ML20106E919

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1 to Updated Final Safety Analysis Report, Chapter 7, Appendix 7A, Tables
ML20106E919
Person / Time
Site: Catawba  Duke Energy icon.png
Issue date: 04/02/2020
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Duke Energy Carolinas
To:
Office of Nuclear Reactor Regulation
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ML20106E897 List:
References
RA-19-0423
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Catawba Nuclear Station UFSAR Appendix 7A. Tables Appendix 7A. Tables

Catawba Nuclear Station UFSAR Table 7-1 (Page 1 of 2)

Table 7-1. List of Reactor Trips Coincidence Reactor Trip Logic Interlocks Comments

1. High neutron flux (Power Range) 2/4 Manual block of low setting High and low setting; manual block permitted by P-10 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, Manual block and automatic reset.

interlocked with P-10 Automatic block above P-10

4. Power range high positive neutron 2/4 No interlocks flux rate
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 2/4 Interlocked with P-7 Low voltage to RCP motors undervoltage permitted below P-7.
12. Reactor coolant pump 2/4 Interlocked with P-7 Underfrequency on 2 motors will trip underfrequency all reactor coolant pump breakers and cause reactor trip; reactor trip blocked below P-7 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-1 (Page 2 of 2)

Coincidence Reactor Trip Logic Interlocks Comments

13. Low-low steam generator water 2/4 in any loop No interlocks level
14. Safety injection signal Coincident with No interlocks (See Section 7.3 for Engineered actuation of safety Safety Features actuation conditions) injection
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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-2 (Page 1 of 1)

Table 7-2. Protection System Interlocks Designation Derivation Function I POWER ESCALATION PERMISSIVES P-6 Presence of P-6: 1/2 neutron flux Allows manual block of source range reactor (intermediate range) above setpoint trip Absence of P-6: 2/2 neutron flux Defeats the block of source range reactor trip (intermediate range) below setpoint P-10 Presence of P-10: 2/4 neutron flux Allows manual block of power range (low (power range) above setpoint 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 Defeats the block of power range (low (power range) below setpoint 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 Blocks reactor trip on: Low reactor coolant (power range) below setpoint (from P- flow in more than one loop, RCP

10) undervoltage, RCP underfrequency, pressurizer low pressure, and pressurizer high level P-8 Absence of P-8: 3/4 neutron flux Blocks reactor trip on low reactor coolant (power range) below setpoint flow in a single loop P-9 Absence of P-9: 3/4 neutron flux Blocks reactor trip on turbine trip (power range) below setpoint P-13 2/2 turbine impulse chamber pressure Input to P-7 below setpoint (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-3 (Page 1 of 3)

Table 7-3. Reactor Trip System Instrumentation Maximum Time Reactor Trip Signal Typical Range Typical Trip Accuracy 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 10 decades of neutron flux 8% of span (From CNC- N.A.

flux overlapping source range by 5 1552.08-00-0360, Rev. 1) decades

3. Source range high neutron flux 7 decades of neutron flux (0.1 to 9.5% of span (From CNC- N.A.

106 counts/sec) 1552.08-00-0359, Rev. 1)

4. Power range high positive Neutron flux (0-120% full +/-5 percent 1 N.A.

neutron flux rate power)

5. Overtemperature T: TH 530 to 650°F +/-7.9°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%)
a. Narrow Range RTD a. 8.0 seconds time constants (Unit 1) 8.0 seconds
b. Thot and Tcold input to (Unit 2)

T

b. 1.5 seconds
c. Tavg input to setpoint
c. 1.5 seconds
d. Pressurizer pressure input to setpoint d. 1.5 seconds
e. Flux imbalance input to e. 1.5 seconds3 setpoint (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-3 (Page 2 of 3)

Maximum Time Reactor Trip Signal Typical Range Typical Trip Accuracy Response (sec)

6. Overpower T TH530 to 650°F +/-4.4°F TC 510 to 630°F TAV 530 to 630°F T Setpoint 0 to 100°F (0-150%)
a. Narrow Range RTD a. 8.0 seconds time constants (Unit 1)
b. Thot and Tcold input to 8.0 seconds T (Unit 2)
c. Tavg input to setpoint b. 1.5 seconds
d. Flux imbalance input to
c. 1.5 seconds setpoint
d. 1.5 seconds3
7. Pressurizer low pressure 1700 to 2500 psig +/-18 psi (Compensated 2.0 signal)
8. Pressurizer high pressure 1700 to 2500 psig +/-18 psi (non-compensate 2.0 signal)
9. Pressurizer high water level Entire cylindrical portion of +/-2.3 percent of full range N.A.

pressurizer (distance between between taps at design taps) temperature and pressure.

