 3 used for and what are the requirements to be in it?

A

Mode 3 - Used for Hot S/D Mode Switch - S/D Avg Coolant Temp - >212 Vessel Head Bolts - Tensioned

90
Q

What is Mode 4 used for and what are the requirements to be in it?

A

Mode 4 - Used for Cold S/D Mode Switch - S/D Avg Coolant Temp - < or = 212 Vessel Head Bolts - Tensioned

91
Q

What is Mode 5 used for and what are the requirements to be in it?

A

Mode 5 - Used for Refueling Mode Switch - S/D or Refuel Avg Coolant Temp - NA Vessel Head Bolts - De-Tensioned

92
Q

What does suppression pool level initially do during a DBA LOCA and why?

A

Level initially rises due to the increased pressure pushing water out of the downcomer piping. Level falls once ECCS systems start taking suction from the torus.

93
Q

What is the T.S. temperature limit for the Drywell in mode 1, 2, &3?

A

<=150dF

94
Q

What is the T.S. limit for the suppression pool temperature when no testing adding heat is being performed?

A

<=95dF

95
Q

What is the T.S. limit for the suppression pool temperature when testing adding heat is being performed?

A

<=105dF

96
Q

Above what suppression pool temperature do Tech Specs require an immediate scram?

A

110dF

97
Q

Above what suppression pool temperature do Tech Specs require RPV pressure to be below 200psig in 12 hours?

A

120dF

98
Q

What is required for Primary Containment Operability?

A

PEALS Penetrations Operable or Closed Equipment Hatch Closed Airlock operable Leakage rates in spec Sealing mechanisms operable

99
Q

What level is the suppression pool maintained at?

A

> - 31 inches and <= -27 inches

100
Q

What is the requirement for Primary containment atmosphere?

A

Oxygen less than 4% volume in Mode 1 >15% RTP

101
Q

What is the Function of the N004’s?

A

• P603 Indication • Hi / Low level alarm • Input to DFCS for RPV level control • Level signal for recirculation limiter #2 • Main turbine & RFP high level trip

102
Q

Which results in a higher drywell pressure? DBA LOCA or a steam line break?

A

DBA LOCA

103
Q

Which results in a higher drywell pressure? DBA LOCA or a steam line break?

A

DBA LOCA

104
Q

What is the design pressure limit for the Drywell (NOT PCPL-A)

A

62psig

105
Q

What is the design temperature limit for the Drywell?

A

300dF (340dF environmental)

106
Q

What is the design internal pressure for the suppression pool?

A

62psig

107
Q

What is the design internal pressure for the suppression pool?

A

62psig

108
Q

The reactor building to suppression pool vacuum breakers open based on differential pressure between what?

A

Reactor building and Drywell

109
Q

At what differential pressure do the suppression pool to drywell vacuum breakers open?

A

0.5psid between suppression pool and drywell

110
Q

At what differential pressure do the reactor building to suppression pool vacuum breakers open?

A

0.5psid between reactor building and drywell

111
Q

How many suppression pool to drywell vacuum breakers are required to be operable to open?

A

8 of 10

112
Q

How many suppression pool to drywell vacuum breakers are required to be closed?

A

10 unless performing functional test

113
Q

How does a group 2 isolation affect drywell floor and equipment drains?

A

close F019 and F020 and F003 and F004 and stops running pumps

114
Q

What is the caveat about the Tigraph Recorder for the Wide Range instruments?

A

The recorder only takes input from N026B. Fails as is, LED will go blank If Div 2 is lost, if the input to the recorder is lost and it fails downscale.

115
Q

What are uncompensated instruments used for? What are some advantages and disadvantages of uncompensated instruments?

A

They are used for all RTGB level indications Advantages: Ref legs are at drywell temperature (135dF) therefore: Less likely to flash on a rapid depressurization; they will flash if your in the Unsafe region of RPV saturation limit after reference legs heat up Disadvantages: More susceptible to drywell temp changes Non condensable gases come out of reference leg causing notching; use the backfill system to prevent. If notching occurs use the lowest indication.

116
Q

What are the most accurate temperature detectors?

A

RTDs - you must have power, linear output signal over a wide range.

117
Q

What to we use to measure RPV temperatures and why?

A

Thermocouples - they have no external power supply.

118
Q

What will trip drywell coolers?

A

LOCA signal loss of power or control power

119
Q

How is Recirc loop flow measured

A

By flow venturis Four transmitters per loop feed flow units A Transmitters feed Recorders B Transmitters feed Indications APRMs use output

120
Q

How does a group 2 isolation affect drywell floor and equipment drains?

A

close F018 and F019 and stops running pumps

121
Q

What are the Power supply for the Shutdown Range instruments?

A

N027 A 120VAC Panel 1AB(2AB) ( Div 1 norm) N027 B 120VAC Panel 1B(2B) (Div 2) 7468 A 120VAC Panel 1AB(2AB) ( Div 1 norm) 7468 B 120VAC Panel 1B(2B) ( Div 2) 3331 120VAC Panel 1(2)B-DG (Div 2)

122
Q

Which shutdown range transmitter uses the black scale? Which one uses the red scale? How do you determine which one is used?

A

The N027 uses the Black scale The 7468 uses the Red scale There are keylock switches in the Rx Bldg to determine which transmitter is used.

123
Q

How many transfer pumps start on a drywell floor or equipment drain hi level alarm?

A

1 lead pump starts when in auto; no pumps start if in lockout

124
Q

How many transfer pumps start on a drywell floor or equipment drain hi hi level alarm?

A

1 standby pump regardless of switch in auto or lock out

125
Q

A loss of PNS will cause which drywell coolers to start?

A

All Unit 2 and 1B (dampers fail open)

126
Q

What will cause all drywell coolers to start (in normal line ups)

A

scram (scram air header pressure 60 psig)

127
Q

What will trip drywell coolers?

A

LOCA signal loss of power or control power

128
Q

What does the lockout switch prevent on the RTGB and when will it not work?

A

Lockout prevents DW coolers from starting after a scram. It will NOT prevent Unit 2 and 1B DW coolers from starting on a loss of pneumatics

129
Q

Which DW coolers are Div 1 and which are Div 2?

A

Div 1: A&D Div 2: B&C

130
Q

How do DW cooler dampers fail on loss of pneumatics?

A

Fail open

131
Q

How do reactor building to torus vacuum breaker butterfly valves fail on loss of pneumatics?

A

Fail closed

132
Q

What are the Power Supplies for Fuel Zone indications?

A

N036 ECCS XU-63 (3/4A) B/U 11/12A DC N037 ECCS XU-64 (3/4B) R615 recorder 120VAC Panel 1B(2B) Div 2 AC.

133
Q

What interlock do the Fuel Zone Range indicators provide.

A

2/3rd core height interlock for RHR (spray) logic Only RTGB indications from ECCS panels

134
Q

Describe the operation of RIP valves.

A

Red and Green lights give valve position Dual lights, top is solenoid status. Bottom is valve position. To re-open after isolation, pushbutton must be depressed twice.

135
Q

Describe the operation of Excess Flow Check Valves.

A

They protect against line failure / leakage. Solenoid bypass to reset Red or Green light on RTGB for position indication of bypass solenoid Yellow light on pushbutton indicates bypass solenoid energized.

136
Q

The reactor vessel level indications on the P603 and P601 actually measure level where?

A

water level in the downcomer region except for N036 and N037 fuel zone instruments which measure water level within the shroud

137
Q

Which reference legs have backfill and why?

A

uncompensated reference legs to prevent non condensibles from coming out of reference leg and causing notching

Systems (6 decks)

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