ML20309A730
Text
McGuire Nuclear Station UFSAR Appendix 7A. Tables Appendix 7A. Tables
McGuire Nuclear Station UFSAR Table 7-1 (Page 1 of 2)
(14 OCT 2000)
Table 7-1. List of Reactor Trips Reactor Trip Coincident Logic Interlocks Comments High neutron flux (Power Range) 2/4 Manual block of low setting permitted by P-10 High and low settings; manual block and automatic reset of low setting by P-10 Intermediate range neutron flux 1/2 Manual block permitted by P-10 Manual block and automatic reset 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 Power range high positive neutron flux rate 2/4 No interlocks Overtemperature T 2/4 No interlocks Overpower T 2/4 No interlocks Pressurizer low pressure 2/4 Interlocked with P-7 Blocked below P-7 Pressurizer high pressure 2/4 No interlocks Pressurizer high water level 2/3 Interlocked with P-7 Blocked below P-7 Low reactor coolant flow 2/3 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 Reactor coolant pump under voltage 2/4 Interlocked with P-7 Low voltage to RCP motors permitted below P-7; Reactor trip blocked below P-7.
Reactor coolant pump bus under-frequency 2/4 Interlocked with P-7 Under frequency on 2 buses will trip all reactor coolant pump breakers and cause reactor trip; reactor trip blocked below P-7 Low-Low steam generator water level 2/4 in any loop No interlocks
McGuire Nuclear Station UFSAR Table 7-1 (Page 2 of 2)
(14 OCT 2000)
Reactor Trip Coincident Logic Interlocks Comments Safety injection signal Coincident with actuation of safety injection No interlocks (See Section 7.3 for Engineered Safety Features actuation conditions)
Manual 1/2 No interlocks Turbine-Generator Trip
- 1. Low Auto Stop Oil Pressure 2/3 Interlocked with P-8 Blocked below P-8
- 2. Turbine Stop Valve Closed 4/4 Interlocked with P-8 Blocked below P-8
McGuire Nuclear Station UFSAR Table 7-2 (Page 1 of 1)
(09 OCT 2015)
Table 7-2. Protection System Interlocks Designation Derivation Function I
POWER ESCALATION PERMISSIVES P-6 1/2 Neutron flux (intermediate-range) above setpoint Allows manual block of source range reactor trip 2/2 Neutron flux (intermediate-range) below setpoint Defeats the block of source range reactor trip 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 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 3/4 Neutron flux (power-range) below setpoint (from P-10) and 2/2 Turbine inlet pressure below setpoint (from P-13)
Signal blocks reactor trip on:
Low flow in more than one loop, under voltage, underfrequency, pressurizer low pressure, and pressurizer high level P-8 2/4 Neutron flux (power-range) above setpoint Signal unblocks reactor trip on low reactor coolant flow or turbine trip P-13 2/2 Turbine inlet pressure below setpoint Input to P-7
McGuire Nuclear Station UFSAR Table 7-3 (Page 1 of 1)
(09 OCT 2015)
Table 7-3. Reactor Protection System Instrument Accuracies Reactor Trip Signal System Accuracy See Note Power-range high neutron flux
+/-1 percent of full power Intermediate-range high neutron flux
+/-1.5 percent of full scale (a)
Deleted per 2015 update Source-range high neutron flux
+/- 2 percent of full scale (a)
Power-range high positive neutron flux rate
+/-5 percent (a)
Overtemperature T
+/-3.2°F Overpower T
+/-2.7°F Pressurizer low pressure
+/-18 psi Pressurizer high pressure
+/-14 psi Pressurizer high water level
+/-2.3 percent of full range p between taps at design temperature and pressure Low reactor coolant flow
+/-2.5 percent of full range within range of 70 percent to 100 percent of full flow (a)
Reactor coolant pump under voltage
+/-5 percent of rated voltage Reactor coolant pump bus underfrequency
+/-0.1 Hz Low-Low steam generator water level
+/-2.3 percent of p signal over pressure range of 700 to 1200 psig Note:
- 1. (a): Reproducibility
McGuire Nuclear Station UFSAR Table 7-4 (Page 1 of 4)
(14 APR 2005)
Table 7-4. Reactor Trip Correlation Trip (1)
Accident (2)
Tech. Spec. (3)
Power-Range High Neutron Flux Trip (Low Setpoint)
- 1. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From A Subcritical Condition (15.4.1)
- 2. Excessive Heat Removal Due to Feedwater System Malfunctions (15.1.1 & 15.1.2)
- 3. Rupture of a Control Rod Drive Mechanism Housing (15.4.8) 3.3.1 Power-Range High Neutron Flux Trip (High Setpoint)
- 1. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From A Subcritical Condition (15.4.1)
- 2. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
- 3. Startup of an Inactive Reactor Coolant Loop (15.4.4)
- 4. Excessive Heat Removal Due to Feedwater System Malfunctions (15.1.1 & 15.1.2)
- 5. Excessive Load Increase Incident (15.1.3)
- 6. Accidental Depressurization of the Main Steam System (15.1.4)
- 7. Major Secondary System Pipe Rupture (15.1.5)
- 8. Rupture of a Control Rod Drive Mechanism Housing (Rod Cluster Control Assembly Ejection) (15.4.8) 3.3.1 Intermediate-Range High Neutron Flux Trip Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From A Subcritical Condition (15.4.1) see note 4 Source-Range High Neutron Flux Trip Uncontrolled Rod Cluster Control Assembly Bank Withdrawal From A Subcritical Condition (15.4.1) see note 4 Power-Range High Positive Neutron Flux Rate Trip Rupture of a Control Rod Drive Mechanism Housing (Rod Cluster Control Assembly Ejection) (15.4.8) 3.3.1
