ML20309A730

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2 to Updated Final Safety Analysis Report, Chapter 7, Appendix 7A, Tables
ML20309A730
Person / Time
Site: Mcguire, McGuire  Duke Energy icon.png
Issue date: 10/08/2020
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Duke Energy Carolinas
To:
Office of Nuclear Reactor Regulation
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RA-19-0424
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McGuire Nuclear Station UFSAR Appendix 7A. Tables Appendix 7A. Tables

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

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 High and low settings; manual block by P-10 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, Manual block and automatic reset.

interlocked with P-10 Automatic block above P-10 Power range high positive neutron flux 2/4 No interlocks rate 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- 2/4 Interlocked with P-7 Under frequency on 2 buses will trip frequency 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 (14 OCT 2000)

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

Reactor Trip Coincident Logic Interlocks Comments Safety injection signal Coincident with No interlocks (See Section 7.3 for Engineered Safety actuation of safety Features actuation conditions) injection 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 (14 OCT 2000)

McGuire 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 1/2 Neutron flux (intermediate- range) above Allows manual block of setpoint source range reactor trip 2/2 Neutron flux (intermediate- range) below Defeats the block of source setpoint range reactor trip P-10 2/4 Neutron flux (power-range) above Allows manual block of power setpoint 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 Signal blocks reactor trip on:

(from P-10) and 2/2 Turbine inlet pressure Low flow in more than one below setpoint (from P-13) loop, under voltage, underfrequency, pressurizer low pressure, and pressurizer high level P-8 2/4 Neutron flux (power-range) above Signal unblocks reactor trip setpoint on low reactor coolant flow or turbine trip P-13 2/2 Turbine inlet pressure below setpoint Input to P-7 (09 OCT 2015)

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

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 +/-5 percent (a) flux rate 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 (a) of 70 percent to 100 percent of full flow Reactor coolant pump under voltage +/-5 percent of rated voltage Reactor coolant pump bus +/-0.1 Hz underfrequency Low-Low steam generator water +/-2.3 percent of p signal over level pressure range of 700 to 1200 psig Note:

1. (a): Reproducibility (09 OCT 2015)

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

Table 7-4. Reactor Trip Correlation Trip (1) Accident (2) Tech. Spec. (3)

Power-Range High Neutron Flux 1. Uncontrolled Rod Cluster 3.3.1 Trip (Low Setpoint) 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)

Power-Range High Neutron Flux 1. Uncontrolled Rod Cluster 3.3.1 Trip (High Setpoint) 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)

Intermediate-Range High Neutron Uncontrolled Rod Cluster Control see note 4 Flux Trip Assembly Bank Withdrawal From A Subcritical Condition (15.4.1)

Source-Range High Neutron Flux Uncontrolled Rod Cluster Control see note 4 Trip Assembly Bank Withdrawal From A Subcritical Condition (15.4.1)

Power-Range High Positive Neutron Rupture of a Control Rod Drive 3.3.1 Flux Rate Trip Mechanism Housing (Rod Cluster Control Assembly Ejection) (15.4.8)

(14 APR 2005)

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

Trip (1) Accident (2) Tech. Spec. (3)

Overtemperature T Trip 1. Uncontrolled Rod Cluster 3.3.1 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)

Overpower T Trip 1. Uncontrolled Rod Cluster 3.3.1 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)

(14 APR 2005)

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

Trip (1) Accident (2) Tech. Spec. (3)

Pressurizer Low Pressure 1. Accidental Depressurization of 3.3.1 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)

Pressurizer High Pressure Trip 1. Uncontrolled Rod Cluster 3.3.1 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)

Pressurizer High Water Level Trip 1. Uncontrolled Rod Cluster 3.3.1 Control Assembly Bank at Power (15.4.2)

2. Loss of External Electrical Load and/or Turbine Trip (15.2.2)

(15.2.3)

