table 7.5-1 main control room indicators and/or … · ndtt considerations. monitor containment...

TABLE 7.5-1

MAIN CONTROL ROOM INDICATORS AND/OR RECORDERS AVAILABLE TO THE OPERATOR

Channel Parameter Available

OPERATIONAL OCCURRENCES 1. Tcold or Thot lThot

(measured, wide range lTcold/

2.

3.

4.

5.

Pressurizer water level

system pressure

Containment pressure

Steam line pressure

SGS-UFSAR

Loop

3

2

4

3/loop

Entire distance between taps (528"approx)

0-3000 psig

0-115% of design pressure (-5 to +55 psigl

0-1200 psig

Accuracy

+4% of full range

+4.2% of span level at 2250 psi a

_!5.5% of full range

+5.5% of full scale

.5% of full scale

1 of 4

Indicator/ Recorder

All channels are recorded

All three channels indicated; one channel is selected for recording

Indicated and recorded

All four are indicated; two are also recorded

All channels are indicated

Purpose

Ensure maintenance of proper cooldown rate and to ensure maintenance of proper relation-temperature NDTT considerations.

Ensure maintenance of proper reactor coolant inventory.

Ensure maintenance of proper relationship between system pressure and temperature for NDTT considerations.

Monitor containment conditions to indicate need for potential safeguards actuation.

Monitor steam generator temperature conditions during hot shutdown and cooldown, and for use in recovery from steam generator tube ruptures.

Revision 18 April 26, 2000

Parameter Channel Available

OPERATIONAL OCCURRENCES (Cont.)

6. Steam generator water level (wide range)

7. Stearn generator water level (narrow range)

ACCIDENT CONDITIONS

1. Containment pressure

2. Refueling water storage tank water level

SGS-UfSAR

1/stearn generator

3/steam generator

2

2

0-100%

0-100%

0-115% of design presBUre 1-5 to +55 psi g)

(-15 to +165 psigl

0-100% of ! 48 ft/H Ol

2

TABLE 7.5-1 [Cont'd)

Accuracy

Refer to Applicable Loop Accuracy Calculation


5% of full

+3% of level span

2 of 4

Indicator/ Recorder

All channels recorded

All channels indicated; the channels used for control are recorded

All four are indicated; two are also recorded

Both

Both are indicated and alarmed

Ensure maintenance of reactor heat sink.

tnsure maintenance of reactor heat sink.

Monitor post-LOCA containment conditions.

tnsure that water is flowing to the safety injection system after a LOCA and determine when to shift from injection to recirculation mode.

1. Ste~m gPnerJtor l•nter level {narrow rang<>l

4. Steam rator water 1 (wide range!

5. Steam l1ne pressure

6. Pressurizer water level

7. Conta1nment hydrogen level

B. Conta1nment area monitors (hlgh range)

SGS-UFSA.R

·r !J:;!f' l.s l l l ·1l> 1 p

<i:;t_e.1m 0-100? or>r.Pr~t or

1/st:eam aPr1erator

3/steam I ine

3

2

2

0-100'1.

0-1200 psig

Entire distance between taps ( 528'' Appwx)

0-IO% vol

1 107?/hr

( r:c·nt )

Refer to Applicable Lorlp 1\r:curacy Cal lation

Refer to Applicable Accucac:y at ion

+7.51. of full scale

Indicate the level is some-where between 0 and 100 of span

2% of full scale

3 of 4

Ir1dicator I

All channels indicated; the channels used for control are recorded

All channels are recorded

All channels are indicated

All three indicated and one is for recording

Both channels are recorded


Purpose

Detect steam generator tube rupture; monitor steam generator water level following a steam line break.

Detect steam generator tube rupture; monitor steam generator water level following a steam line break.

Monitor steam line pressures following steam generator tube rupture or steam line break.

Indicate that coolant inventory restored in pressurizer following cooldown after steam generator tube rupture or steam line break.