McGuire Nuclear Station UFSAR Table 7-4 (Page 2 of 4)
(14 APR 2005)
Trip (1)
Accident (2)
Tech. Spec. (3)
Overtemperature T Trip
- 1. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal At Power (15.4.2)
- 2. Uncontrolled Boron Dilution (15.4.6)
- 3. Loss of External Electrical Load and/or Turbine Trip (15.2.2)
(15.2.3)
- 4. Excessive Heat Removal Due to Feedwater System Malfunctions (15.1.1 & 15.1.2)
- 5. Excessive Load Increase Incident (15.1.3)
- 6. Accidental Depressurization of the Reactor Coolant System (15.6.1)
- 7. Accidental Depressurization of the Main Steam System (15.1.4)
- 8. Loss of Reactor Coolant From Small Ruptured Pipes or From Cracks in large Pipes Which Actuates ECCS (15.6.5) 3.3.1 Overpower T Trip
- 1. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal at Power (15.4.2)
- 2. Excessive Heat Removal Due to Feedwater System Malfunctions (15.1.1 & 15.1.2)
- 3. Excessive Load Increase Incident (15.1.3)
- 4. Accidental Depressurization of The Main Steam System (15.1.4)
- 5. Major Secondary System Pipe Rupture (15.1.5) 3.3.1
McGuire Nuclear Station UFSAR Table 7-4 (Page 3 of 4)
(14 APR 2005)
Trip (1)
Accident (2)
Tech. Spec. (3)
Pressurizer Low Pressure
- 1. Accidental Depressurization of the Reactor Coolant System (15.6.1)
- 2. Loss of Reactor Coolant From Small Ruptured Pipes or From Cracks in Large Pipes Which Actuates ECCS (15.6.3)
- 3. Major Reactor Coolant System Pipe Ruptures (LOCA) (15.6.5)
- 4. Steam Generator Tube Rupture (15.6.3) 3.3.1 Pressurizer High Pressure Trip
- 1. Uncontrolled Rod Cluster Control Assembly Bank Withdrawal At Power (15.4.2)
- 2. Loss of External Electrical Load and/or Turbine Trip (15.2.2)
(15.2.3) 3.3.1 Pressurizer High Water Level Trip
- 1. Uncontrolled Rod Cluster Control Assembly Bank at Power (15.4.2)
- 2. Loss of External Electrical Load and/or Turbine Trip (15.2.2)
(15.2.3) 3.3.1 Low Reactor Coolant Flow
- 1. Partial Loss of Forced Reactor Coolant Fow (15.3.1)
- 2. Loss of Off-Site Power to the Station Auxiliaries (Station Blackout) (15.2.6)
- 3. Complete Loss of Forced Reactor Coolant Flow (15.3.2) 3.3.1 Reactor Coolant Pump Under Voltage Trip Complete Loss of Forced Reactor Coolant Flow (15.3.2) 3.3.1 Reactor Coolant Pump Bus Underfrequency Trip Complete Loss of Forced Reactor Coolant Flow (15.3.2) 3.3.1 Low-low Steam Generator Water Level Trip Loss of Normal Feedwater (15.2.7) 3.3.1
McGuire Nuclear Station UFSAR Table 7-4 (Page 4 of 4)
(14 APR 2005)
Trip (1)
Accident (2)
Tech. Spec. (3)
- 1. Loss of external electrical load and/or Turbine Trip (15.2.2)
(15.2.3) 3.3.1
- 2. Loss of Off-Site Power to the Station Auxiliaries (Station Blackout) (15.2.6)
Safety Injection Signal Actuation Trip Accidental Depressurization of the Main Steam System (15.1.4) see note 5 Manual Trip Available for all Accidents (15.0) see note 4 Note:
- 1. Trips are listed in order of discussion of Section 7.2.
- 2. References refer to accident analyses presented in 15.0.
- 3. References refer to Technical Specifications.
- 4. A technical specification is not required because this trip is not assumed to function in the accident analyses
- 5. Accident assumes that the reactor is tripped at end of life (EOL) which is the worst initial condition for this case. Pressurizer low pressure is the first out trip of safety injection.
McGuire Nuclear Station UFSAR Table 7-5 (Page 1 of 1)
(30 NOV 2012)
Table 7-5. Instrument 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 Pressure1 4
2 Deleted Per 2012 Update Note:
- 1. Permissible bypass if reactor coolant pressure less than 1955 psig.
McGuire Nuclear Station UFSAR Table 7-6 (Page 1 of 1)
(14 OCT 2000)
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 1b through 1c of Table 7-5
- b. Containment Pressure (Phase B)
See Item 2b of Table 7-5
- c. Manual
- 1) Phase A 2
1
- 2) Phase B See Item No. 2a of Table 7-5
- 2.
STEAM LINE ISOLATION
- a. Low Steam Line Pressure 3/steam line 2/steam line in any system line
- b. Containment Pressure High-High See Item 2b of Table 7-5
- c. Manual 1/loop 1/loop
- d. High Negative Steam Line Pressure Rate 3/Steam line in any steam line 2/Steam line
- 3.
FEEDWATER LINE ISOLATION
- a. Safety Injection See Item 1 of Table 7-5
McGuire Nuclear Station UFSAR Table 7-7 (Page 1 of 1)
(14 OCT 2000)
Table 7-7. Interlocks for Engineered Safety Features Actuation System Designation Input Function Performed P-4 Reactor trip Actuates turbine trip Closes main feedwater valves on Tavg below setpoint. Prevents opening of main feedwater valves which were closed by safety injection or high steam generator water level.
Allows manual reset/block of the automatic reactuation of safety injection.
Blocks steam dump control via load rejection Tavg controller.
Makes steam dump valves available for either tripping or modulation.
Reactor not tripped Defeats the manual reset/block preventing automatic reactuation of safety injection.
Blocks steam dump control via plant trip Tavg.
controller.
P-11 2/3 Pressurizer pressure below setpoint Allows manual block of safety injection actuation on low pressurizer pressure signal.