Low Reactor Coolant Flow 1. Partial Loss of Forced Reactor 3.3.1 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)

Reactor Coolant Pump Under Complete Loss of Forced Reactor 3.3.1 Voltage Trip Coolant Flow (15.3.2)

Reactor Coolant Pump Bus Complete Loss of Forced Reactor 3.3.1 Underfrequency Trip Coolant Flow (15.3.2)

Low-low Steam Generator Water Loss of Normal Feedwater (15.2.7) 3.3.1 Level Trip (14 APR 2005)

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

Trip (1) Accident (2) Tech. Spec. (3)

Reactor Trip on Turbine Trip 1. Loss of external electrical load 3.3.1 and/or Turbine Trip (15.2.2)

(15.2.3)

2. Loss of Off-Site Power to the Station Auxiliaries (Station Blackout) (15.2.6)

Safety Injection Signal Actuation Accidental Depressurization of the see note 5 Trip Main Steam System (15.1.4)

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.

(14 APR 2005)

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

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 3 2 Pressure
c. Pressurizer Low Pressure1 4 2 Deleted Per 2012 Update Note:
1. Permissible bypass if reactor coolant pressure less than 1955 psig.

(30 NOV 2012)

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

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 See Item 1b through 1c of Injection (Phase A) Table 7-5
b. Containment See Item 2b of Table 7-5 Pressure (Phase B)
c. Manual 2 1
1) Phase A
2) Phase B See Item No. 2a of Table 7-5
2. STEAM LINE ISOLATION
a. Low Steam Line 3/steam line 2/steam line in any system Pressure line
b. Containment See Item 2b of Table 7-5 Pressure High-High
c. Manual 1/loop 1/loop
d. High Negative 3/Steam line in any steam 2/Steam line Steam Line line Pressure Rate
3. FEEDWATER LINE ISOLATION
a. Safety Injection See Item 1 of Table 7-5 (14 OCT 2000)

McGuire Nuclear Station UFSAR Table 7-7 (Page 1 of 1)

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 Allows manual block of safety injection actuation setpoint 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 Defeats manual block of steam line isolation on setpoint 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 Closes all feedwater control valves.

above setpoint on any steam generator.

Trips all main feedwater pumps which closes the pump discharge valves.

Actuates turbine trip.

(14 OCT 2000)

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

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 (14 OCT 2000)

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

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.

(14 OCT 2000)

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

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 (14 OCT 2000)

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

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 (14 OCT 2000)

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

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 (14 OCT 2000)

McGuire Nuclear Station UFSAR Table 7-12 (Page 1 of 2)

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 Indicator/ Purpose Indicated Recorder Avail. Req.

Accuracy(1)

1. Tcold or Thot 1 Thot, 1 Tcold per 2 Thot and 2 Tcold 0-700°F +/- 4% of full range All channels are Ensure (measured, loop recorded maintenance of wide range) proper cooldown rate and to ensure maintenance of proper relationship between system pressure and temperature for NDTT considerations.
2. Pressurizer 3 2 Entire distance +/- 5% of P at 2250 All 3 channels Ensure Water Level between taps psia indicated; one maintenance of channel is proper reactor recorded coolant inventory.
3. System 2 2 0-3000 psig +/- 3% of full range Both channels Ensure Pressure (wide indicated; one maintenance of range) channel is proper recorded. relationship between system pressure and temperature for NDTT considerations.

(05 APR 2011)

McGuire Nuclear Station UFSAR Table 7-12 (Page 2 of 2)

Parameter No. of Channels Range Available Indicator/ Purpose Indicated Recorder Avail. Req.

Accuracy(1)

4. Containment 4 (2 IR, 2 WR) 2 (WR) -5 to 20 PSIG +/- 2.4% of span All 4 are Monitor Pressure (IR) indicated, 2 are containment

-5 to 60 PSIG recorded (1 IR, conditions to (WR) 1 WR). indicate need for potential safeguards actuation.