NUREG 0737

NUREG 0737

Revision 18 Apri 1 2 6, 2000

I

Channels Parameter

ACCIDENT CONDITIONS (Cent)

9. Reactor vessel level 2

10. Containment liquid level

11. Neutron flux

12. Core Exit

4

2

2

2 (29 TC's

Hot leg-

top of RV

Bottom -top of RV

ro-a amps -120% wide range log power

32"F Thermocouples (11 each channel) 2300"F

13. Margin to 2 ± 999"F Saturation 0-250"F

0-25"F

TABLE 7.5-1 {Cont)

Accuracy

6% without RCPs

running

±10.5% of full span

(2) (3)

(4)

Indicator/ Recorder

One channel

recorded

One set recorded


Both are indicated and alarmed

Both channels are indicated

Both Channels recorded and indicated

Purpose

Detect cooling.

inadequate

Indication of neutron flux

during and following an accident

NUREG 0737

Detect inadequate core cooling

core

(1) The CET subsystem which is part of the In-Core Instrumentation System, has been upgraded to EQ to ensure availability post accident. However, since the balance of the In-Core Instrumentation is non-safety related, the FSAR text on the CET subsystem remains under Section 7.7 of the FSAR.

(2) Accuracy of the representative core exit T/C temperature (instrument and rack error) ±6°F/random + 3°F (bias) . (3) Process measurement accuracy:

Core Condition Error Covered core ~o -ll°F bias Core uncovered and CET at 700"F -85°F bias Core uncovered and CET at 1200°F -140~F bias

(4) The indicated margin to saturation is automatically adjusted by the subcooling margin monitor computer for errors that could cause indication to be higher than actual. This provides the operator with reasonable confidence that the RCS fluid will be subcooled at the core exit whenever a positive margin to saturation is indicated on the display units.

4 of 4 SGS-UFSAR Revision 23

October 17, 2007

I

Parameter

NUCLEAR INSTRUMENTATION

1. Source Range a. Count rate

b. Startup rate

SGS-UFSAR

TABLE 7.5-2

MAIN CONTROL ROOM INDICATORS AND/OR RECORDERS AVAILABLE TO THE OPERATOR TO MONITOR SIGNIFICANT PLANT PARAMETERS DURING NORMAL OPERATION

No. of Channels Available

2

2

1 to 10 6 counts/ sec

-1.0 to 5.0 decades/min

Accuracy

±7% of the linear full scale analog voltage

±7% of the linear full scale analog voltage

1 of 11

Indicator/ Recorder

Both channels indicated. Either may be selected for recording.

Both channels indicated.

Notes

One two-pen recorder is used to record any of the 8 nuclear channels (2 source range, 2 intermediate range and 4 power range).

Revision 6 February 15, 1987

Parameter

NUCLEAR INSTRUMENTATION

2. Intermediate Range a. Flux level


2

b. Startup rate 2

3 . Power Range a. Uncalibrated

ion chamber current (top and bottom uncompensated ion chambers)

SGS-UFSAR

decades/min

4

TABLE 7.5-2 (Cont)

-1.0 to 5.0 full scale analog

0 to 120% of full power current

Accuracy

±7% of the linear full scale analog voltage and ±3% of the linear full scale voltage in the range of 10-4 to 10-3

amps

±7% of the linear indicated.

±1% of full power

2 of 11

Indicator/ Recorder

Both channels indicated. Either may be selected for recording using the recorder in Item 1 above.

Both channels

All 8 current signals indicated

Notes


NUCLEAR

b. Calibrated ion chamber current (top and bottom uncompensated ion chambers)

c. Not used

d. flux of the top and bottom ion chambers

SGS-UFSAR

No. of Channels

4

4

TABLE 7.5-2 (Cont.)

0-120% of full power

0 to 120% of full power

±2% of full power

±3% of full power for indication ±2% for recording

3 of 11

Indicator/

All 8 current recorded (four recorders) Recorder 1 - upper

and lower currents for Channel 1

Recorder 2 - upper And lower currents for Channel 2

Recorder 3 - upper and lower currents for Channel 1

Recorder 4 upper and lower currents for Channel 1

All 4 channels indicated. 2 of the 4

channels may be recorded using recorder in Item 1 above.

Revision 25 October 26, 2010

No. of Channels

Parameter Available

NUClEAR INSTRUMENTATION (Cont.)

e. Average ftux of 4 the top and bottom ion chambers

f. Flux 4 difference of the top and bottom ion chambers

REACTOR COOLANT SYSTEM

1. Taverage 1/loop (measured)

2. AT( measured) 1/loop

a. Tcold or 1·Thot and Thot 1·Tcold per (measured, loop wide range)

SGS·UFSAR

TABlE 7.5·2 (Cont.)

