ML20106E919
Text
Catawba Nuclear Station UFSAR Appendix 7A. Tables Appendix 7A. Tables
Catawba Nuclear Station UFSAR Table 7-1 (Page 1 of 2)
(22 OCT 2001)
Table 7-1. List of Reactor Trips Reactor Trip Coincidence Logic Interlocks Comments
- 1.
High neutron flux (Power Range) 2/4 Manual block of low setting permitted by P-10 High and low setting; manual block and automatic reset of low setting by P-10
- 2.
Intermediate range neutron flux 1/2 Manual block permitted by P-10 Manual block and automatic reset
- 3.
Source range neutron flux 1/2 Manual block permitted by P-6, interlocked with P-10 Manual block and automatic reset.
Automatic block above P-10
- 4.
Power range high positive neutron flux rate 2/4 No interlocks
- 5.
Overtemperature T 2/4 No interlocks
- 6.
Overpower T 2/4 No interlocks
- 7.
Pressurizer low pressure 2/4 Interlocked with P-7 Blocked below P-7
- 8.
Pressurizer high pressure 2/4 No interlocks
- 9.
Pressurizer high water level 2/3 Interlocked with P-7 Blocked below P-7
- 10.
Low reactor coolant flow 2/3 in any loop Interlocked with P-7 and P-8 Low flow in one loop will cause a reactor trip when above P-8 and a low flow in two loops will cause a reactor trip when above P-7. Blocked below P-7.
1/4 Interlocked with P-8 Blocked below P-8.
- 11.
Reactor coolant pump undervoltage 2/4 Interlocked with P-7 Low voltage to RCP motors permitted below P-7.
- 12.
Reactor coolant pump underfrequency 2/4 Interlocked with P-7 Underfrequency on 2 motors will trip all reactor coolant pump breakers and cause reactor trip; reactor trip blocked below P-7
Catawba Nuclear Station UFSAR Table 7-1 (Page 2 of 2)
(22 OCT 2001)
Reactor Trip Coincidence Logic Interlocks Comments
- 13.
Low-low steam generator water level 2/4 in any loop No interlocks
- 14.
Safety injection signal Coincident with actuation of safety injection No interlocks (See Section 7.3 for Engineered Safety Features actuation conditions)
- 15.
Turbine (anticipatory) trip a) Low stop valve EH pressure 2/4 Interlocked with P-9 Blocked below P-9 b) Turbine stop valve closed 4/4 Interlocked with P-9 Blocked below P-9
- 16.
Manual 1/2 No interlocks
Catawba Nuclear Station UFSAR Table 7-2 (Page 1 of 1)
(22 OCT 2001)
Table 7-2. Protection System Interlocks Designation Derivation Function I POWER ESCALATION PERMISSIVES P-6 Presence of P-6: 1/2 neutron flux (intermediate range) above setpoint Allows manual block of source range reactor trip Absence of P-6: 2/2 neutron flux (intermediate range) below setpoint Defeats the block of source range reactor trip P-10 Presence of P-10: 2/4 neutron flux (power range) above setpoint Allows manual block of power range (low setpoint) reactor trip Allows manual block of intermediate range reactor trip and intermediate range rod stops (C-1)
Blocks source range reactor trip (back-up for P-6)
Absence of P-10: 3/4 neutron flux (power range) below setpoint Defeats the block of power range (low setpoint) reactor trip Defeats the block of intermediate range reactor trip and intermediate range rod stops (C-1)
Input to P-7 II BLOCKS OF REACTOR TRIPS P-7 Absence of P-7: 3/4 neutron flux (power range) below setpoint (from P-
- 10)
Blocks reactor trip on: Low reactor coolant flow in more than one loop, RCP undervoltage, RCP underfrequency, pressurizer low pressure, and pressurizer high level P-8 Absence of P-8: 3/4 neutron flux (power range) below setpoint Blocks reactor trip on low reactor coolant flow in a single loop P-9 Absence of P-9: 3/4 neutron flux (power range) below setpoint Blocks reactor trip on turbine trip P-13 2/2 turbine impulse chamber pressure below setpoint Input to P-7
Catawba Nuclear Station UFSAR Table 7-3 (Page 1 of 3)
(17 APR 2012)
Table 7-3. Reactor Trip System Instrumentation Reactor Trip Signal Typical Range Typical Trip Accuracy Maximum Time Response (sec)
- 1.
Power range high neutron flux 0 to 120% full power 1% of full power 0.5(3)
- 2.
Intermediate range high neutron flux 10 decades of neutron flux overlapping source range by 5 decades 8% of span (From CNC-1552.08-00-0360, Rev. 1)
N.A.
- 3.
Source range high neutron flux 7 decades of neutron flux (0.1 to 106 counts/sec) 9.5% of span (From CNC-1552.08-00-0359, Rev. 1)
N.A.
- 4.
Power range high positive neutron flux rate Neutron flux (0-120% full power)
+/-5 percent 1 N.A.
- 5.
Overtemperature T:
- a. Narrow Range RTD time constants
- b. Thot and Tcold input to T
- c. Tavg input to setpoint
- d. Pressurizer pressure input to setpoint
- e. Flux imbalance input to setpoint TH 530 to 650°F TC 510 to 630°F TAV 530 to 630°F PPRZR1700 to 2500 psig F () +/-60 T Setpoint 0 to 100°F (0-150%)
+/-7.9°F
- a. 8.0 seconds (Unit 1) 8.0 seconds (Unit 2)
- b. 1.5 seconds
- c. 1.5 seconds
- d. 1.5 seconds
- e. 1.5 seconds3
Catawba Nuclear Station UFSAR Table 7-3 (Page 2 of 3)
(17 APR 2012)
Reactor Trip Signal Typical Range Typical Trip Accuracy Maximum Time Response (sec)
- 6.
Overpower T
- a. Narrow Range RTD time constants
- b. Thot and Tcold input to T
- c. Tavg input to setpoint
- d. Flux imbalance input to setpoint TH530 to 650°F TC 510 to 630°F TAV 530 to 630°F T Setpoint 0 to 100°F (0-150%)
+/-4.4°F
- a. 8.0 seconds (Unit 1) 8.0 seconds (Unit 2)
- b. 1.5 seconds
- c. 1.5 seconds
- d. 1.5 seconds3
- 7.