5. Steam Line 2/Steamline 2/Steamline 0-1300 psig +/- 4% of full scale All required Monitor steam Pressure channels are generator indicated, one is temperature recorded conditions during hot shutdown and cooldown, and for use in recovery steam generator ruptures.
6. Steam 1/Steam 2/Plant +5 to -45 feet +/- 5% of level span All channels Ensure Generator Generator from nominal full (cold) recorded maintenance of Water Level load water level reactor heat sink.

(wide range)

7. Steam 4/Steam 2/Steam +5 to -10 feet +/- 4% of P span All channels Ensure Generator Generator Generator from nominal full (hot) indicated maintenance of Water Level load water level reactor heat sink.

(narrow range)

(1)

Includes accuracy and environmental effects.

(05 APR 2011)

McGuire Nuclear Station UFSAR Table 7-13 (Page 1 of 2)

Table 7-13. Main Control Board Indicators and/or Recorders Available to the Operator. Condition IV Events No. of Channels Available Indicated Indicator/

Parameter Avail. Req. Range Accuracy(1) Recorder Purpose

1. Containment 4 (2 IR, 2 WR) 2 (WR) -5 to 20 PSIG +/- 2.4% of span All 4 are Monitor post-Pressure (IR) indicated, 2 are LOCA

-5 to 60 PSIG recorded (1 IR, 1 Containment (WR) WR). conditions.

2. Refueling Water 3 2 0-100% of span 4% of All are indicated Ensure that water Storage Tank and alarmed, one is flowing to the level span Water Level is recorded safety injection system after a LOCA and determine when to shift from injection to recirculation mode.
3. Steam Generator 4/Steam 2/Steam +5 to -10 feet +/- 18.6% of P All channels Detect steam Water Level Generator Generator from nominal full span(a) indicated, one generator tube (narrow range) load level channel recorded rupture; monitor steam generator water level following a steam line break.
4. Steam line 2/Steam line 2/Steam line 0-1300 psig +/- 12.5% of full All channels are Monitor steam Pressure scale indicated, one is line pressures recorded following steam generator tube rupture or steam line break.

(05 APR 2011)

McGuire Nuclear Station UFSAR Table 7-13 (Page 2 of 2)

No. of Channels Available Indicated Indicator/

Parameter Avail. Req. Range Accuracy(1) Recorder Purpose

5. Pressurizer 3 2 Entire distance +/-29% of span All 3 are Indicate that Water Level between taps indicated and one water has is recorded 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.

(05 APR 2011)

McGuire Nuclear Station UFSAR Table 7-14 (Page 1 of 9)

Table 7-14. Control Room Indicators and/or Recorders Available to the Operator to Monitor Significant Unit Parameters During Normal Operation No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes NUCLEAR INSTRUMENTATION

1. Source Range
a. Count rate 2 0.1 to 106 +/- 10% of the linear Both channels Control Board Deleted Per (NIS) counts/sec full scale indicated. 2015 Update
b. Count rate 2 0.1 to 105 +/- 2% of full scale Both channels Control board Provided for (Gamma- counts/sec. or of equivalent full indicated Cat-1 PAM per metrics) scale Table 1-6, and to supplement S/R NIS during modes 3-6 operations
c. Startup rate 2 -0.5 to 5.0 +/-10% of the linear Both channels Control Board (NIS) decades/min. full scale analog indicated.

voltage

2. Intermediate Range
a. Flux level 2 10 decades of 9% of the log Both channels Control Board neutron flux arithmic of the full indicated.