10. Low reactor coolant flow 0 to 120% of rated flow +/-2.5 percent of full flow 1.0 within range of 70 percent to 100 percent of full flow 1
11. Reactor Coolant pump 0 to 100% rated voltage +/-1% 1.5 undervoltage
12. Reactor coolant pump 50 to 65 Hz +/-0.1 Hz 0.6 underfrequency (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-3 (Page 3 of 3)

Maximum Time Reactor Trip Signal Typical Range Typical Trip Accuracy Response (sec)

13. Low-low steam generator water +/-~ 6 ft. (unit 2), +/-~ 8 ft. (unit 1) +/-2.3 percent of signal 2.0 level from nominal full load water over pressure range of 700 level to 1200 psig
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.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-4 (Page 1 of 4)

Table 7-4. Reactor Trip Correlation Tech Spec.3/

Trip 1 Accident 2 UFSAR3

1. Power Range 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

High Neutron Bank Withdrawal From a Subcritical 3.3.1 / Table 7-3 Flux Trip Condition or Low Power Startup Condition 3.3.2 / Table 7-15 (Low Setpoint) (15.4.1)

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 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

High Neutron Bank Withdrawal From a Subcritical or 3.3.1 / Table 7-3 Flux Trip Low Power Startup Condition (15.4.1) 3.3.2 / Table 7-15 (High Setpoint)

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 1. Uncontrolled Rod Cluster Control Assembly See Note 4 Range High Bank Withdrawal From a Subcritical or Table 3.3.1-1/-

Neutron Flux Low Power Startup Condition (15.4.1) 3.3.1 / Table 7-3 Trip 3.3.2 / Table 7-15 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-4 (Page 2 of 4)

Tech Spec.3/

Trip1 Accident2 UFSAR3

4. Source Range 1. Uncontrolled Rod Cluster Control Assembly See Note 4 High Neutron Bank Withdrawal From a Subcritical or Table 3.3.1-1/-

Flux Trip Low Power Startup Condition (15.4.1) 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 1. Spectrum of Rod Cluster Control Assembly Table 3.3.1-1/-

High Positive Ejection Accidents (15.4.8) See Note 4 Neutron Flux 3.3.1 / Table 7-3 Rate Trip 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 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

T Trip Bank Withdrawal at Power (15.4.2) 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)

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-4 (Page 3 of 4)

Tech Spec.3/

Trip1 Accident2 UFSAR3

7. Overpower T Trip 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

Bank Withdrawal at Power (15.4.2) 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 1. Inadvertent Opening Of A Pressurizer Table 3.3.1-1/-

Low Pressure Safety Or Relief Valve (15.6.1) 3.3.1 / Table 7-3 Trip 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 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

High Pressure Bank Withdrawal at Power (15.4.2) 3.3.1 / Table 7-3 Trip 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 1. Uncontrolled Rod Cluster Control Assembly Table 3.3.1-1/-

High Water Bank Withdrawal at Power (15.4.2) See Note 4 Level Trip 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 1. Partial Loss of Forced Reactor Coolant Table 3.3.1-1/-

Coolant Flow Flow (15.3.1) 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)

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-4 (Page 4 of 4)

Tech Spec.3/

Trip1 Accident2 UFSAR3

12. Reactor Coolant 1. Complete Loss of Forced Reactor Coolant Table 3.3.1-1/-

Pump Under- Flow (15.2.1) 3.3.1 / Table 7-3 voltage Trip 3.3.2 / Table 7-15

2. Partial Loss Of Forced Reactor Coolant Flow (15.3.1)
13. Reactor Coolant 1. Complete Loss of Forced Reactor Coolant Table 3.3.1-1/-

Pump Under- Flow (15.3.2) 3.3.1 / Table 7-3 frequency Trip 3.3.2 / Table 7-15

14. Low-low Steam 1. Loss of Normal Feedwater Flow (15.2.7) Table 3.3.1-1/-

Generator Water 3.3.1 / Table 7-3 Level Trip 3.3.2 / Table 7-15

2. Turbine Trip (15.2.3)
3. Feedwater System Pipe Break (15.2.8)
15. Safety Injection 1. Inadvertent Opening Of A Steam Generator See Note 5 Signal Actuation Relief Or Safety Valve (15.1.4) 3.3.1 / Table 7-3 Trip 3.3.2 / Table 7-15
2. Steam System Piping Failure (15.1.5)
3. Feedwater System Pipe Break (15.2.8)
16. Reactor Trip on 1. Loss of External Load and/or Turbine Trip See Note 4 Turbine Trip (15.2.2/ 15.2.3) 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 See Note 4 Station Auxiliaries (15.2.6) 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.