Pressurizer low pressure 1700 to 2500 psig
+/-18 psi (Compensated signal) 2.0
- 8.
Pressurizer high pressure 1700 to 2500 psig
+/-18 psi (non-compensate signal) 2.0
- 9.
Pressurizer high water level Entire cylindrical portion of pressurizer (distance between taps)
+/-2.3 percent of full range between taps at design temperature and pressure.
N.A.
- 10.
Low reactor coolant flow 0 to 120% of rated flow
+/-2.5 percent of full flow within range of 70 percent to 100 percent of full flow 1 1.0
- 11.
Reactor Coolant pump undervoltage 0 to 100% rated voltage
+/-1%
1.5
- 12.
Reactor coolant pump underfrequency 50 to 65 Hz
+/-0.1 Hz 0.6
Catawba Nuclear Station UFSAR Table 7-3 (Page 3 of 3)
(17 APR 2012)
Reactor Trip Signal Typical Range Typical Trip Accuracy Maximum Time Response (sec)
- 13.
Low-low steam generator water level
+/-~ 6 ft. (unit 2), +/-~ 8 ft. (unit 1) from nominal full load water level
+/-2.3 percent of signal over pressure range of 700 to 1200 psig 2.0
- 14.
Turbine trip N.A.
- 15.
Manual Reactor Trip N.A.
- 16.
Safety Injection Input from ESF N.A.
Notes:
- 1. Reproducibility (see definitions in 7.0).
- 2. Accuracy of steam flow signal is +/-3 percent of maximum calculated flow over the pressure range of 700 to 1200 psig.
- 3. Does not include neutron detector.
Catawba Nuclear Station UFSAR Table 7-4 (Page 1 of 4)
(22 OCT 2001)
Table 7-4. Reactor Trip Correlation Trip1 Accident2 Tech Spec.3/
UFSAR3
- 1.
Power Range High Neutron Flux Trip (Low Setpoint)
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From a Subcritical Condition or Low Power Startup Condition (15.4.1)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Feedwater System Malfunctions that result in a Reduction in Feedwater Temperature (15.1.1)
- 3.
Spectrum of Rod Cluster Control Assembly Ejection Accidents (15.4.8)
- 4.
Chemical and Volume Control System Malfunction That Results In A Decrease In Boron Concentration In The Reactor Coolant (15.4.6)
- 2.
Power Range High Neutron Flux Trip (High Setpoint)
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From a Subcritical or Low Power Startup Condition (15.4.1)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
- 3.
Startup of an Inactive Reactor Coolant Pump At An Incorrect Temperature (15.4.4)
- 4.
Feedwater System Malfunctions That Result in a reduction In Feedwater Temperature (15.1.1)
- 5.
Excessive Increase In Secondary Steam Flow (15.1.3)
- 6.
Inadvertent Opening of A Steam Generator Relief or Safety Valve (15.1.4)
- 7.
Steam System Piping Failure (15.1.5)
- 8.
Spectrum of Rod Cluster Control Assembly Ejection Accidents (15.4.8)
- 9.
Rod Cluster Control Assembly Misoperation (15.4.3)
- 3.
Intermediate Range High Neutron Flux Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From a Subcritical or Low Power Startup Condition (15.4.1)
See Note 4 Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
Catawba Nuclear Station UFSAR Table 7-4 (Page 2 of 4)
(22 OCT 2001)
Trip1 Accident2 Tech Spec.3/
UFSAR3
- 4.
Source Range High Neutron Flux Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From a Subcritical or Low Power Startup Condition (15.4.1)
See Note 4 Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Chemical and Volume Control System Malfunction That Results In A Decrease In Boron Concentration In the Reactor Coolant (15.4.6)
- 5.
Power Range High Positive Neutron Flux Rate Trip
- 1.
Spectrum of Rod Cluster Control Assembly Ejection Accidents (15.4.8)
Table 3.3.1-1/-
See Note 4 3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From A Subcritical Or Low Power Startup Condition (15.4.1)
- 6.
Overtemperature T Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Chemical and Volume Control System Malfunction that Results in a Decrease in Boron Concentration in the Reactor Coolant (15.4.6)
- 3.
Loss of External Load and/or Turbine Trip (15.2.2/ 15.2.3)
- 4.
Feedwater System Malfunctions That Result in a Reduction in Feedwater Temperature (15.1.1)
- 5.
Excessive Increase In Secondary Steam Flow (15.1.3)
- 6.
Inadvertent Opening Of A Pressurizer Safety or Reliefs Valve (15.6.1)
- 7.
Inadvertent Opening Of A Steam Generator Relief or Safety Valve (15.1.4)
- 8.
Loss-Of-Coolant Accidents (15.6.5)
- 9.
Feedwater System Pipe Break (15.2.8)
- 10.
Rod Cluster Control Assembly Misoperation (15.4.3)
- 11.
Steam Generator Tube Failure (15.6.3)
Catawba Nuclear Station UFSAR Table 7-4 (Page 3 of 4)
(22 OCT 2001)
Trip1 Accident2 Tech Spec.3/
UFSAR3
- 7.
Overpower T Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Feedwater System Malfunctions That Result in a Reduction In Feedwater Temperature (15.1.1)
- 3.
Excessive Increase In Secondary Steam Flow (15.1.3)
- 4.
Inadvertent Opening Of A Steam Generator Relief Of Safety Valve (15.1.4)
- 5.
Steam System Piping Failure (15.1.5)
- 8.
Pressurizer Low Pressure Trip
- 1.
Inadvertent Opening Of A Pressurizer Safety Or Relief Valve (15.6.1)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Loss-Of-Coolant Accidents (15.6.5)
- 3.
Deleted Per 2001 Update.
- 4.
Steam Generator Tube Failure (15.6.3)
- 9.
Pressurizer High Pressure Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Loss of External Load and/or Turbine Trip (15.2.2/ 15.2.3)
- 3.