Allows manual block of steam line isolation on low compensated steam line pressure signal and allows steam line isolation on high steam line negative pressure rate.
2/3 Pressurizer pressure above setpoint Defeats manual block of steam line isolation on low steam line pressure and defeats steam line isolation on high steamline negative pressure rate.
Defeats manual block of safety injection actuation on low Pressurizer Pressure.
P-12 3/4 Tavg above setpoint Defeats the manual bypass of steam dump block.
P-14 2/3 Steam generator water level above setpoint on any steam generator.
Closes all feedwater control valves.
Trips all main feedwater pumps which closes the pump discharge valves.
Actuates turbine trip.
McGuire Nuclear Station UFSAR Table 7-8 (Page 1 of 2)
(14 OCT 2000)
Table 7-8. Auxiliary Shutdown Control Panel Controls and Indicators Available for Hot Standby Indicators Pressurizer Level Pressurizer Pressure Reactor Coolant Loop D Hot Leg Temperature NC Cold Leg Wide Range Temperature Neutron Flux Letdown Temperature Letdown Pressure Letdown Flow ND Pump Discharge Temp, A&B ND to NC Cold Leg Temp, A&B ND to NC Cold Leg Temp, C&D NC Wide Range Pressure Controls Reciprocating Charging Pump Nuclear Service Water Pump 1A Nuclear Service Water Pump 1B Component Cooling Water Pump 1A1 Component Cooling Water Pump 1A2 Component Cooling Water Pump 1B1 Component Cooling Water Pump 1B2 Pressurizer Heater Backup Group '1A' Pressurizer Heater Backup Group '1B' Boric Acid Transfer Pump 1A Boric Acid Transfer Pump 1B Letdown Orifice Isolation Valve - 1NV457A Letdown Orifice Isolation Valve - 1NV458A Letdown Orifice Isolation Valve - 1NV35A Centrifugal Charging Pump 1A Centrifugal Charging Pump 1B Boric Acid Charging Pumps Valve - 1NV265B Auxiliary Spray Supply to Pressurizer Isolation Valve - 1NV21A NV Supply to NC Loop 4 Isolation Valve - 1NV16A NV Supply to NC Loop 1 Isolation Valve - 1NV13B Pressurizer #1 Power Operated Safety Relief Valve - 1NC34A Pressurizer #1 Power Operated Safety Relief Valve - 1NC32B Pressurizer #1 Power Operated Safety Relief Valve - 1NC36B NC Loop 3 Supply to Excess Letdown Hx. #1 Isolation Valve - 1NV24B NC Loop 3 Supply to Excess Letdown Hx. #1 Isolation Valve - 1NV25B NC Letdown Isolation to Regenerative Hx. #1 Valve - 1NV1A NC Letdown Isolation to Regenerative Hx. #1 Valve - 1NV2A BA to BA Blender Control Valve - 1NV267A Excess Letdown Hx. #1 Tube Outlet Control Valve - 1NV26B Regenerative Hx. #1 Tube Inlet Control Valve - 1NV241 Charging Line Flow Control Valve - 1NV238
McGuire Nuclear Station UFSAR Table 7-8 (Page 2 of 2)
(14 OCT 2000)
Note:
- 1. While not used for hot standby, RHR controls as described in Section 7.4.1.5.1.6, have been provided on this panel for the operators convenience.
McGuire Nuclear Station UFSAR Table 7-9 (Page 1 of 1)
(14 OCT 2000)
Table 7-9. Auxiliary Feedwater Pump Motor 1A Control Panel Controls and Indicators Available for Hot Standby Indicators Steam Generator 1A Level Steam Generator 1B Level Steam Generator 1A Pressure Steam Generator 1B Pressure Flow to Steam Generator 1A Flow to Steam Generator 1B Controls Motor 1A Control Motor 1A Control Selector Hotwell Supply Valves - 1/CA/2, 1/CM/265 Pump 1A AFW to SG 1A Valve Position Selector Station Pump 1A AFW to SG 1B Valve Position Selector Station
McGuire Nuclear Station UFSAR Table 7-10 (Page 1 of 1)
(14 OCT 2000)
Table 7-10. Auxiliary Feedwater Pump Motor 1B Control Panel Controls and Indicators Available for Hot Standby Indicators Steam Generator 1C Level Steam Generator 1D Level Steam Generator 1C Pressure Steam Generator 1D Pressure Flow to Steam Generator 1C Flow to Steam Generator 1D Controls Motor 1B Control Motor 1B Control Selector Pump 1B AFW to SG 1C Valve Position Selector Station Pump 1B AFW to SG 1D Valve Position Selector Station
McGuire Nuclear Station UFSAR Table 7-11 (Page 1 of 1)
(14 OCT 2000)
Table 7-11. Auxiliary Feedwater Pump Turbine Control Panel Controls and Indicators Available for Hot Standby Indicators Steam Generator 1A Level Steam Generator 1B Level Steam Generator 1C Level Steam Generator 1D Level Steam Generator 1A Pressure Steam Generator 1B Pressure Steam Generator 1C Pressure Steam Generator 1D Pressure Flow to Steam Generator 1A Flow to Steam Generator 1B Flow to Steam Generator 1C Flow to Steam Generator 1D Controls Hotwell Supply Valve - 1/CM/265 Hotwell Supply Valve - 1/CA/2 AFWPT Control AFWPT Control Selector AFWPT Stop Valve - 1/SA/48 AFWPT Stop Valve - 1/SA/49
McGuire Nuclear Station UFSAR Table 7-12 (Page 1 of 2)
(05 APR 2011)
Table 7-12. Main Control Board Indicators and/or Recorders Available to the Operator. Condition II and III Events Parameter No. of Channels Range Available Indicated Accuracy(1)
Indicator/
Recorder Purpose Avail.
Req.
- 1.