(corresponds scale.

to 0 to full scale analog voltage) overlapping the source range by 4 decades (09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 2 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

b. Startup rate 2 -0.5 to 5.0 +/-9 % of the linear Both channels Control Board decades/min. full scale analog indicated.

voltage

3. Power Range
a. Uncalibrate 4 0 to 120% of +/- 1% of full span All 8 current NIS Racks in Meters d ion full power signals indicated. control room NI301(302) chamber current provide a 0 to 5 current (top mA DC current and bottom indication of the uncompens full power level ated ion of the reactor chambers) section monitored.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 3 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

b. Calibrated 4 0-120% of full +/- 2% of full span All 8 current Control Board ion power signals recorded chamber (four 2 pen current 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.

Deleted Per 2015 Update

c. Average 4 0 to 120% of +/-3% of full power All 4 channels Control Board flux of the full power for indication, +/- 2% indicated. Any 2 top and for recording of the four bottom ion channels may be chamber recorded.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 4 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

d. Average 4 0 to 120% of +/- 2% of full power All 4 channels Control Board flux of the full power, 0 to to 120%, +/- 6% of recorded.

top and 200% full full power to 200%.

bottom ion power chambers

e. Flux 4 -30 to +30% +/-4% All 4 channels Control Board difference indicated.

of the top and bottom ion chambers REACTOR COOLANT SYSTEM

1. Taverage 1/Loop 530° - 630°F +/- 4°F All channels Control Board (measured) indicated.
2. T (measured) 1/Loop 0 to 150% of +/- 4% of full power All channels Control Board full power T T indicated. One channel is available on Ovation PCS.
a. Tcold or Thot 1-Thot and 0-700° +/- 4% of span Both channels Control Board (measured, 1-Tcold per recorded.

wide range) loop

3. Overpower T 1/Loop 0 to 150% of +/- 3% of full power All channels Control Board Setpoint full power T T indicated. One channel is selected for recording.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 5 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

4. 1/Loop 0 to 150% of +/- 4% of full power All channels Control Board Overtemperature full power T T indicated. One T Setpoint channel is selected for recording.
5. Pressurizer 4 1700 to 2500 +/- 28 psi All channels Control Board Pressure psig indicated. One channel is recorded.
6. Pressurizer 3 Entire +/- 5% of P signal All channels Control Board Two pen Level distance at 2250 psia indicated. One recorder used, between taps channel is second pen recorded. records reference level signal.
7. Primary Coolant 3/Loop 0 to 120% of Repeatability of All channels Control Board Flow rated flow 4.5% of full flow indicated.
8. Reactor Coolant 1/Loop 0 to 800 +/- 4% All channels Control Board One channel for pump motor amperes indicated. each bus.

amperes

9. System 2 0-3000 psig +/- 3% of full range Both channels Control Board Pressure Wide indicated; one is Range recorded.

REACTOR CONTROL SYSTEM

1. Demanded Rod 1 0 to 100% of +/- 5% The one channel Control Board Speed rated speed is indicated.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 6 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

2. Auctioneered 1 530° to 630°F +/- 3°F The one channel Control Board The highest of Taverage is recorded. 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 Control Board is recorded.
4. Control Rod If system not Position available, borate and sample accordingly.
a. Number of 1/group 0 to 230 steps +/- 1 step Each group is Control Board These signals steps of indicated during are used in demanded rod motion. conjunction with rod the measured withdrawal position signals (4b) to detect deviation of any individual rod from the demanded position. A deviation will actuate an alarm and annunciator.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 7 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

b. Full length 1 for each 0 to 228 steps +/- 3 steps at full Each rod position Control Board rod rod accuracy, +/- 12 is indicated.

measured steps at 1/2 position accuracy CONTAINMENT SYSTEM Containment 4 -5 to 20 PSIG +/- 2.4% of full All 4 channels Control Board Pressure scale indicated, one is recorded FEEDWATER AND STEAM SYSTEMS

1. Auxiliary 1/Feed 0 to 600 gpm 8.8% All channels Control Board One channel to Feedwater Flow line indicated. measure the flow to each steam generator.
2. Steam 4/Steam +5 to -10 feet +/- 4% of P (hot) All channels Control Board Generator level generator from nominal indicated.