Feedwater Sysem Pipe Break (15.2.8)
- 10.
Pressurizer High Water Level Trip
- 1.
Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
Table 3.3.1-1/-
See Note 4 3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Loss of External Load and/or Turbine Trip (15.2.2/ 15.2.3)
- 11.
Low Reactor Coolant Flow
- 1.
Partial Loss of Forced Reactor Coolant Flow (15.3.1)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Loss of Non-Emergency AC Power to the Station Auxiliaries (15.2.6)
- 3.
Complete Loss of Forced Reactor Coolant Flow (15.3.1)
- 4.
Startup Of An Inactive Reactor Coolant Pump At An Incorrect Temperature (15.4.4)
Catawba Nuclear Station UFSAR Table 7-4 (Page 4 of 4)
(22 OCT 2001)
Trip1 Accident2 Tech Spec.3/
UFSAR3
- 12.
Reactor Coolant Pump Under-voltage Trip
- 1.
Complete Loss of Forced Reactor Coolant Flow (15.2.1)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Partial Loss Of Forced Reactor Coolant Flow (15.3.1)
- 13.
Reactor Coolant Pump Under-frequency Trip
- 1.
Complete Loss of Forced Reactor Coolant Flow (15.3.2)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 14.
Low-low Steam Generator Water Level Trip
- 1.
Loss of Normal Feedwater Flow (15.2.7)
Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Turbine Trip (15.2.3)
- 3.
Feedwater System Pipe Break (15.2.8)
- 15.
Safety Injection Signal Actuation Trip
- 1.
Inadvertent Opening Of A Steam Generator Relief Or Safety Valve (15.1.4)
See Note 5 3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Steam System Piping Failure (15.1.5)
- 3.
Feedwater System Pipe Break (15.2.8)
- 16.
- 1.
Loss of External Load and/or Turbine Trip (15.2.2/ 15.2.3)
See Note 4 Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 2.
Loss of Non-Emergency AC Power to the Station Auxiliaries (15.2.6)
See Note 4 Table 3.3.1-1/-
3.3.1 / Table 7-3 3.3.2 / Table 7-15
- 17.
Manual Trip Available for all Accidents (15.0)
See note 4 3.3.1 / Table 7-3 3.3.2 /Table 7-15 Notes:
- 1. Trips are listed in order of discussion in 7.2.
- 2. References refer to accident analyses presented in Chapter 15.
- 3. References refer to Technical Specifications and UFSAR Sections.
- 4. A response time Technical Specification is not required because this trip is not assumed to function in the accident analyses, or it is not a time critical action.
- 5. Reactor trip occurs in conjunction with safety injection on setpoints in Technical Specifications, Table 3.3.2-1, item 1.
Catawba Nuclear Station UFSAR Table 7-5 (Page 1 of 1)
(17 APR 2012)
Table 7-5. Instrumentation Operating Condition for Engineered Safety Features No.
Functional Unit No. of Channels No. of Channels to Trip
- 1.
Safety Injection
- a. Manual 2
1
- b. High Containment Pressure 3
2
- c. Pressurizer Low Pressure 4
2
- 2.
- a. Manual 2
1 Deleted Per 2012 Update.
4 2
Catawba Nuclear Station UFSAR Table 7-6 (Page 1 of 1)
(17 APR 2012)
Table 7-6. Instrument Operating Conditions for Isolation Functions No.
Functional Unit No. Of Channels No. Of Channels To Trip
- 1. Containment Isolation
- a. Automatic Safety Injection (Phase A)
See item No. 1 (b) and (c) of Table 7-5
- b. Containment Pressure (Phase B) 4 2
- c. Manual Phase A Phase B 2
2 1
1
- 2. Steam Line Isolation
- a. High Steam Negative Pressure Rate 12 (3/steam line) 2/steam line in any steam line.
- b. Containment Pressure (High-High) 4 2
- c. Low steam line pressure 12 (3/steam line) 2/steam line
- d. Manual 1/loop1 1/loop1
- 3. Feedwater Line Isolation
- a. Safety Injection See Item No. 1 of Table 7-5
- b. Steam Generator High-High level 2/4 on any Steam Generator 4/loop 2/loop
- c. Low Tavg interlocked with P4 See P4 on Table 7-7 Note:
- 1. Additionally, there will be two switches (one for train A and one for train B) that will actuate all four main steam line isolation and bypass valves at the system level.
Catawba Nuclear Station UFSAR Table 7-7 (Page 1 of 2)
(22 OCT 2001)
Table 7-7. Interlocks for Engineered Safety Features Actuation System Designation Input Function Performed P-4 Reactor trip (a)
Actuates turbine trip (b) Closes main feedwater valves on Tavg below setpoint (c)
Prevents opening of main feedwater valves which were closed by safety injection or High-High steam generator water level (d) Allows manual block of the automatic reactuation of safety injection (e)
Blocks steam dump control via load rejection Tavg controller (f)
Makes steam dump valves available for either tripping or modulation (g) Runback of Main Feedwater Pump Turbines (non-safety function)
Reactor not tripped (a)
Defeats the block preventing automatic reactuation of safety injection (b) Block steam dump control via plant trip Tavg controller P-11 2/3 Pressurizer pressure below setpoint (a)
Allows manual block of safety injection actuation on low pressurizer pressure signal (b) Allows manual block of steamline isolation on low compensated steamline pressure signal and allows steamline isolation on high steamline negative pressure rate P-11 2/3 Pressurizer pressure above setpoint (a)
Reinstates automatically steamline isolation on low steamline pressure.
Reinstates automatically safety injection on low pressurizer pressure. Automatically blocks steamline isolation on high steamline negative pressure rate.
(b) Defeats manual block of steamline isolation on low steamline pressure.
Defeats manual block of safety injection on low pressurizer pressure. Defeats steamline isolation on high steamline negative pressure rate.
Catawba Nuclear Station UFSAR Table 7-7 (Page 2 of 2)
(22 OCT 2001)
Designation Input Function Performed (c)
Defeats manual block of motor driven auxiliary feedwater pumps automatic starting on 2/4 low-low steam generator level and loss of both main feedwater pumps as described in Section 7.4.1.1.