Tcold or Thot (measured, wide range) 1 Thot, 1 Tcold per loop 2 Thot and 2 Tcold 0-700°F
+/- 4% of full range All channels are recorded Ensure maintenance of proper cooldown rate and to ensure maintenance of proper relationship between system pressure and temperature for NDTT considerations.
- 2.
Pressurizer Water Level 3
2 Entire distance between taps
+/- 5% of P at 2250 psia All 3 channels indicated; one channel is recorded Ensure maintenance of proper reactor coolant inventory.
- 3.
System Pressure (wide range) 2 2
0-3000 psig
+/- 3% of full range Both channels indicated; one channel is recorded.
Ensure maintenance of proper relationship between system pressure and temperature for NDTT considerations.
McGuire Nuclear Station UFSAR Table 7-12 (Page 2 of 2)
(05 APR 2011)
Parameter No. of Channels Range Available Indicated Accuracy(1)
Indicator/
Recorder Purpose Avail.
Req.
- 4.
Containment Pressure 4 (2 IR, 2 WR) 2 (WR)
-5 to 20 PSIG (IR)
+/- 2.4% of span All 4 are indicated, 2 are recorded (1 IR, 1 WR).
Monitor containment conditions to indicate need for potential safeguards actuation.
- 5.
Steam Line Pressure 2/Steamline 2/Steamline 0-1300 psig
+/- 4% of full scale All required channels are indicated, one is recorded Monitor steam generator temperature conditions during hot shutdown and cooldown, and for use in recovery steam generator ruptures.
- 6.
Steam Generator Water Level (wide range) 1/Steam Generator 2/Plant
+5 to -45 feet from nominal full load water level
+/- 5% of level span (cold)
All channels recorded Ensure maintenance of reactor heat sink.
- 7.
Steam Generator Water Level (narrow range) 4/Steam Generator 2/Steam Generator
+5 to -10 feet from nominal full load water level
+/- 4% of P span (hot)
All channels indicated Ensure maintenance of reactor heat sink.
(1) Includes accuracy and environmental effects.
McGuire Nuclear Station UFSAR Table 7-13 (Page 1 of 2)
(05 APR 2011)
Table 7-13. Main Control Board Indicators and/or Recorders Available to the Operator. Condition IV Events No. of Channels Parameter Avail.
Req.
Range Available Indicated Accuracy(1)
Indicator/
Recorder Purpose
- 1.
Containment Pressure 4 (2 IR, 2 WR) 2 (WR) -5 to 20 PSIG (IR)
+/- 2.4% of span All 4 are indicated, 2 are recorded (1 IR, 1 WR).
Monitor post-LOCA Containment conditions.
- 2.
Refueling Water Storage Tank Water Level 3
2 0-100% of span 4% of level span All are indicated and alarmed, one is recorded Ensure that water is flowing to the safety injection system after a LOCA and determine when to shift from injection to recirculation mode.
- 3.
Steam Generator Water Level (narrow range) 4/Steam Generator 2/Steam Generator
+5 to -10 feet from nominal full load level
+/- 18.6% of P span(a)
All channels indicated, one channel recorded Detect steam generator tube rupture; monitor steam generator water level following a steam line break.
- 4.
Steam line Pressure 2/Steam line 2/Steam line 0-1300 psig
+/- 12.5% of full scale All channels are indicated, one is recorded Monitor steam line pressures following steam generator tube rupture or steam line break.
McGuire Nuclear Station UFSAR Table 7-13 (Page 2 of 2)
(05 APR 2011)
No. of Channels Parameter Avail.
Req.
Range Available Indicated Accuracy(1)
Indicator/
Recorder Purpose
- 5.
Pressurizer Water Level 3
2 Entire distance between taps
+/-29% of span All 3 are indicated and one is recorded Indicate that water has returned to pressurizer following cooldown after steam generator rupture or steam line break.
(1) Includes accuracy and environmental effects.
(2) For the steam break, when the water level channel is exposed to a hostile environment, the accuracy required can be relaxed. The indication need only convey to the operator that water level in the steam generator is somewhere between the narrow range steam generator water level taps.
McGuire Nuclear Station UFSAR Table 7-14 (Page 1 of 9)
(09 OCT 2015)
Table 7-14. Control Room Indicators and/or Recorders Available to the Operator to Monitor Significant Unit Parameters During Normal Operation Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes NUCLEAR INSTRUMENTATION
- 1. Source Range
- a. Count rate (NIS) 2 0.1 to 106 counts/sec
+/- 10% of the linear full scale Both channels indicated.
Control Board Deleted Per 2015 Update
- b. Count rate (Gamma-metrics) 2 0.1 to 105 counts/sec.
+/- 2% of full scale or of equivalent full scale Both channels indicated Control board Provided for Cat-1 PAM per Table 1-6, and to supplement S/R NIS during modes 3-6 operations
- c. Startup rate (NIS) 2
-0.5 to 5.0 decades/min.
+/-10% of the linear full scale analog voltage Both channels indicated.
Control Board
- 2. Intermediate Range
- a. Flux level 2
10 decades of neutron flux (corresponds to 0 to full scale analog voltage) overlapping the source range by 4 decades 9% of the log arithmic of the full scale.
Both channels indicated.
Control Board
McGuire Nuclear Station UFSAR Table 7-14 (Page 2 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- b. Startup rate 2
-0.5 to 5.0 decades/min.
+/-9 % of the linear full scale analog voltage Both channels indicated.
Control Board
- 3. Power Range
- a. Uncalibrate d ion chamber current (top and bottom uncompens ated ion chambers) 4 0 to 120% of full power current
+/- 1% of full span All 8 current signals indicated.
NIS Racks in control room Meters NI301(302) provide a 0 to 5 mA DC current indication of the full power level of the reactor section monitored.
McGuire Nuclear Station UFSAR Table 7-14 (Page 3 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- b. Calibrated ion chamber current 4
0-120% of full power
+/- 2% of full span 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 Deleted Per 2015 Update
- c. Average flux of the top and bottom ion chamber 4
0 to 120% of full power
+/-3% of full power for indication, +/- 2%
for recording All 4 channels indicated. Any 2 of the four channels may be recorded.