(narrow range) full load level One channel per Steam Generator is recorded.

3. Steam 1/Steam +5 to -45 ft +/- 5% of level (cold) All channels Control Board generator level generator from nominal recorded.

(wide range) full load level

4. Programmed 1/Steam 38.9% to 65% +/- 4% All channels Control Board steam generator generator of span recorded.

level signal (09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 8 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

5. Main feedwater 2/Steam 0 to 120% of +/- 5% 2 channels per Control Board flow generator maximum Steam Generator calculated is indicated. One flow channel per Steam Generator is recorded.
6. Magnitude of 1/Main 0 to 100% of +/- 3% All channels Control Board 1. One signal controlling valve opening indicated. channel for main and bypass each main control valves feedwater control valve.
2. OPEN/SHU T indication is provided in the control room for each main and bypass feedwater control valve.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-14 (Page 9 of 9)

No. of Channels Indicated Indicator/

Parameter Available Range Accuracy(1) Recorder Location Notes

7. Steam flow 2/Steam 0 to 117% of +/- 5.5% All channels Control Board Accuracy is generator max. indicated. equipment calculated capability; One channel is are flow however, recorded.

absolute accuracy depends on calibration against feedwater flow.

8. Steam line 3/loop 0 to 1300 psig +/- 4% of full scale All channels Control Board pressure indicated, one is recorded
9. Steam dump 1 0-100% max. +/- 3% The one channel Control Board OPEN/SHUT modulate signal steam dump is indicated. indication is capacity provided in the control room for each steam dump valve.
10. Turbine inlet 3 0 to 1000 PSI +/- 3.5% Two channels Control Board OPEN/SHUT pressure indicated. indication is provided in the control room for each turbine stop valve.

(1)

Includes channel accuracy and environmental effects.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-15 (Page 1 of 3)

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 Fails High None - Signal to discharge damper will None - ESF signal is not inhibited Fan) prevent air flow before blowdown event and redundant signal to Air Return Fan will prevent air flow after blowdown event.

One Pressure Switch (Air Return Fails Low None - This is the fail-safe position of None - Redundant train will operate Fan) the CPCS. and provide air flow One Pressure Switch (Discharge Fails High None - Signal to air return fan will None - ESF signal is not inhibited Damper) prevent air flow One Pressure Switch (Discharge Fails Low None - This is the fail-safe position of None - Redundant train will operate Damper) the CPCS 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 None - Fan will operate prevent air flow Discharge Damper Fails Open None - Signal to fan will prevent air None - This is fail safe condition of flow 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 Fails High None - Signal to discharge valve will None - EST signal is not inhibited Pump) prevent spray (27 MAR 2002)

McGuire Nuclear Station UFSAR Table 7-15 (Page 2 of 3)

Resulting Consequences Component Malfunction Containment Pressure Control Engineered Safety Features One Pressure Switch (Spray Fails Low None - This is safe condition for CPCS None - Redundant train will provide Pump) spray One Pressure Switch (Discharge Fails High None - Signal to spray pump will None - ESF signal is not inhibited Valve) prevent spray One Pressure Switch (Discharge Fails Low None - This is safe condition for CPCS None - Redundant train will provide Valve) spray Valve Fails Open None - Signal to spray pump will None - This is safe condition for prevent spray 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 None - Redundant train will provide prevent spray 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 Fails High None - Fan operates continuously after None - ESF Signal is not inhibited Skimmer Fan & Air Return Fan) initiation One Pressure Switch (H2 Fails Low None - This is the fail safe position of None - Redundant train will operate Skimmer Fan & Air Return Fan) the CPCS 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 None - Fan will operate air flow Inlet Valve Fails Closed None - This is the safe condition of None - The redundant train will CPCS operate and provide air flow (27 MAR 2002)

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

Resulting Consequences Component Malfunction Containment Pressure Control Engineered Safety Features H2 Skimmer Fan Fails to Start None - This is the safe condition of None - The redundant train will CPCS operate and provide air flow One Power Supply Loss None - This is the safe condition of None - The redundant train will CPCS operate and provide air flow (27 MAR 2002)

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

Table 7-16. Ice Condenser RTD's Bay Radial Elev. Above Bay Radial Elev. Above No. Loc. Wear Slab Detail No. Loc. 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 58 FT 6 (3)

Dwg.