(d) Defeats manual block of Turbine Trip and Feedwater Isolation on 2/4 Hi-Hi Steam Generator Level.
P-12 2/4 Tavg below setpoint (a)
Blocks steam dump (b) Allows manual bypass of steam dump block for the cooldown valves only 3/4 Tavg above setpoint (a)
Defeats the manual bypass of steam dump block P-14 2/4 Steam generator water level above setpoint on any steam generator (a)
Closes all feedwater control valves (b) Trips all main feedwater pumps which closes the pump discharge valves (c)
Actuates turbine trip
Catawba Nuclear Station UFSAR Table 7-8 (Page 1 of 2)
(22 OCT 2001)
Table 7-8. Auxiliary Shutdown Panel A Instrumentation And Controls Available For Hot Shutdown INDICATORS:
Steam Generator A Level Steam Generator B Level Steam Generator A Pressure Steam Generator B Pressure Auxiliary Feedwater Flow to Steam Generator A Auxiliary Feedwater Flow to Steam Generator B Auxiliary Feedwater Condensate Storage Tank Level Low Condenser Hotwell Level Low Upper Surge Tank Level Low Auxiliary Feedwater Pumps Train A Loss of Normal Suction Nuclear Service Water System Flow Component Cooling Water System Flow Centrifugal Charging Flow Letdown Flow Pressurizer Level Pressurizer Pressure Reactor Coolant Cold Leg Temperature & Hot Leg Temperature Seal Injection Flow Volume Control Tank Level Boric Acid Flow Boric Acid Tank Level LOCA Sequencer Activated Status Light B/O Sequencer Activated Status Light Diesel Generator A Status Light Auxiliary Shutdown Panel Relay Status AC Low Pressure Mode Light NC Loop B Wide Range Pressure NC Loop C Wide Range Pressure CONTROLS:
Catawba Nuclear Station UFSAR Table 7-8 (Page 2 of 2)
(22 OCT 2001)
Auxiliary Shutdown Panel A Transfer Switch Auxiliary Feedwater Motor A Start/Stop Auxiliary Feedwater Pump A Normal Suction Valve CA11A Auxiliary Feedwater Pump A RN Suction Valve CA15A Nuclear Service Water Supply Valve RN250A Auxiliary Feedwater Pump A Discharge to Steam Generator A Isolation Valve 1CA62A Auxiliary Feedwater Pump A Discharge to Steam Generator B Isolation Valve 1CA58A Auxiliary Feedwater Pump A Auxiliary Feedwater to SG A Valve Position Selector Station (CA60)
Auxiliary Feedwater Pump A Auxiliary Feedwater to SG 1B Valve Position Selector Station (CA56)
Nuclear Service Water Pump A Component Cooling Water Pump A1 Component Cooling Water Pump A2 Boric Acid Transfer Pump A Centrifugal Charging Pump A Component Cooling System Valves - KC1A, KC3A, KC50A, KC230A, KCC37A Chemical & Volume Control Systems Valves -
- NV1A, NV2A,
- NV13A, NV37A,
- NV11A, NV186A, NV172A, NV238A, NV148, NV309, NV294, NV39A Pressure #1 Power Operated Safety Relief Valves -
NC33A, NC34A Pressurizer Heater Cold Leg Accumulator C discharge isolation -
NI76A Cold Leg Accumulator A discharge isolation -
NI54A Sequencer Reset Residual Heat Removal Pump A Suction - ND002 Residual Heat Removal Pump B Suction - ND037 Resideual Heat Removal Pump A
Catawba Nuclear Station UFSAR Table 7-9 (Page 1 of 3)
(22 OCT 2001)
Table 7-9. Auxiliary Shutdown Panel B Instrumentation And Controls Available For Hot Shutdown INDICATORS:
Steam Generator C Level Steam Generator D Level Steam Generator C Pressure Steam Generator D Pressure Auxiliary Feedwater Flow to Steam Generator C Auxiliary Feedwater Flow to Steam Generator D Auxiliary Feedwater Condensate Storage Tank Level Low Condenser Hotwell Level Low Upper Surge Tank Level Low Auxiliary Feedwater Pumps Train B Loss of Normal Suction Pressurizer Level Pressurizer Pressure Reactor Coolant Cold Leg Temperature
& Hot Leg Temperature Nuclear Service Water System Flow Component Cooling Water System Flow Centrifugal Charging Flow Seal Injection Flow Volume Control Tank Level Boric Acid Flow Boric Acid Tank Level LOCA sequencer activated status light B/O sequencer activated status light Diesel Generator B status light Auxiliary Shutdown Panel Relay Status NC Loop C Wide Range Pressure Low Pressure Mode Status Light CONTROLS:
Catawba Nuclear Station UFSAR Table 7-9 (Page 2 of 3)
(22 OCT 2001)
Auxiliary Shutdown Panel B Transfer Switch Auxiliary Feedwater Motor B Start/Stop Auxiliary Feedwater Pump B Normal Suction Valve CA9B Auxiliary Feedwater Pump B RN Suction Valve CA18B Nuclear Service Water Supply Valve RN310B Auxiliary Feedwater Pump B Discharge to Steam Generator C Isolation Valve CA46B Auxiliary Feedwater Pump B Discharge to Steam Generator D Isolation Valve CA42B Auxiliary Feedwater Pump B Auxiliary Feedwater to SG C Valve Position Selector Station (CA44)
Auxiliary Feedwater Pump B Auxiliary Feedwater to SG ID Valve Position Selector Station (CA40)
Nuclear Service Water Pump B Component Cooling Water Pump B1 Component Cooling Water Pump B2 Boric Acid Transfer Pump B Centrifugal Charging Pump B Auxiliary Shutdown Panel B Instrumentation And Controls Available For Hot Shutdown Component Cooling System Valves -
KC2B, KC18B, KC53B, KC228B, KCC40B Chemical & Volume Control Systems Valves - NV122B, NV123B, NV124B, NV125B, NV236B, NV309, NV32B Pressurizer #1 Power Operated Safety Relief Valves NC31B, NC32B, NC35B, NC36B Pressurizer Heater
Catawba Nuclear Station UFSAR Table 7-9 (Page 3 of 3)
(22 OCT 2001)