Control Board
McGuire Nuclear Station UFSAR Table 7-14 (Page 4 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- d. Average flux of the top and bottom ion chambers 4
0 to 120% of full power, 0 to 200% full power
+/- 2% of full power to 120%, +/- 6% of full power to 200%.
All 4 channels recorded.
Control Board
- e. 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 indicated. One channel is available on Ovation PCS.
Control Board
- a. Tcold or Thot (measured, wide range) 1-Thot and 1-Tcold per loop 0-700° +/- 4% of span Both channels recorded.
Control Board
- 3. Overpower T Setpoint 1/Loop 0 to 150% of full power T
+/- 3% of full power T
All channels indicated. One channel is selected for recording.
Control Board
McGuire Nuclear Station UFSAR Table 7-14 (Page 5 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- 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. One channel is recorded.
Control Board
- 6. Pressurizer Level 3
Entire distance between taps
+/- 5% of P signal at 2250 psia All channels indicated. One channel is recorded.
Control Board Two pen recorder used, second pen records reference level signal.
- 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 motor amperes 1/Loop 0 to 800 amperes
+/- 4%
All channels indicated.
Control Board One channel for each bus.
- 9. System Pressure Wide Range 2
0-3000 psig +/- 3% of full range Both channels indicated; one is recorded.
Control Board REACTOR CONTROL SYSTEM
- 1. Demanded Rod Speed 1
0 to 100% of rated speed
+/- 5%
The one channel is indicated.
Control Board
McGuire Nuclear Station UFSAR Table 7-14 (Page 6 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- 2. Auctioneered Taverage 1
530° to 630°F +/- 3°F The one channel is recorded.
Control Board The highest of the four Tavg channels into the auctioneer will be passed to the recorder
- 3. Treference 1
530 to 630°F +/-4°F The one channel is recorded.
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.
McGuire Nuclear Station UFSAR Table 7-14 (Page 7 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- b. Full length rod measured position 1 for each rod 0 to 228 steps +/- 3 steps at full accuracy, +/- 12 steps at 1/2 accuracy Each rod position is indicated.
Control Board CONTAINMENT SYSTEM Containment Pressure 4
-5 to 20 PSIG +/- 2.4% of full scale All 4 channels indicated, one is recorded Control Board FEEDWATER AND STEAM SYSTEMS
- 1. Auxiliary Feedwater Flow 1/Feed line 0 to 600 gpm 8.8% All channels indicated.
Control Board One channel to measure the flow to each steam generator.
- 2. Steam Generator level (narrow range) 4/Steam generator
+5 to -10 feet from nominal full load level
+/- 4% of P (hot)
All channels indicated.
One channel per Steam Generator is recorded.
Control Board
- 3. Steam generator level (wide range) 1/Steam generator
+5 to -45 ft from nominal full load level
+/- 5% of level (cold)
All channels recorded.
Control Board
- 4. Programmed steam generator level signal 1/Steam generator 38.9% to 65%
of span
+/- 4% All channels recorded.
Control Board
McGuire Nuclear Station UFSAR Table 7-14 (Page 8 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- 5. Main feedwater flow 2/Steam generator 0 to 120% of maximum calculated flow
+/- 5% 2 channels per Steam Generator is indicated. One channel per Steam Generator is recorded.
Control Board
- 6. Magnitude of signal controlling main and bypass control valves 1/Main 0 to 100% of valve opening
+/- 3% All channels indicated.
Control Board
- 1. One channel for each main feedwater control valve.
- 2. OPEN/SHU T indication is provided in the control room for each main and bypass feedwater control valve.
McGuire Nuclear Station UFSAR Table 7-14 (Page 9 of 9)
(09 OCT 2015)
Parameter No. of Channels Available Range Indicated Accuracy(1)
Indicator/
Recorder Location Notes
- 7. Steam flow 2/Steam generator 0 to 117% of max.
calculated flow
+/- 5.5% All channels indicated.
One channel is are recorded.
Control Board Accuracy is equipment capability;
- however, absolute accuracy depends on calibration against feedwater flow.
- 8. Steam line pressure 3/loop 0 to 1300 psig +/- 4% of full scale All channels indicated, one is recorded Control Board
- 9. Steam dump modulate signal 1
0-100% max.
steam dump capacity
+/- 3% The one channel is indicated.
Control Board OPEN/SHUT indication is provided in the control room for each steam dump valve.
- 10. Turbine inlet pressure 3
0 to 1000 PSI
+/- 3.5% Two channels indicated.
Control Board OPEN/SHUT indication is provided in the control room for each turbine stop valve.
(1) Includes channel accuracy and environmental effects.
McGuire Nuclear Station UFSAR Table 7-15 (Page 1 of 3)
(27 MAR 2002)
Table 7-15. Single Failure Analysis on Containment Pressure Control System Air Return Fans and Discharge Dampers Resulting Consequences Component Malfunction Containment Pressure Control Engineered Safety Features One Pressure Switch (Air Return Fan)
Fails High None - Signal to discharge damper will prevent air flow before blowdown event and redundant signal to Air Return Fan will prevent air flow after blowdown event.
None - ESF signal is not inhibited One Pressure Switch (Air Return Fan)
Fails Low None - This is the fail-safe position of the CPCS.