Range Accuracy

0 to 2001 of t2X of full full power power to 120

:t6X of full power to 200%

·30 to +30X :1:4%

540 • 615°F :1.:4°F

0 to 150% of :1:4% of fulL full power 4T power AT

0 • 700°F t4%

4 of 11

Indicator/ Recorder

All 4 channels recorded.

All 4 channels indicated.

All channels indicated.

All channels indicated. One channel is selected for recording.

Both channels recorded.

Notes

Revision 15 June 12, 1996

REACTU'" CC'OLAtlT SYSTEI·l ICont . l

3. OverpowPr .\T Set point

4. Overtemperature T Setpoint

5. Pressurizer Pressure

6. Pressurizer Level

7. Primary Coolant Flow

8. System Pressure

SGS-OFSAR

ll '· . 1 (h.:;nriP 1 S {I'Jc<l l dbl, - - - -

1: l " f'

3/l 00p

2

0-?',"F

1700 to ~500 psig

Ent1re distance between taps o-1oo•

0 to 120~ of rated fl0w

0 )f100 psig

±41 of full power :\T

±4' of full power .\T

±'il.O psi

±4.2% span level at 2250 psia

Repeatability of iH of full flow

±5.5%

5 of 11

Indicator/ ~~£Or de~

All channels One channel

indicated. is selected

for recording.


All channels indicated One channel is selected for recording.


All channels indicated.

All channels indicated and recorded.

Two-pen recorder used, second pen records reference level signal

Revision 18 April 26, 2000

I l

Parameter

REACTOR CONTROL SYSTEM


1. Demanded rod speed 1

2. Auctioneered T

3.

average

T reference

4. Control rod Position

SGS-UFSAR

1

1

0 to 100% of rated speed

540° to 615°F

TABLE 7.5-2 (Cont)

Accuracy

±2%

6 of 11

Indicator/ Recorder

The one channel is indicated.

The one channel is recorded.

The one channel is recorded.

Notes

Any one of the T channels avg into the auctioneer may be bypassed.

If system not available, borate and sample accordingly.


No. of Channels

Parameter Available

REACTOR CONTROL SYSTEM

a. Number of 1/group steps of demanded rod withdrawal

b. Demanded 1 position of the part length rod bank.

SGS-UFSAR

TABLE 7.5-2 (Cont)

Indicator/ Range Accuracy Recorder

0 to 230 steps ::!: 1 step Each group is indicated during rod motion.

0 to 230 steps ::!: 1 step The bank is indicated during rod motion.

7 of 11

Notes

These signals are used in conjunction with the measured position signals (4c) to detect deviation of any individual rod from the demanded position. A deviation will actuate an alarm and annunciator.


Parameter

REACTOR CONTROL SYSTEM (Cont.!

5.

c. Full length rod measured position

Control rod bank demanded position

SGS-UFSAR


1 for each rod

4

0 to 230 steps

0 to 230 step!!

TABLE 7.5-2 (Cont.)

Accuracy

Unit 1, +12 steps (100\::_RT~~O\)

Unit 2, +12 steps 1RTP>B5\l +18 step!! 1RTP::_85%!

:1:2.5\ of total travel

a of 11

Indicator/ Recorder

Each rod position is indicated.

All 4 control rod bank positions are recorded along with the low-low limit alarm for each bank.

Rod position indicators are required to be calibrated within !12 steps.

1. One channel for each control bank.

2 • An alarm and annunciator is actuated when the last rod control bank to be withdrawn reaches the withdrawal limit, when any rod control bank reaches the low insertion limit, and when any rod control bank reaches the low-law insertion limit.

Revision 16 January 31, 1998

Parameter

CONTAINMENT SYSTEM

Containment pressure

FEEDWATER AND STEAM SYSTEMS

1.

2.

3.

Auxiliary feedwater flow

Steam generator level (narro;.! range)

Steam generator level (wide range)

SGS-UFSAR


1/stearn line

3/steam generator

1/steam generator

0 - 115 of design pressure (-5 to +55 psigl

0-250000 PPH

0-100%

0-100%

TABLE 1.5-2 (Cant.)

Accuracy

+5. 5% of full span



9 of 11

lndicatm:/ Recorder

All 4 channels indicated and 2 are also recorded.