Cold Leg Accumulator D discharge isolation - NI88B Cold Leg Accumulator B discharge isolation - NI65B Sequencer Reset Residual Heat Removal Pump A Suction
- ND001B Residual Heat Removal Pump B Suction
- ND36B Residual Heat Removal Pump B Train B Auxiliary Feedwater Pumps Discharge Valves Auto-Start Alignment Reset Switch
Catawba Nuclear Station UFSAR Table 7-10 (Page 1 of 2)
(22 OCT 2001)
Table 7-10. Auxiliary Feedwater Pump Turbine Control Panel Instrumentation And Controls Available For Hot Shutdown INDICATORS:
Steam Generator A Level Steam Generator B Level Steam Generator C Level Steam Generator D Level Steam Generator A Pressure Steam Generator B Pressure Steam Generator C Pressure Steam Generator D Pressure Auxiliary Feedwater Flow to Steam Generator A Auxiliary Feedwater Flow to Steam Generator B Auxiliary Feedwater Flow to Steam Generator C Auxiliary Feedwater Flow to Steam Generator D Steam Supply Press to CA Pump Turbine INDICATING LIGHTS:
Steam Supply Valve SA2 Open-Close Steam Supply Valve SA5 Open-Close Condenser Hotwell Level Upper Surge Tank Level Auxiliary Feedwater Condensate Storage Tank Level Auxiliary Feedwater Pumps Loss of Normal Suction CONTROLS:
Auxiliary Feedwater Turbine Driven Pump Steam Drain Isolation TE33A Auxiliary Feedwater Turbine Driven Pump Discharge to SG A Isolation Valve CA54B Auxiliary Feedwater Turbine Driven Pump Discharge to SG B Isolation Valve CA66B Auxiliary Feedwater Turbine Driven Pump Discharge to SG C Isolation Valve CA50A Auxiliary Feedwater Turbine Driven Pump Discharge to SG D Isolation Valve CA38A
Catawba Nuclear Station UFSAR Table 7-10 (Page 2 of 2)
(22 OCT 2001)
Auxiliary Feedwater Turbine Driven Pump Normal Suction Valve CA7A Nuclear Service Water Supply Valve CA116A Nuclear Service Water Supply Valve CA85B Auxiliary Feedwater Pump Turbine Start/Stop Auxiliary Feedwater Pumps Suction From Hotwell Isolation Valve CA2 Auxiliary Feedwater Pumps Suction From Upper Suirge Tank Isolation Valve CA4 Auxiliary Feedwater Pumps Suction From CA Condensate Storage Tank Isolation Valve CA6 Steam Generator 1A Power Operated Relief Valve SV19 Steam Generator 1B Power Operated Relief Valve SV13 Steam Generator 1C Power Opeated Relief Valve SV7 Steam Generator 1D Power Opeated Relief Valve SV1 Steam Generators Power Operated Relief Valves Transfer Switch (Unit 1 Only)
Train A Auxiliary Feedwater Pumps Discharge Valves Auto-Start Alignment Reset Switch
Catawba Nuclear Station UFSAR Table 7-11 (Page 1 of 8)
(17 APR 2012)
Table 7-11. Control Room Indicators and/or Recorders Available to the Operator to Monitor Significant Plant Parameters During Normal Operation Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes Nuclear Instrumentation
- 1. Source Range
- a. Count rate 2
10-1 to 106 counts/sec 10% of span (From CNC-1552.08 0359, Rev. 1)
Both channels indicated. Both channels are recorded.
Control board One recorder is used to record all 8 nuclear channels (2 source range, 2 intermediate range, and 4 power range)
- b. Startup rate 2
-0.5 to 5.0 decades/ min
+/-7% of the linear full scale analog voltage Both channels indicated Control Board
- 2. Intermediate Range
- a. Flux level 2
10 decades, 10-8 to 200% FP, of neutron flux (corresponds to 0 to full scale analog voltage) overlapping source range by 5 decades 8.4% of span (From CNC-1552.08 0360, Rev. 1)
Both channels indicated. Both channels are recorded using recorder in Item 1 above.
Control Board
- b. Startup rate 2
-0.5 to 5.0 decades/ min
+/-7% of the linear full scale analog voltage Both channels indicated Control Board
Catawba Nuclear Station UFSAR Table 7-11 (Page 2 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 3. Power Range
- a. Uncalibrated ion chamber current (top and bottom uncompensated ion chambers) 4 0-5 mA
+/-1% of full power current All 8 current signals indicated.
NIS racks in control room
- b. Calibrated ion chamber current (top and bottom uncompensated ion chambers) 4 0 to 120% of full power current
+/-2% full power current All 8 current signals recorded (four 2 pen recorders). Recorder 1 - upper currents for two diagonally opposed detectors.
Recorder 2 - upper currents for remaining detectors.
Recorder 3 - lower currents for two diagonally opposed detectors. Recorder -
4 lower currents for remaining detectors.
Control Board
- c. Upper and lower ion chamber current difference 4
-60 to +60%
+/-3% of full Diagonally opposed channels are recorded using recorder in Item 1.
Control board
Catawba Nuclear Station UFSAR Table 7-11 (Page 3 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- d. Average flux of the top and bottom ion chambers 4
0 to 120% of full power
+/-3% of full power for indication
+/-2% for recording All 4 channels indicated. All 4 channels are recorded using recorder in Item 1.
Control board
- e. Average flux of the top and bottom ion chambers 4
0 to 200% of full power
+/-2% of full power to 120%, +/-6%
of full power to 200%
All 4 channels recorded.
Control board
- f. Flux difference of the top and bottom ion chambers 4
-30 to +30%
+/-4%
All 4 channels indicated.
Control board Reactor Coolant System
- 1. Taverage (measured) 1/loop 530° - 630°F
+/-4°F All channels indicated.