None - Redundant train will operate and provide air flow One Pressure Switch (Discharge Damper)
Fails High None - Signal to air return fan will prevent air flow None - ESF signal is not inhibited One Pressure Switch (Discharge Damper)
Fails Low None - This is the fail-safe position of the CPCS None - Redundant train will operate and provide air flow Motor Starter Fails Open None - The fan fails to start None - The redundant train will operate and provide air flow Motor Starter Fails Closed None - Signal to discharge damper will prevent air flow None - Fan will operate Discharge Damper Fails Open None - Signal to fan will prevent air flow None - This is fail safe condition of ESF System Discharge Damper Fails Closed None - This is safe condition of CPCS None - The redundant train will operate and provide air flow Air Return Fan Fails to Start None - This is safe condition of CPCS None - The redundant train will operate and provide air flow One Power Supply Loss None - This is safe condition of CPCS None - The redundant train will operate and provide air flow One Pressure Switch (Spray Pump)
Fails High None - Signal to discharge valve will prevent spray None - EST signal is not inhibited
McGuire Nuclear Station UFSAR Table 7-15 (Page 2 of 3)
(27 MAR 2002)
Resulting Consequences Component Malfunction Containment Pressure Control Engineered Safety Features One Pressure Switch (Spray Pump)
Fails Low None - This is safe condition for CPCS None - Redundant train will provide spray One Pressure Switch (Discharge Valve)
Fails High None - Signal to spray pump will prevent spray None - ESF signal is not inhibited One Pressure Switch (Discharge Valve)
Fails Low None - This is safe condition for CPCS None - Redundant train will provide spray Valve Fails Open None - Signal to spray pump will prevent spray None - This is safe condition for ESF Valve Fails Closed None - This is safe condition for CPCS None - Redundant train will provide spray Pump Breaker Fails Open None - This is safe condition for CPCS None - The redundant train will provide spray Pump Breaker Fails Closed None - Signal to spray valve will prevent spray None - Redundant train will provide spray Feeder Cable for 4KV Switchgear Fails Open None - This is safe condition for CPCS None - Redundant train will provide spray One Pressure Switch (H2 Skimmer Fan & Air Return Fan)
Fails High None - Fan operates continuously after initiation None - ESF Signal is not inhibited One Pressure Switch (H2 Skimmer Fan & Air Return Fan)
Fails Low None - This is the fail safe position of the CPCS None - Redundant train will operate and provide air flow Motor Starter Fails Open None - The fan fails to start None - The redundant train will operate and provide air flow Motor Starter Fails Closed None - Signal to inlet valve will prevent air flow None - Fan will operate Inlet Valve Fails Closed None - This is the safe condition of CPCS None - The redundant train will operate and provide air flow
McGuire Nuclear Station UFSAR Table 7-15 (Page 3 of 3)
(27 MAR 2002)
Resulting Consequences Component Malfunction Containment Pressure Control Engineered Safety Features H2 Skimmer Fan Fails to Start None - This is the safe condition of CPCS None - The redundant train will operate and provide air flow One Power Supply Loss None - This is the safe condition of CPCS None - The redundant train will operate and provide air flow
McGuire Nuclear Station UFSAR Table 7-16 (Page 1 of 3)
(14 APR 2005)
Table 7-16. Ice Condenser RTD's Bay No.
Radial Loc.
Elev. Above Wear Slab Detail Bay No.
Radial Loc.
Elev. Above Wear Slab Detail ICE BED RTD's:
1 24 3
55 FT (2) 25 13 3
55 FT (2) 2 24 3
30 FT 9 (2) 26 13 3
30 FT 9 (2) 3 24 3
0 FT 0 (2) 27 13 3
0 FT 0 (2) 4 21 2
55 FT (1) 28 10 2
55 FT (1) 5 21 2
30 FT 9 (1) 29 10 2
30 FT 9 (1) 6 21 2
10 FT 6 (1) 30 10 2
10 FT 6 (1) 7 18 1
55 FT (1) 31 7
1 55 FT (1) 8 18 1
30 FT 9 (1) 32 7
1 30 FT 9 (1) 9 18 1
10 FT 6 (1) 33 7
1 10 FT 6 (1) 10 18 2
55 FT (1) 34 7
2 55 FT (1) 11 18 2
30 FT 9 (1) 35 7
2 30 FT 9 (1) 12 18 2
10 FT 6 (1) 36 7
2 10 FT 6 (1) 13 18 3
55 FT (1) 37 7
3 55 FT (1) 14 18 3
30 FT 9 (1) 38 7
3 30 FT 9 (1) 15 18 3
10 FT 6 (1) 39 7
3 10 FT 6 (1) 16 15 2
55 FT (1) 40 4
2 55 FT (1) 17 15 2
30 FT 9 (1) 41 4
2 30 FT 9 (1) 18 15 2
10 FT 6 (1) 42 4
2 10 FT 6 (1) 19 13 1
55 FT (6) 43 1
3 55 FT (2) 20 13 1
30 FT 9 (6) 44 1
3 30 FT 9 (2) 21 13 1
1 FT 6 (6) 45 1
3 0 FT 0 (2) 22 13 2
55 FT (1) 46 13 See Dwg.
58 FT 6 (3) 23 13 2
30 FT 9 (1) 47 13 See Dwg.
58 FT 6 (4) 24 13 2
10 FT 6 (1) 48 13 Spare (5)
FLOOR COOLING RTD's:
13 13 2
0 FT 0 (7) 2 2
2 0 FT 0 (7) 14 14 2
0 FT 0 (7) 3 3
2 0 FT 0 (7)
McGuire Nuclear Station UFSAR Table 7-16 (Page 2 of 3)
(14 APR 2005)
Bay No.
Radial Loc.
Elev. Above Wear Slab Detail Bay No.
Radial Loc.
Elev. Above Wear Slab Detail 16 16 2
0 FT 0 (7) 5 5
2 0 FT 0 (7) 17 17 2
0 FT 0 (7) 6 6
2 0 FT 0 (7) 19 19 2
0 FT 0 (7) 8 8
2 0 FT 0 (7) 20 20 2
0 FT 0 (7) 9 9
2 0 FT 0 (7) 10 10 2
0 FT 0 (7) 22 22 2
0 FT 0 (7) 23 23 2
0 FT 0 (7) 12 12 2
0 FT 0 (7)
FLOOR COOLING GLYCOL RTD's:
34 1
2 FT 0 35 1
8 FT 0 36 1
51 FT 0 37 1
5 FT 0 Bay No.
Radial Loc.