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-5 (Page 1 of 1)

Table 7-5. Instrumentation Operating Condition for Engineered Safety Features No. of Channels to No. Functional Unit No. of Channels Trip

1. Safety Injection
a. Manual 2 1
b. High Containment Pressure 3 2
c. Pressurizer Low Pressure 4 2
2. Containment Spray
a. Manual 2 1 Deleted Per 2012 Update. 4 2 (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-6 (Page 1 of 1)

Table 7-6. Instrument Operating Conditions for Isolation Functions No. Of Channels No. Functional Unit No. Of Channels To Trip

1. Containment Isolation
a. Automatic Safety See item No. 1 (b) and (c) of Injection (Phase A) Table 7-5
b. Containment Pressure 4 2 (Phase B)
c. Manual Phase A 1 2

Phase B 2 1

2. Steam Line Isolation
a. High Steam Negative 12 (3/steam line) 2/steam line in any Pressure Rate steam line.
b. Containment Pressure 4 2 (High-High)
c. Low steam line 12 (3/steam line) 2/steam line pressure
d. Manual 1/loop1 1/loop1
3. Feedwater Line Isolation
a. Safety Injection See Item No. 1 of Table 7-5
b. Steam Generator 4/loop 2/loop High-High level 2/4 on any Steam Generator
c. Low Tavg See P4 on Table 7-7 interlocked with P4 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.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-7 (Page 1 of 2)

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 (a) Allows manual block of safety injection below setpoint 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 (a) Reinstates automatically steamline above setpoint 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.

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-7 (Page 2 of 2)

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 (a) Closes all feedwater control valves water level above (b) Trips all main feedwater pumps which setpoint on any steam closes the pump discharge valves generator (c) Actuates turbine trip (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-8 (Page 1 of 2)

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:

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-8 (Page 2 of 2)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-9 (Page 1 of 3)

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:

(22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-9 (Page 2 of 3)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-9 (Page 3 of 3)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-10 (Page 1 of 2)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-10 (Page 2 of 2)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-11 (Page 1 of 8)

Table 7-11. Control Room Indicators and/or Recorders Available to the Operator to Monitor Significant Plant Parameters During Normal Operation No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes Nuclear Instrumentation

1. Source Range
a. Count rate 2 10-1 to 106 10% of span Both channels Control One recorder is used counts/sec (From CNC- indicated. Both board to record all 8 1552.08 channels are nuclear channels (2 0359, Rev. 1) recorded. source range, 2 intermediate range, and 4 power range)
b. Startup rate 2 -0.5 to 5.0 +/-7% of the Both channels Control decades/ min linear full indicated Board scale analog voltage
2. Intermediate Range
a. Flux level 2 10 decades, 10-8 to 8.4% of span Both channels Control 200% FP, of (From CNC- indicated. Both Board neutron flux 1552.08 channels are recorded (corresponds to 0 0360, Rev. 1) using recorder in to full scale analog Item 1 above.

voltage) overlapping source range by 5 decades

b. Startup rate 2 -0.5 to 5.0 +/-7% of the Both channels Control decades/ min linear full indicated Board scale analog voltage (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 2 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

3. Power Range
a. Uncalibrated 4 0-5 mA +/-1% of full All 8 current signals NIS racks ion power indicated. in control chamber current room current (top and bottom uncompensated ion chambers)
b. Calibrated ion 4 0 to 120% of full +/-2% full All 8 current signals Control chamber power current power recorded (four 2 pen Board current current recorders). Recorder (top and bottom 1 - upper currents for uncompensated two diagonally ion chambers) 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.

c. Upper and 4 -60 to +60% +/-3% of full Diagonally opposed Control lower channels are recorded board ion chamber using recorder in current Item 1.

difference (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 3 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

d. Average flux of 4 0 to 120% of full +/-3% of full All 4 channels Control the top and power power for indicated. All 4 board bottom ion indication channels are recorded chambers +/-2% for using recorder in recording Item 1.
e. Average flux of 4 0 to 200% of full +/-2% of full All 4 channels Control the top and power power to recorded. board bottom ion 120%, +/-6%

chambers of full power to 200%

f. Flux difference 4 -30 to +30% +/-4% All 4 channels Control of the top and indicated. board bottom ion chambers Reactor Coolant System
1. Taverage 1/loop 530° - 630°F +/-4°F All channels Control (measured) indicated. board
2. T (measured) 1/loop 0 to 150% of full +/-4% of full All channels indica- Control power T power T ted. One channel is board selected for recording.
a. Tcold or Thot 1-Thot, 1-Tcold per 0 to 700° +/-4% All Thot channels are Control (measured, loop recorded on 1 board wide range) multipoint recorder.