All channels indicated

All channels indicated. The channels used for control are recorded.

All channels recorded.

Notes

One channel to measure the flow to each steam generator


Parameter


4. Progra.m:med steam generator level signal

5. Main feedwater flow

6. Magnitude of signal

control valves

SGS-UFSAR


1/steam generator

2/steam generator

1/main 1/bypass

TABLE 7.5-2 (Cont.)

Range

0-100%

0 to 120% of maximum calculated flow

0 to 100% of valve opening

Accuracy

±5%

±1.5%

10 of 11

Indicator/ Recorder

lUI channels indicated.


All channels indicated

Notes

l. One channel for each main and bypass feedwater control valve

2. OPEN/SHUT indication is provided in the control room for each main and bypass feedwater control valve.


I

Parameter


7. Steam flow

8. Steam line pressure

9. Steam dump modulated signal

10. Turbine steamline inlet pressure

SGS-UFSAR


2/steam generator

3/loop

1

2

TABLE 7.5-2 (Cont.)

0 to 120% of maximum calculated flow

0 to 1200 psig

0 - 85% max calculated steam flow

0 to 120% to max calculated turbine load

Accuracy

±10%

±5.5%

±1.5%

±3.5%

11 of 11

:Cndicator/ Recorder


All channels indicated and 1 is recorded.

The one channel is indicated

Both cha:mels indicated.

OPEN/SHUT indication is provided in the control roo:n for each steam dump valve.

OPEN/SHUT indication is provided in control room for each turbine stop valve.


I

TABLE 7.5-3

INDEX TYPE "A" VARIABLES

Variable Description Variable Reference Reactor Coolant System Hot Leg 5 Water Temperature

Reactor Coolant Pressure 6

Degrees of Subcooling 9 Containment Pressure 11 Refueling Water Storage Tank Level 27 Pressurizer Level 30 Steam Generator Pressure 36 Auxiliary Feedwater Flow 39 Auxiliary Feedwater Storage Tank 40 Level {Condensate Storage Tank)

steam Generator Water Level - Narrow Range 35a

1 of 1 SGS-UFSAR

No.

Revision 16 January 31, 1998

Variable Ref. No.

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

16

SGS-UFSAR

TABLE 7.5-4

SUMMARY OF INSTRUMENTATION COMPLIANCE WITH REGULATORY GUIDE 1.97

Variable

Neutron Flux (Source Range, Intermediate range, Power range) - Monitors

Control Rod Position

RCS Soluble Boron Concentration

RCS Cold Water

- Indication

RCS Hot Leg Water Temperature RTDs

- Indication

RCS Pressure Transmitters

Core Exit Temperature - Thermocouples

Coolant Level in Reactor

of Subcooling - Display (inputs - See variable Ref. No. 6 and 7)

Containment Sump Water Level -Transmitters and Level Switches

Containment Pressure (narrow and wide range) - Transmitters

Containment Isolation Valve Position (excluding check valves) - Limit Switches

Concentration or Radiation Level in Circulating Primary Coolant

Analysis of Primary Coolant (Gamma

Containment Area Radiation - Monitors

Effluent Noble Gas Effluent from Condenser Air Removal System Exhaust - Monitors

1 of 5

Level

Unit 1-2 Unit 2-1

1

1

Unit 1-3a Unit 2-1 Unit 1-3b Unit 2-1

3a Unit 1-3b Unit 2-1

Unit 1-3a Unit 2-1

1

1

1

3a

Unit 1-3a Unit 2-1

1

5

5

3a

1


Variable

17

18

19

20

21

22

23

24

25

26

27

28

29

30

31

SGS-UFSAR

TABLE 7.5-4 (Cont)

Variable

Containment 3ydrogen Concentration -

Containment Effluent Radioactivity Noble Gases from Identified Release Points - Monitors

Radiation Exposure Rate (Electrical Penetration Area) - Monitors

RHR Sys~em Flow - Transmitters

RHR Hea-: Exchanger Outlet Temperature -

Accumulator Tank Level and Pressure -- Transmitters - Transmitter

Accumulator Isolation Valve Position

Boric Acid Flow Transmitters

Flow in HPI Transmitters

Flow in LPI System - Transmitters

Water Tank Level and Low Level Alarm - Transmitters

Transmitter Range

Reactor Coolant Pump Status

Primary Relief Valve Positions (including PORV and code valves) or Flow through or Pressure in Relief Valve Lines

Pressurizer Level - Transmitters

- Transmitter

Pressurizer Heater Status (Current) - Heaters

2 of 5

3a

3b

3b

3a

4b

1

Unit 1-3a Unit 2-1

3a

3a

Unit 1-3a Unit 2-1 Unit 1-4c Unit 2-1

1

1

Unit -3a Unit -1 Unit -4c Unit -1

2


•

•

•

Variable Ref. No.