Elev. Above Wear Slab Detail TEMPERATURE SWITCHES:
1 1
2 57 FT (T) 2 4
2 57 FT (T) 3 7
2 57 FT (T) 4 18 2
57 FT (T) 5 21 2
57 FT (T) 6 24 2
57 FT (T)
WALL PANEL RTD's:
25 1
10 FT 6 (8) 26 8
10 FT 6 (8) 27 8
1 FT 0 (8) 28 13 10 FT 6 (8) 29 13 1 FT 0 (8) 30 18 10 FT 6 (8) 31 18 1 FT 0 (8) 32 24 10 FT 6 (8)
McGuire Nuclear Station UFSAR Table 7-16 (Page 3 of 3)
(14 APR 2005)
Bay No.
Radial Loc.
Elev. Above Wear Slab Detail Bay No.
Radial Loc.
Elev. Above Wear Slab Detail WEAR SLAB RTD's:
41 1
1 0FT0 (7) 44 8
1 0FT0 (7) 42 17 1
0FT0 (7) 45 8
2 0FT0 (7) 43 17 2
0FT0 (7) 46 24 1
0FT0 (7)
Deleted Per 2005 Update FLOOR THAW RTDs NPRD9840 1-2 2
0FT0 (7)
NPRD9880 15-16 2
0FT0 (7)
NPRD9850 4-5 2
0FT0 (7)
NPRD9890 18-19 2
0FT0 (7)
NPRD9860 7-8 2
0FT0 (7)
NPRD9900 21-22 2
0FT0 (7)
NPRD9870 11-12 2
0FT0 (7)
NPRD9910 24 2
0FT0 (7)
DETAIL NO:
(1) (2) (6)
- LATTICE-FRAME MTD. ICE BED. TEMP. RTD (3) (4)
- PLENUM-PANEL MTD. RTD (5)
- NOT USED (7)
- WEAR SLAB (FLOOR) MTD. RTD (8)
- WALL PANEL MTD. RTD (T)
- TEMPERATURE SWITCH
McGuire Nuclear Station UFSAR Table 7-17 (Page 1 of 1)
(14 OCT 2000)
Table 7-17. Devices Actuated on ESFAS and LOOP Equipment Train A Train B CRA-P-1 X
CRA-C-1 X
CR-AHU-11 X
CRA-AHU-11 X
SGR-AHU-1A1 X
SGR-AHU-2A1 X
SGR-AHU-1C1 X
SGR-AHU-2C1 X
BR-XF-11 X
CRA-P-2 X
CRA-C-2 X
CR-AHU-21 X
CRA-AHU-21 X
SGR-AHU-1B1 X
SGR-AHU-2B1 X
SGR-AHU-1D1 X
SGR-AHU-2D1 X
BR-XF-21 X
CRA-OAPFT-1 X
CRA-OAPFT-2 X
Note:
- 1. Includes associated dampers.
- 2. X Denotes operational equipment.
McGuire Nuclear Station UFSAR Table 7-18 (Page 1 of 1)
(30 NOV 2012)
Table 7-18. Unit 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 Defeats remote load dispatching C-4 2/4 Overpower T above setpoint Blocks automatic and manual control rod withdrawal Actuates turbine runback via load reference Defeats remote load dispatching C-5 1/1 Turbine inlet pressure below setpoint Defeats remote load dispatching Blocks automatic control rod withdrawal C-7A 1/1 Time derivative (absolute value) of turbine inlet pressure (decrease only) above setpoint Makes steam dump valves available for either tripping or modulation C-9 Any condenser pressure above setpoint, or any 3 out of 4 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
McGuire Nuclear Station UFSAR Table 7-19 (Page 1 of 2)
(24 APR 2014)
Table 7-19. Reactor Trip System Instrumentation Response Times Functional Unit Response Time
- 1. Manual Reactor Trip N.A.
- 2. Power Range, Neutron Flux 0.5 second
- 3. Power Range, Neutron Flux, High Positive Rate N.A.
- 4. Intermediate Range, Neutron Flux N.A.
- 5. Source Range, Neutron Flux N.A.
- 6. Overtemperature DT (Note 1)
Narrow Range RTD time constant Filter Time Constant Thot and Tcold input to DT Tavg input to setpoint Pressurizer pressure input to set point Flux imbalance input to set point
- a. 3.5 sec 4.7 sec 2.606 sec 1.863 sec 1.500 sec 1.500 sec
- b. 4.0 sec 4.25 sec 2.488 sec 1.827 sec
- c. 4.5 sec 3.8 sec 2.372 sec 1.791 sec
- d. 5.0 sec 3.35 sec 2.259 sec 1.755 sec
- e. 5.5 sec 2.9 sec 2.149 sec 1.720 sec
- f. 6.0 sec 2.45 sec 2.042 sec 1.685 sec
- g. 6.5 sec 2.0 sec 1.937 sec 1.650 sec
- h. 7.0 sec 1.55 sec 1.835 sec 1.616 sec
- i.
7.5 sec 1.1 sec 1.734 sec 1.582 sec Deleted Per 2014 Update.
- 7. Overpower DT (Note 1)
Narrow Range RTD time constant Filter time Constant Thot and Tcold input to DT Tavg input to setpoint Flux imbalance input to set point
- a. 3.5 sec 4.7 sec 2.606 sec 1.500 sec (Note 2) 1.500 sec
- b. 4.0 sec 4.25 sec 2.488 sec
- c. 4.5 sec 3.8 sec 2.372 sec
- d. 5.0 sec 3.35 sec 2.259 sec
- e. 5.5 sec 2.9 sec 2.149 sec
- f. 6.0 sec 2.45 sec 2.042 sec
- g. 6.5 sec 2.0 sec 1.937 sec
- h. 7.0 sec 1.55 sec 1.835 sec
- i.