Control board
- 2. T (measured) 1/loop 0 to 150% of full power T
+/-4% of full power T All channels indica-ted. One channel is selected for recording.
Control board
- a. Tcold or Thot (measured, wide range) 1-Thot, 1-Tcold per loop 0 to 700°
+/-4%
All Thot channels are recorded on 1 multipoint recorder.
All Tcold channels are recorded on another multipoint recorder.
Control board
Catawba Nuclear Station UFSAR Table 7-11 (Page 4 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 3. Overpower T Setpoint 1/loop 0 to 150% of full power T
+/-4% of full power T All channels indicated One channel selected for recording.
Control board
- 4. Overtemperature T Setpoint 1/loop 0 to 150% of full power T
+/-4% of full power T All channels indicated One channel is selected for recording.
Control board
- 5. Pressurizer Pressure 4
1700 to 2500 psig
+/-28 psi All channels indicated.
Control board
- 6. Pressurizer Level 3
Entire distance between taps
+/-3.5%P level at 2250 psia All channels indicated. Two channels recorded.
Control board
- 7. Primary Coolant Flow 3/loop 0 to 120% of rated flow Repeatability of +/-4.5% of full flow All channels indicated.
Control board
- 8. Reactor Coolant Pump Current 1/loop 0-800 Amps
+/-2%
All channels indicated.
Control board One channel for each pump
- 9. System Pressure Wide Range 2
0 to 3000 psig
+/-4.%
All channels indicated and recorded.
Control board Reactor Control System
- 1. Demanded Rod Speed 1
0 to 100% of rated speed
+/-2%
The one channel is indicated.
Control board
- 2. Selected Tavg 1
530° to 630°F
+/-4°F Value is displayed and can be trended on control room display.
Control board Any one of the Tavg channels into the auctioneer may be bypassed
Catawba Nuclear Station UFSAR Table 7-11 (Page 5 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 3. Selected Tref 1
530° to 630°F
+/-4°F Value is displayed and can be trended on control room display.
Control board
- 4. Control Rod Position If system not available, borate and sample accordingly
- a. Number of steps of demanded rod withdrawal 1/group 0 to 230 steps
+/-1 step Each group is indicated during rod motion.
Control board These signals are used in conjunction with the measured position signals (4b) to detect deviation of any individual rod from the demanded position. A deviation will actuate an alarm and annunciator.
- b. Full length rod measured position 1 for each rod 0 to 228 steps
+/-4 steps Each rod position is indicated.
Control board
Catawba Nuclear Station UFSAR Table 7-11 (Page 6 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 5. Control Rod Bank Demanded Position 4
0 to 230 steps
+/-2.5% of total bank travel Value is displayed and can be trended on control room display along with the low-low limit alarm for each bank.
Control board
- 1. One channel for each control bank.
- 2. An alarm and annunciator are 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-low insertion limit.
Containment System
- 1. Containment Pressure 4
-5 to 5 psig
+/-3%
All 4 channels indicated and 2 are recorded.
Control board Feedwater and Steam Systems
- 1. Auxiliary Feedwater Flow 1/feed 50 to 800 gpm
+/-2.5%
All channels indicated Control board One channel to measure the flow to each steam generator
- 2. Steam Generator Level (narrow range) 4/steam generator
+7 to -5 feet (unit 2),
+5 to -10 feet (unit 1) from nominal full load level
+/-4% of P level (hot)
All channels indicated. The channels used for control are recorded.
Control board.
Catawba Nuclear Station UFSAR Table 7-11 (Page 7 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 3. Steam Generator Level (wide range) 1/steam generator
+7 to -41 ft (unit 2),
+5 to -45 feet (unit 1) from nominal full load level
+5% of level (cold)
All channels recorded.
Control board.
- 4. Programmed Steam Generator Level Signal 1/steam generator
+7 to -5 feet (unit 2)
+5 to -10 feet (unit 1)
+/-4%
All channels recorded.
Control board
- 5. Main Feedwater Flow 2/steam generator 0 to 120% of maximum+/-5% mum calculated flow All Values are displayed and can be trended on control room display.
The selected channels used for control are recorded Control board
- 6. Magnitude of Signal Controlling Main and Bypass Feedwater Control Valves 1/main 1/bypass 0 to 100% of valve opening
+/-1.5%
All channels indicated Control board
- 1. One channel for each main and bypass feedwater control valve
- 2. OPEN/SHUT indi-cation is provided in the control room for each main and bypass feedwater control valve
Catawba Nuclear Station UFSAR Table 7-11 (Page 8 of 8)
(17 APR 2012)
Parameter No. of Channels Available Typical Range Indicated Accuracy(p)
Indicator/ Recorder Location Notes
- 7. Steam Flow 2/steam generator 0 to 120% of maximum calculated flow
+/-5.5%
All Values are displayed and can be trended on control room display. The selected channels used for control are recorded.
Control board Accuracy is equip-ment capability; however, absolute accuracy depends on calibration against feedwater flow.
- 8. Steam Line Pressure 3/loop 0 to 1300 psig
+/-4%
All channels indicated and 1 is recorded.
Control board
- 9. Steam Dump Modulate Signal 1
0-100% of steam dump valves open
+/-1.5%
The one channel is indicated.
Control board OPEN/SHUT indication is provided in the control room for each steam dump valve
- 10. Turbine Impulse Chamber Pressure 2
0 to 120 percent of maximum calculated turbine load
+/-3.5%
Additional channel available on control room display.
Control board OPEN/SHUT indication is provided in the control room for each turbine stop valve Note:
- 1. Includes channel accuracy and environmental effects
Catawba Nuclear Station UFSAR Table 7-12 (Page 1 of 1)
(17 APR 2012)
Table 7-12. Plant Control System Interlocks Designation Derivation Function C-1 1/2 Neutron flux (intermediate range) above setpoint Blocks automatic and manual control rod withdrawal C-2 1/4 Neutron flux (power range) above setpoint Blocks automatic and manual control rod withdrawal C-3 2/4 Overtemperature T above setpoint Blocks automatic and manual control rod withdrawal Actuates turbine runback via load reference C-4 2/4 Overpower T above setpoint Blocks automatic and manual control rod withdrawal Actuates turbine runback via load reference C-5 Selected Turbine impulse chamber pressure below setpoint Block automatic control rod withdrawal C-7 2/3 Time derivative (absolute value) of turbine impulse chamber pressure (decrease only) above setpoint Makes steam dump valves available for either tripping or modulation C-9 Any condenser pressure above setpoint, or All circulation water pump breakers open Blocks steam dump to condenser C-11 1/1 Bank D control rod position above setpoint Blocks automatic rod withdrawal C-16 Reduced limit in coolant temperature above normal setpoint.