All Tcold channels are recorded on another multipoint recorder.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 4 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

3. Overpower T 1/loop 0 to 150% of full +/-4% of full All channels Control Setpoint power T power T indicated One board channel selected for recording.
4. Overtemperature T 1/loop 0 to 150% of full +/-4% of full All channels Control Setpoint power T power T indicated One board channel is selected for recording.
5. Pressurizer 4 1700 to 2500 psig +/-28 psi All channels Control Pressure indicated. board
6. Pressurizer 3 Entire distance +/-3.5%P All channels Control Level between taps level at 2250 indicated. Two board psia channels recorded.
7. Primary Coolant 3/loop 0 to 120% of rated Repeatability All channels Control Flow flow of +/-4.5% of indicated. board full flow
8. Reactor Coolant 1/loop 0-800 Amps +/-2% All channels Control One channel for each Pump Current indicated. board pump
9. System Pressure 2 0 to 3000 psig +/-4.% All channels Control Wide Range indicated and board recorded.

Reactor Control System

1. Demanded Rod 1 0 to 100% of rated +/-2% The one channel is Control Speed speed indicated. board
2. Selected Tavg 1 530° to 630°F +/-4°F Value is displayed Control Any one of the Tavg and can be trended on board channels into the control room display. auctioneer may be bypassed (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 5 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

3. Selected Tref 1 530° to 630°F +/-4°F Value is displayed Control and can be trended on board control room display.
4. Control Rod If system not available, Position borate and sample accordingly
a. Number of 1/group 0 to 230 steps +/-1 step Each group is Control These signals are used steps of indicated during rod board in conjunction with the demanded rod motion. measured position withdrawal 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 1 for each rod 0 to 228 steps +/-4 steps Each rod position is Control measured indicated. board position (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 6 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

5. Control Rod Bank 4 0 to 230 steps +/-2.5% of Value is displayed Control 1. One channel for Demanded Position total bank and can be trended on board each control bank.

travel control room display

2. An alarm and along with the low-annunciator are low limit alarm for actuated when the each bank.

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 4 -5 to 5 psig +/-3% All 4 channels Control Pressure indicated and 2 are board recorded.

Feedwater and Steam Systems

1. Auxiliary 1/feed 50 to 800 gpm +/-2.5% All channels Control One channel to Feedwater indicated board measure the flow to Flow each steam generator
2. Steam Generator 4/steam generator +7 to -5 feet (unit 2), +/-4% of P All channels Control Level (narrow +5 to -10 feet (unit 1) level (hot) indicated. The board.

range) from nominal full channels used for load level control are recorded.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 7 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

3. Steam Generator 1/steam generator +7 to -41 ft (unit 2), +5% of All channels Control Level (wide range) +5 to -45 feet (unit 1) level recorded. board.

from nominal full (cold) load level

4. Programmed Steam 1/steam generator +7 to -5 feet (unit 2) +/-4% All channels Control Generator Level +5 to -10 feet (unit 1) recorded. board Signal
5. Main Feedwater 2/steam generator 0 to 120% of All Values Control board Flow maximum+/-5% mum are calculated flow displayed and can be trended on control room display.

The selected channels used for control are recorded

6. Magnitude of 1/main 1/bypass 0 to 100% of valve +/-1.5% All channels Control 1. One channel for Signal Controlling opening indicated board each main and bypass Main and Bypass feedwater control Feedwater Control valve Valves
2. OPEN/SHUT indi-cation is provided in the control room for each main and bypass feedwater control valve (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-11 (Page 8 of 8)

No. of Channels Indicated Parameter Available Typical Range Accuracy(p) Indicator/ Recorder Location Notes

7. Steam Flow 2/steam generator 0 to 120% of +/-5.5% All Values are Control Accuracy is equip-maximum calculated displayed and can be board ment capability; flow trended on control however, absolute room display. The accuracy depends on selected channels calibration against used for control are feedwater flow.

recorded.

