ML17046A422
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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 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. 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 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 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 channels are 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 -ll°F bias Core uncovered and CET at 700"F -85°F bias Core uncovered and CET at 1200°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 106 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 No. of Channels Available 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 Revision 6 February 15, 1987 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 psig Ent1re distance between taps o-1oo* 0 to 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/ All channels One channel indicated. is selected for recording. All channels indicated. One channel is selected for recording. All channels indicated One channel 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 No. of Channels Available 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. Revision 6 February 15, 1987 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. Revision 6 February 15, 1987 Parameter REACTOR CONTROL SYSTEM (Cont.! 5. c. Full length rod measured position Control rod bank demanded position SGS-UFSAR No. of Channels Available 1 for each rod 4 0 to 230 steps 0 to 230 step!! TABLE 7.5-2 (Cont.) Accuracy Unit 1, +12 steps 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 No. of Channels Available 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 Refer to Applicable Loop Accuracy Calculation Refer to Applicable Loop Accuracy Calculation 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 Revision 17 October 16, 1998 Parameter FEEDWATER AND STEAM SYSTEMS 4. Progra.m:med steam generator level signal 5. Main feedwater flow 6. Magnitude of signal control valves SGS-UFSAR No. of Channels Available 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. The channels used for control are recorded. 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. Revision 25 October 26, 2010 I Parameter FEEDWATER AND STEAM SYSTEMS 7. Steam flow 8. Steam line pressure 9. Steam dump modulated signal 10. Turbine steamline inlet pressure SGS-UFSAR No. of Channels Available 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. The channels used for control are recorded. 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. Revision 25 October 26, 2010 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 Revision 25 October 26, 2010 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 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 Revision 25 October 26, 2010
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- 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 5 of 5 SGS-UFSAR Revision 20 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 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 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. 3 of 3 SGS-UFSAR Revision 20 May 6, 2003