Stops automatic turbine loading until condition clears.
Catawba Nuclear Station UFSAR Table 7-13 (Page 1 of 1)
(22 OCT 2001)
Table 7-13. Deleted Per 1990 Update
Catawba Nuclear Station UFSAR Table 7-14 (Page 1 of 1)
(22 OCT 2001)
Table 7-14. ESF Bypass Indication Bypass indication is provided for each train of the following safety-related functions:
Annulus ventilation Auxiliary building ventilation Auxiliary feedwater (motor driven)
Auxiliary feedwater (turbine driven)
Chemical and volume control system (charging/injection)
Component cooling Containment air return and hydrogen skimmer Containment isolation Containment penetration valve injection water Containment pressure control Containment spray Control room ventilation and chilled water Diesel building ventilation Diesel generator Diesel generator room sump drainage Groundwater drainage Nuclear service water Nuclear service water pump structure ventilation Reactor trip Residual heat removal (injection)
Residual heat removal (spray)
Safety injection Safety injection (accumulator)
Spent fuel pool cooling
Catawba Nuclear Station UFSAR Table 7-15 (Page 1 of 4)
(17 APR 2012)
Table 7-15. ESF Response Times Initiation Signal and Function Maximum
Response
Time (sec)
- 1. Manual Initiation
- a. Safety Injection (ECCS)
N.A.
- b. Containment Spray N.A.
- c. Phase A Isolation N.A.
- d. Phase B Isolation N.A.
- e. Containment Air Release and Addition N.A.
- f. Steam Line Isolation N.A.
- g. Diesel Building Ventilation Operation N.A.
- h. Nuclear Service Water Operation N.A.
- i.
Turbine Trip N.A.
- j.
Component Cooling Water N.A.
- k. Annulus Ventilation Operation N.A.
- l.
Auxiliary Building Filtered Exhaust Operation N.A.
- m. Reactor Trip N.A.
- n. Emergency Diesel Generator Operation N.A.
- o. Containment Air Return and Hydrogen Skimmer Operation N.A.
- p. Auxiliary Feedwater N.A.
- 2. Containment Pressure-High
- a. Safety Injection (ECCS) 27(1)/12(3)
- 1) Reactor Trip 2
- 2) Feedwater Isolation 12
- 3) Phase A Isolation2,8 18(3)/28(4)
- 4) Deleted
- 5) Auxiliary Feedwater5 N.A.
- 6) Nuclear Service Water Operation 65(3)/76(4)
- 7) Turbine Trip N.A.
- 8) Component Cooling Water 65(3)/76(4)
- 9) Emergency Diesel Generator Operation 11
- 10) Control Room Area Ventilation Operation N.A.
Catawba Nuclear Station UFSAR Table 7-15 (Page 2 of 4)
(17 APR 2012)
Initiation Signal and Function Maximum
Response
Time (sec)
- 11) Annulus Ventilation Opeation 23
- 12) Auxiliary Building Filtered Exhaust Operation N.A.
- 13) Containment Sump Recirculation N.A.
- 3. Pressurizer Pressure-Low
- a. Safety Injection (ECCS) 27(1)/12(3)
- 1) Reactor Trip 2
- 2) Feedwater Isolation 12
- 3) Phase A Isolation2,8 18(3)/28(4)
- 4) Deleted
- 5) Auxiliary Feedwater5 N.A.
- 6) Nuclear Service Water Operation 65(3)/76(4)
- 7) Turbine Trip N.A.
- 8) Component Cooling Water 65(3)/76(4)
- 9) Emergency Diesel Generator Operation 11
- 10) Control Room Area Ventilation Operation N.A.
- 11) Annulus Ventilation Operation 23
- 12) Auxiliary Building Filtered Exhaust Operation N.A.
- 13) Containment Sump Recirculation N.A.
- 4. Steam Line Pressure-Low Steam Line Isolation 10
- 5. Containment Pressure-High-High Deleted Per 2012 Update.
- a. Phase B Isolation 65(3)/76(4)
Nuclear Service Water Operation N.A.
- b. Steam Line Isolation 10
- c. Containment Air Return and Hydrogen Skimmer Fan Operation 600(9)
- 6. Steam Line Pressure - Negative Rate-High Steam Line Isolation 10
- 7. Steam Generator Water Level-High-High
- a. Turbine Trip 3
Catawba Nuclear Station UFSAR Table 7-15 (Page 3 of 4)
(17 APR 2012)
Initiation Signal and Function Maximum
Response
Time (sec)
- b. Feedwater Isolation 12
- 8. Tavg-Low Feedwater Isolation N.A.
- 9. Doghouse Water Level-High High Feedwater Isolation N.A.
- 10. Start Permissive Containment Pressure Control System N.A.
- 11. Termination Containment Pressure Control System N.A.
- 12. Steam Generator Water Level-Low-Low
- a. Motor-Driven Auxiliary Feedwater Pumps 60
- b. Turbine-Driven Auxiliary Feedwater Pump 60
- 13. Loss-of-Offsite Power
- a. Motor-Driven Auxiliary Feedwater Pumps 60
- b. Turbine-Driven Auxiliary Feedwater Pump 60
- c. Control Room Area Ventilitation N.A.
- d. Emergency Diesel Generator Operation 11
- 1) Diesel Building Ventilation Operation N.A.
- 2) Nuclear Service Water Operation 65(3)/76(4)
- 14. Trip of All Main Feedwater Pumps
- a. Motor-Driven Auxiliary Feedwater Pumps 60
- b. Turbine Trip N.A.