32

33

34

35

35A

36

37

38

39

40

41 41A

42

43

44

45

46

47

48

49

SGS-UFSAR

TABLE 7.5-4 (Cont)

Variable Description

Compliance Level

Quench Tank Level (Pressurizer Relief Tank) - Transmitters

.Range

Quench Tank Temperature (Pressurizer Relief Tank)

Quench Tank Pressure (Pressurizer Relief Tank)

Transmitters Range

Steam Generator Level - Transmitters

steam Generator Level - Narrow Range

Steam Generator Pressure - Transmitters

Safety/Relief Valve Positions or Main Steam Flow - Transmitters

Main Feedwater Flow

Auxiliary Feedwater Flow - Transmitters

condensate Storage Tank Water Level (Auxiliary Feedwater Storage Tank) - Transmitters

COntainment Spray Flow Containment Spray Flow Additive Rate - Transmitters

Beat Removal by the Containment Fan Beat Removal System - Transmitters

containment Atmosphere Temperature

Containment Sump Water Temperature

CVCS Makeup Flow-in - Transmitters

Letdown Flow - Transmitters

Volume Control Tank Level - Transmitters

Component Cooling Water Temperature to ESF System - Transmitters

Component Cooling Water Flow to ESF System - Transmitters

3 of 5

4c

3b

l

Unit 1-3a Unit 2-1

Unit 2-1

Unit 1-3a Unit 2-1

3a

1

Unit l-3a Unit 2-1

Unit 1-4a Unit 2-1

5

3a

3a

4b

5

3a

Unit 1-3b Unit 2-1

4a

Unit 1-4a Unit 2-1

4b

Revision 15 June 12, 1996

Variable Ref. No.

50

51

52

52 A

528

53

53 A

54

55

56

57

58

59

60A

608

61

62

63

SGS-UFSAR

TABLE 7.5-4 (Cont.)

Variable Compliance Description Level

High-Level Radioactive Liquid Tank Level - Indication 3b

Radioactive Gas Holdup Tank Pressure-Indication 3b

Emergency Ventilation Damper Position -control Room Damper Limit Switches 4a

Emergency Ventilation Damper Position -Auxiliary Bldg. Damper Limit Switches 4a

Emergency Ventilation Damper Position -Fuel Handling Bldg. 4a

Status of Standby Power 5

status of Control Air 5

Containment or Purge Effluent N/A

Reactor Shield Building Annulus Effluent N/A

Auxiliary Building Effluent N/A

condenser Air Removal System Exhaust N/A

Common Plant Vent or Multi-Purpose Vent Discharging any of above releases -Monitors 3a

Vent from Steam Generator Safety Relief Valves or Atmospheric Dump Valves -Monitors s All other identified Release Points (Decontamination Bldg.) -Monitors 3b

All other identified Release Points (Auxiliary Feed Pump Turbine Exhaust} -Monitors 5

All Identified Plant Release Points -Monitors (Particulates and Halogens) 3a

Radiation Exposure Meters 5

Airborne radiohalogens and particulates (portable sampling with onsite analysis capability) 1

4 of 5 Revision 16 January 31, 1998

Variable Ref. No.

64

65

66

67

68

69

70

71

72

TABLE 7.5-4 {Cont.)

Variable Description

Plant and Environs Radiation -Instrument Range

Plant and Environs Radioactivity

Wind Direction

Wind Speed

Estimation of Atmospheric Stability

Primary Coolant (Grab Sample)

Containment Air (Grab sample}

Containment Sump (Grab sample)

Effluent Radioactivity - Noble Gases -Monitors

73 DELETED*

Compliance Level

4c

1

1

1

1

5

5

5

3a

*ijOTE This variable is replaced by variable 35a as primary indication of SGTR


May 6, 2003

TABLE 7.5-5

JUSTIFICATION FOR NONCONFORMANCE TO REGULATORY GUIDE 1.97

Variable Reference No.