7.5 sec 1.1 sec 1.734 sec Deleted Per 2014 Update.
McGuire Nuclear Station UFSAR Table 7-19 (Page 2 of 2)
(24 APR 2014)
Functional Unit Response Time
- 8. Pressurizer PressureLow 2.0 seconds
- 9. Pressurizer Pressure - High 2.0 seconds
- 10. Pressurizer Water LevelHigh N.A
- 11. Low Reactor Coolant flow
- a. Single Loop (Above P-8) 1.0 second
- b. Two Loops (Above P-7 and below P-8) 1.0 second
- 12. Steam Generator Water Level--Low-Low 3.039 seconds
- 13. Undervoltage-Reactor Coolant Pumps
< 1.5 seconds
- 14. Underfrequency-Reactor Coolant Pumps
< 0.6 second
- 15. Turbine Trip
- a. Low Fluid Oil Pressure N.A
- b. Turbine Stop Valve Closure N.A
- 16. Safety Injection Input from ESF N.A.
- 17. Reactor Trip System Interlocks N.A.
- 18. Reactor Trip Breakers N.A.
- 19. Automatic Trip and Interlock Logic N.A.
Note(s):
- 1. The RTD and filter time constant combinations for Overtemperature DT and Overpower DT are provided to allow adjustments to reduce spurious DT runback alarms resulting from hot leg streaming.
- 2. The response time requirement for Tave input to set point for Overpower DT is the same for all combinations of RTD time constants and filter time constants.
McGuire Nuclear Station UFSAR Table 7-20 (Page 1 of 3)
(09 OCT 2015)
Table 7-20. Engineered Safety Features Response Times Initiating signal and Function Response Time In Seconds
- 1. Manual
- a. Safety Injection (ECCS)
N.A.
Deleted Per 2012 Update
- b. Containment Isolation
- 1) Phase A Isolation N.A.
- 2) Phase B Isolation N.A.
- 3) Purge and Exhaust Isolation N.A.
- c. Steam Line Isolation N.A.
- d. Feedwater Isolation N.A.
- e. Auxiliary Feedwater N.A.
- f. Nuclear Service Water N.A.
- g. Component Cooling Water N.A.
- h. Reactor Trip (from SI)
N.A.
- i.
Start Diesel Generators N.A.
- 2. Containment Pressure-High
- a. Safety Injection (ECCS) 27(1)
- b. Reactor Trip (from SI) 2
- c. Feedwater Isolation 12
- d. Containment Isolation-Phase A(2) 18(3)/28(4)
- e. Containment Purge and Exhaust Isolation N.A.
- f. Auxiliary Feedwater(5)
N.A.
- g. Nuclear Service Water 65(3)/76(4)
- h. Component Cooling Water 65(3) /76(4)
- i.
Start Diesel Generators 11
- 3. Pressurizer Pressure-Low-Low
- a. Safety Injection (ECCS) 27(1)/12(3)
- b. Reactor Trip (from SI) 2
- c. Feedwater Isolation 12
- d. Containment Isolation-Phase A(2) 18(3) /28(4)
- e. Containment Purge and Exhaust Isolation N.A.
- f. Auxiliary Feedwater5 N.A.
McGuire Nuclear Station UFSAR Table 7-20 (Page 2 of 3)
(09 OCT 2015)
Initiating signal and Function Response Time In Seconds
- g. Nuclear Service Water System 76(1)/65(3)
- h. Component Cooling Water 76(1)/65(3)
- i.
Start Diesel Generators 11
- 4. Steam Line Pressure-Low Steam Line Isolation 10
- 5. Containment Pressure-High-High Deleted Per 2012 Update
- a. Containment Isolation-Phase B N.A.
- b. Steam Line Isolation 10
- 6. Steam Generator Water Level-High-High
- a. Turbine Trip N.A.
- b. Feedwater Isolation 12
- 7. Steam Generator Water Level Low-Low
- a. Motor-driven Auxiliary 60
- b. Turbine-driven Auxiliary Feedwater Pump 60
- 8. Negative Steam Line Pressure Rate - High Steam Line Isolation 10
- 9. Start Permissive Containment Pressure Control System N.A.
- 10. Termination Containment Pressure Control System N.A.
- 11. Auxiliary Feedwater Suction Pressure - Low Auxiliary Feedwater Pumps (Suction Supply Automatic Realignment 19
- 12. RWST Level Automatic Switchover to Recirculation 100
- 13. Blackout
- a. Start Motor-Driven Auxiliary Feedwater Pumps 60
- b. Start Turbine-Driven Auxiliary Feedwater Pump(6) 60
- 14. Trip of Main Feedwater Pumps Start Motor-Driven Auxiliary Feedwater 60
McGuire Nuclear Station UFSAR Table 7-20 (Page 3 of 3)
(09 OCT 2015)
Initiating signal and Function Response Time In Seconds Pumps
- 15. Loss of Power
- a. 4 kV Loss of Voltage 11
TABLE NOTATION
- 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 contrifugal charging pumps, Safety Injection and RHR pumps.
- 2. Valves 1KC305B and 1KC315B are exceptions to the response times listed in the table. The following response times in seconds are the required values for those valves for the initiating signal and function indicated:
2.d 30 (3)/40(4) 3.d 30 (3) 4.d 30 (3)/40(4)
- 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 and Safety Injection 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 and Safety Injection pumps.
- 5. Response time for motor-driven auxiliary feedwater pumps on all Safety Injection signal shall be less than or equal to 60 seconds. Response time limit includes opening of valves to establish Safety Injection path and attainment of discharge pressure for auxiliary feedwater pumps.
- 6. The turbine driven pump does not start on a blackout signal coincident with a safety injection signal.
- 7. Deleted Per 2012 Update.