- 15. Auxiliary Feedwater Suction Pressure-Low (Suction Supply Automatic Realignment) 21(6)
- 16. Refueling Water Storage Tank Level-Low Coincident with Safety Injection Signal (Automatic Switchover to Containment Sump) 60
- 17. Loss of Power
- a. 4 kV Bus Undervoltage Loss of Voltage 8.5
- b. 4 kV Bus Undervoltage-Grid Degraded Voltage 600
Catawba Nuclear Station UFSAR Table 7-15 (Page 4 of 4)
(17 APR 2012)
Initiation Signal and Function Maximum
Response
Time (sec)
- 18. Suction Transfer-Low Pit Level Nuclear Service Water Operation N.A.
Notes:
- 1. Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish Safety Injection path and attainment of discharge pressure for centrifugal charging pumps, Safety Injection and residual heat removal pumps.
- 2. Valves KC305B and KC315B are exceptions to the response times listed in the table. The following response times in seconds are the required values for these valves for the initiating signal and function indicated:
2.a.3 30(3)/40(4) 3.a.3 30(3)
- 3. Diesel generator starting and sequence loading delays not included. Off-site power available.
Response time limit includes opening of valves to establish Safety Injection path and attainment of discharge pressure for centrifugal charging pumps.
- 4. Diesel generator starting and sequence loading delays included. Response time limit includes opening of valves to establish Safety Injection path and attainment of discharge pressure for centrifugal charging pumps.
- 5. Response time for motor-driven auxiliary feedwater pumps on all Safety Injection signals shall be less than or equal to 60 seconds. Response time limit includes attainment of discharge pressure for auxiliary feedwater pumps.
- 6. Response time includes a time delay of up to 6 seconds.
- 7. The VQ System valves are designed to close on a Phase "A" Isolation Signal with corresponding 18/28 second response times.
- 8. Valves NW20A and NW69B are exceptions to the response times listed in the table. The following response times in seconds are the required values for these valves for the initiating signal and function indicated (PIP C99-0821).
2.a.3 65(3)/76(4) 3.a.3 65(3)/76(4)
- 9. The Containment Air Return Fan (CARF) reaches its functional state within 600 seconds. The 600 seconds response time represents the maximum time that the Hydrogen Skimmer System (HSS) suction valves start opening and the Hydrogen Skimmer Fan (HSF) starts operating.
Catawba Nuclear Station UFSAR Table 7-16 (Page 1 of 3)
(27 MAR 2003)
Table 7-16. Main Control Board Indicators and/or Recorders Available to the Operator (Condition II, III, and IV Events)
Function Design Requirement Range Purpose Accuracy
- 1. Wide Range T hot and T cold Two T hot and two T cold indicator channels. The T hot channels are on a separate power supply from the T cold channels. Capability of recording both T hot and T cold in each loop is provided.
0 to 700°F
- 1. Main the plant in a safe shutdown conditon.
- 2. Ensure proper cooldown rate
- 3. Ensure proper relationship between system pressure and temperature
+/- 8% of full range
+/- 8% of full range
+/- 8% of full range
- 2. Pressurizer Water Level Two channels on separate power supplies with one channel recorded.
Entire distance between taps
- 1. Maintain proper reactor coolant inventory
- 2. Determine return of water level to pressurizer following steam break and steam generator tube ruptures.
Sufficient accuracy to indicate water level is above pressurizer heaters and below 100% of span (Approximately +/- 25% of span)
Same as above
- 3. System Wide Range Pressure Two channels on separate power supplies with one channel recorded.
0 to 3000 psi Ensure proper relationship between system pressure and temperature
+/- 8% of full range
- 4. Containment Pressure Two channels on separate power supplies with both channels recorded.
-5 psig to +
60 psig Monitor containment conditions following primary or secondary system break inside containment
+/- 4% of full scale
- 5. Steamline Pressure Two channels per steamline on separate power supplies with one channel per steamline recorded.
0 to 1300 psig
- 1. Needed to determine type of accident that has occurred and the proper recovery procedure to use.
- 2. Determine that plant is in a safe shutdown condition
+/- 4% of full scale
+/- 4% of full scale
Catawba Nuclear Station UFSAR Table 7-16 (Page 2 of 3)
(27 MAR 2003)
Function Design Requirement Range Purpose Accuracy
- 6. Steam Generator Water Level Two narrow range channels per Steam Generator on separate power supplies. One wide range channel per Steam Generator, which may share a power supply with one of the narrow range channels. Each wide range channel is recorded.
0 to 100%
of span
- 1. Maintain adequate heat sink following an accident
- 2. Needed in recovery procedure following Steam Generator tube rupture
- 3. Ensure that Steam Generator Tubes are covered following a LOCA Sufficient accuracy to indicate water level is between 0 and 100% of span
- 7. Refueling Water Storage Tank Level Two channels on separate power supplies with one channel recorded.
0 to 100%
of span Determine when to perform the necessary manual actions following switchover from the injection phase to the recirculation phase of safety injection after a LOCA
+/- 3% of level span
- 8. Boric Acid Tank Level Two channels on separate power supplies with one channel recorded.
0 to 100%
level To ensure that borated water is leaving the boric acid tanks
+/- 5%
- 9. Containment Radiation Level Two channels on separate power supplies with one channel recorded. Detectors are located on the primary shield wall approximately 180° apart 10E0 to 10E8 R/hr Monitor containment conditions following an accident
+/- 1/2 decade
- 10. Containment Hydrogen Concentration Two channels on separate power supplies with one channel recorded.
0 to 30%
Hydrogen by Volume Monitor containment conditions following an accident (later)
Catawba Nuclear Station UFSAR Table 7-16 (Page 3 of 3)
(27 MAR 2003)
Function Design Requirement Range Purpose Accuracy
- 11. Containment Sump Level Two channels on separate power supplies with both channels recorded.
0 to 20 feet
- 1. Monitor containment conditions following a primary or secondary system break
- 2. Determine when to perform the necessary manual actions following switchover from the injection phase to the recirculation phase of safety injection following a LOCA
+/- 10%