4

5

13

14

24

27

35

39

40

41

42

44

SGS-UFSAR

Justification

Isolation devices are not provided for these variables. However, these variables will be on the safety parameter display system and Class lE multiplexors will have qualified isolation devices.

Same as 4

There is radiation monitoring on the letdown line; however, during an accident this line is isolated. The back-up or alternate means of measuring this variable is the Sampling System.

The Sampling System obviates the need for this variable.

Same as 4

Same as 4

Same as 4

Same as 4

Same as 4

An alternate means of determining the containment spray flow is the spray additive tank flow rate, which is available (refer to Variable Code No. 41a). The spray additive tank flow rate is the flow of liquid which is educted to the suction of the containment spray pumps. The eduction is accomplished by recirculating the containment spray liquid from the discharge to the suction of the containment spray pumps. Indication of the spray additive flow provides confirmation of containment spray pumps operation.

Same as 4

The containment sump temperature indication is not required in Safety Guide 1, "Net Positive Suction Head for Emergency Core Cooling and

1 of 3 Revision 20 May 6, 2003

I

Variable

45

46

47

49

53

53A

SGS-UFSAR

TABLE 7.5-5 (Cont)

Containment Heat Removal System Pumps". PSE&G' s Emergency Core Cooling and Containment Heat Removal pumps,

suction storage

Same as

Same as

Same as

Same as

from tank

Guide

4

4

4

4

the residual heat removal pumps which take the containment sump when the refueling water

is empty, were designed to meet the criteria in 1.

1) The vi tal instrument bus parameters current, watts) aYe not adjustable by the

(voltage, frequency, operator. The vital

instru.ment inverter bus and automatically switches to the backup action.

supply without operator

2) Vi tal Instrument Bus Inverter failure annunciated on the overhead annunciator, Failure of all Channel Indications, and auxiliary alarm typewriter 115 VAC Instrument Bus Loss of

in alarm conditions for Loss of Vital Instrument Bus These lead the operator through actions required due to the loss of a vita: instrument bus to maintain the plant in a safe condition and to maintain

with the Technical The alarms are expected to be available during accident conditions.

3) The inverter and

on every shift. abnormalities are

volts, inverter output frequency, line are moni tared

must be taken if inverters are located in an

accessible mild environment area.

1) The PORV accumulators are normally supplied air by the control air header which is monitored by RG 1.97 instruments. In the event the air header containment isolation valves are closed the PORVs, the minimum of 100

can

control air from air to accumulators are designed to supply for a close/ open cycles. There are no actions the

with to the PORV accumulators air pressure actions to restore the control air. The operator is directed to procedures for loss of control air that contains steps necessary to restore control air pressure.

2) The accumulators are provided with low air pressure alarms to indicate that the air supply available to opera~e the PORVs is low. The alarm response directs the operator to for loss of control a'r that contains steps necessary to restore control air pressure. The alarms are expec~ed to be available during accident conditions.

2 of 3 Revision 25 October 26, 2010

TABLE 7.5-5 (Cont)

Variable Reference No. Justification

59

60B

62

69, 70, 71

73

The steam generator safety relief valves and the atmospheric dump valves are located on the main steam line, upstream of the MSIV. A radiation monitor is installed on the main steam line of each steam generator also upstream of the MSIV. This monitor will therefore give an indication of the level of radiation in the steam from the vents if the steam generator safety relief valves or the atmospheric dump valves should open.

The steam supply to the auxiliary feed pump is taken from the main steam line of No. 11 (21) and No. 13 (23) steam generators, upstream of the MSIVs. A radiation monitor is installed on the main steam line of each steam generator also upstream of the MSIV. If the auxiliary feed pump is in operation, this monitor will therefore give an indication of the level of radiation in the exhaust.

This variable was deleted in Revision 3 of Regulatory Guide 1.97.

These variables were changed to level 5 as a result of Technical Specification Amendments 254/235, which allows the use of contingency sampling capability in lieu of PASS.

DELETED*

*NOTE This variable is replaced by variable 35a as primary indication of SGTR.


May 6, 2003

table 7.5-1 main control room indicators and/or … · ndtt considerations. monitor containment...

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