23 13 2 30 FT 9 (1) 47 13 See 58 FT 6 (4)

Dwg.

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)

(14 APR 2005)

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

Bay Radial Elev. Above Bay Radial Elev. Above No. Loc. Wear Slab Detail No. Loc. 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 Elev. Above Bay No. Radial Loc. 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)

(14 APR 2005)

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

Bay Radial Elev. Above Bay Radial Elev. Above No. Loc. Wear Slab Detail No. Loc. 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 (14 APR 2005)

McGuire Nuclear Station UFSAR Table 7-17 (Page 1 of 1)

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 1

SGR-AHU-1A X SGR-AHU-2A1 X SGR-AHU-1C1 X SGR-AHU-2C1 X 1

BR-XF-1 X CRA-P-2 X CRA-C-2 X CR-AHU-21 X CRA-AHU-21 X 1

SGR-AHU-1B 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.

(14 OCT 2000)

McGuire Nuclear Station UFSAR Table 7-18 (Page 1 of 1)

Table 7-18. Unit Control System Interlocks Designation Derivation Function C-1 1/2 Neutron flux (intermediate Blocks automatic and manual control range)above setpoint rod withdrawal C-2 1/4 Neutron flux (power range) above Blocks automatic and manual control setpoint 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 Defeats remote load dispatching setpoint Blocks automatic control rod withdrawal C-7A 1/1 Time derivative (absolute value) of Makes steam dump valves available for turbine inlet pressure (decrease only) either tripping or modulation above setpoint C-9 Any condenser pressure above setpoint, Blocks steam dump to condenser or any 3 out of 4 circulation water pump breakers open C-11 1/1 Bank D control rod position above Blocks automatic rod withdrawal setpoint (30 NOV 2012)

McGuire Nuclear Station UFSAR Table 7-19 (Page 1 of 2)

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 Filter Time Thot and Tavg input Pressurizer Flux imbalance RTD time Constant Tcold input to setpoint pressure input input to set point constant to DT to set point

a. 3.5 sec 4.7 sec 2.606 sec 1.863 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 1.500 sec 1.500 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 Filter time Thot and Tcold Tavg input to Flux imbalance constant Constant input to DT setpoint input to set point

a. 3.5 sec 4.7 sec 2.606 sec
b. 4.0 sec 4.25 sec 2.488 sec 1.500 sec 1.500 sec (Note 2)
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.

(24 APR 2014)

McGuire Nuclear Station UFSAR Table 7-19 (Page 2 of 2)

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.

(24 APR 2014)

McGuire Nuclear Station UFSAR Table 7-20 (Page 1 of 3)

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.

(09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-20 (Page 2 of 3)

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 19 Supply Automatic Realignment
12. RWST Level Automatic Switchover to Recirculation 100
13. Blackout
a. Start Motor-Driven Auxiliary Feedwater 60 Pumps
b. Start Turbine-Driven Auxiliary Feedwater 60 Pump(6)
14. Trip of Main Feedwater Pumps Start Motor-Driven Auxiliary Feedwater 60 (09 OCT 2015)

McGuire Nuclear Station UFSAR Table 7-20 (Page 3 of 3)

Initiating signal and Function Response Time In Seconds Pumps

15. Loss of Power
a. 4 kV Loss of Voltage 11
b. 4 kV Degraded Voltage 11 with SI, and 600 without SI Note:

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.

(09 OCT 2015)

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