8. Steam Line 3/loop 0 to 1300 psig +/-4% All channels Control Pressure indicated and 1 is board recorded.
9. Steam Dump 1 0-100% of steam +/-1.5% The one channel is Control OPEN/SHUT Modulate Signal dump valves open indicated. board indication is provided in the control room for each steam dump valve
10. Turbine Impulse 2 0 to 120 percent of +/-3.5% Additional channel Control OPEN/SHUT Chamber Pressure maximum calculated available on control board indication is provided turbine load room display. in the control room for each turbine stop valve Note:
1. Includes channel accuracy and environmental effects (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-12 (Page 1 of 1)

Table 7-12. Plant Control System Interlocks Designation Derivation Function C-1 1/2 Neutron flux (intermediate range) Blocks automatic and manual control rod above setpoint withdrawal C-2 1/4 Neutron flux (power range) above Blocks automatic and manual control rod setpoint 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 Makes steam dump valves available for turbine impulse chamber pressure either tripping or modulation (decrease only) above setpoint C-9 Any condenser pressure above setpoint, or Blocks steam dump to condenser All circulation water pump breakers open C-11 1/1 Bank D control rod position above Blocks automatic rod withdrawal setpoint C-16 Reduced limit in coolant temperature Stops automatic turbine loading until above normal setpoint. condition clears.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-13 (Page 1 of 1)

Table 7-13. Deleted Per 1990 Update (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-14 (Page 1 of 1)

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 (22 OCT 2001)

Catawba Nuclear Station UFSAR Table 7-15 (Page 1 of 4)

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.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-15 (Page 2 of 4)

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 (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-15 (Page 3 of 4)

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 8.5 Loss of Voltage
b. 4 kV Bus Undervoltage- 600 Grid Degraded Voltage (17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-15 (Page 4 of 4)

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.

(17 APR 2012)

Catawba Nuclear Station UFSAR Table 7-16 (Page 1 of 3)

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 Two T hot and two T cold 0 to 700°F 1. Main the plant in a safe shutdown +/- 8% of full range hot and T cold indicator channels. The T hot conditon.

channels are on a separate

2. Ensure proper cooldown rate +/- 8% of full range power supply from the T cold channels. Capability of 3. Ensure proper relationship between +/- 8% of full range recording both T hot and T cold system pressure and temperature in each loop is provided.
2. Pressurizer Two channels on separate Entire 1. Maintain proper reactor coolant Sufficient accuracy to Water Level power supplies with one distance inventory indicate water level is channel recorded. between above pressurizer heaters taps and below 100% of span (Approximately +/- 25% of span)
2. Determine return of water level to Same as above pressurizer following steam break and steam generator tube ruptures.
3. System Wide Two channels on separate 0 to 3000 Ensure proper relationship between +/- 8% of full range Range Pressure power supplies with one psi system pressure and temperature channel recorded.
4. Containment Two channels on separate -5 psig to + Monitor containment conditions +/- 4% of full scale Pressure power supplies with both 60 psig following primary or secondary system channels recorded. break inside containment
5. Steamline Two channels per steamline on 0 to 1300 1. Needed to determine type of +/- 4% of full scale Pressure separate power supplies with psig accident that has occurred and the one channel per steamline proper recovery procedure to use.

recorded.

2. Determine that plant is in a safe +/- 4% of full scale shutdown condition (27 MAR 2003)

Catawba Nuclear Station UFSAR Table 7-16 (Page 2 of 3)

Function Design Requirement Range Purpose Accuracy

6. Steam Two narrow range channels 0 to 100% 1. Maintain adequate heat sink Sufficient accuracy to Generator per Steam Generator on of span following an accident indicate water level is Water Level separate power supplies. One between 0 and 100% of
2. Needed in recovery procedure wide range channel per Steam span following Steam Generator tube Generator, which may share a rupture power supply with one of the narrow range channels. Each 3. Ensure that Steam Generator Tubes wide range channel is are covered following a LOCA recorded.
7. Refueling Two channels on separate 0 to 100% Determine when to perform the +/- 3% of level span Water Storage power supplies with one of span necessary manual actions following Tank Level channel recorded. switchover from the injection phase to the recirculation phase of safety injection after a LOCA
8. Boric Acid Two channels on separate 0 to 100% To ensure that borated water is leaving +/- 5%

Tank Level power supplies with one level the boric acid tanks channel recorded.

9. Containment Two channels on separate 10E0 to Monitor containment conditions +/- 1/2 decade Radiation Level power supplies with one 10E8 R/hr following an accident channel recorded. Detectors are located on the primary shield wall approximately 180° apart
10. Containment Two channels on separate 0 to 30% Monitor containment conditions (later)

Hydrogen power supplies with one Hydrogen following an accident Concentration channel recorded. by Volume (27 MAR 2003)

Catawba Nuclear Station UFSAR Table 7-16 (Page 3 of 3)

Function Design Requirement Range Purpose Accuracy

11. Containment Two channels on separate 0 to 20 feet 1. Monitor containment conditions +/- 10%

Sump Level power supplies with both following a primary or secondary channels recorded. 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 (27 MAR 2003)
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