ML18100A114

Attachment to Amendment No. 138 - Vogtle Electric Generating Plant Unit 3 LAR 17-024

ML18100A114
Person / Time
Site:	Vogtle
Issue date:	08/23/2018
From:	NRC/NRO/DLSE/LB4
To:	Southern Nuclear Operating Co
gleaves b/415-5848
Shared Package
ML18100A110	List: ML18100A111 ML18100A113 ML18100A114 ML18100A115 ML18100A116 ML18100A117
References
EPID L-2017-LLA-0127, LAR 17-024
Download: ML18100A114 (16)

Text

ATTACHMENT TO LICENSE AMENDMENT NO. 138 TO FACILITY COMBINED LICENSE NO. NPF-91 DOCKET NO.52-025 Replace the following pages of the Facility Combined License No. NPF-91 with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Facility Combined License No. NPF-91 REMOVE INSERT 7

7 Appendix A to Facility Combined License Nos. NPF-91 and NPF-92 REMOVE INSERT 1.1-5 1.1-5 3.1.4-1 3.1.4-1 3.1.4-2 3.1.4-2 3.1.4-3 3.1.4-3 3.1.4-4 3.1.4-4 3.1.6-1 3.1.6-1 3.1.7-1 3.1.7-1 3.3.1-6 3.3.1-6 3.3.1-7 3.3.1-7 3.3.5-3 3.3.5-3 3.3.17-3 3.3.17-3 3.3.19-3 3.3.19-3 3.5.4-3 3.5.4-3 3.8.3-1 3.8.3-1

(7) Reporting Requirements (a)

Within 30 days of a change to the initial test program described in UFSAR Section 14, Initial Test Program, made in accordance with 10 CFR 50.59 or in accordance with 10 CFR Part 52, Appendix D, Section VIII, Processes for Changes and Departures, SNC shall report the change to the Director of NRO, or the Directors designee, in accordance with 10 CFR 50.59(d).

(b)

SNC shall report any violation of a requirement in Section 2.D.(3),

Section 2.D.(4), Section 2.D.(5), and Section 2.D.(6) of this license within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />. Initial notification shall be made to the NRC Operations Center in accordance with 10 CFR 50.72, with written follow up in accordance with 10 CFR 50.73.

(8) Incorporation The Technical Specifications, Environmental Protection Plan, and ITAAC in Appendices A, B, and C, respectively of this license, as revised through Amendment No. 138, are hereby incorporated into this license.

(9) Technical Specifications The technical specifications in Appendix A to this license become effective upon a Commission finding that the acceptance criteria in this license (ITAAC) are met in accordance with 10 CFR 52.103(g).

(10) Operational Program Implementation SNC shall implement the programs or portions of programs identified below, on or before the date SNC achieves the following milestones:

(a)

Environmental Qualification Program implemented before initial fuel load; (b)

Reactor Vessel Material Surveillance Program implemented before initial criticality; (c)

Preservice Testing Program implemented before initial fuel load; (d)

Containment Leakage Rate Testing Program implemented before initial fuel load; (e)

Fire Protection Program

1.

The fire protection measures in accordance with Regulatory Guide (RG) 1.189 for designated storage building areas (including adjacent fire areas that could affect the storage area) implemented before initial receipt 7

Amendment No. 138

Technical Specifications Definitions 1.1 VEGP Units 3 and 4 1.1 - 5 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4) 1.1 Definitions REACTOR TRIP SYSTEM (RTS) RESPONSE TIME The RTS RESPONSE TIME shall be that time interval from when the monitored parameter exceeds its RTS trip setpoint at the channel sensor until loss of gripper coils voltage. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

SHUTDOWN MARGIN (SDM)

SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a.

All rod cluster control assemblies (RCCAs) are fully inserted except for the single assembly of highest reactivity worth, which is assumed to be fully withdrawn.

However, with all RCCAs verified fully inserted by two independent means, it is not necessary to account for a stuck RCCA in the SDM calculation. With any RCCAs not capable of being fully inserted, the reactivity worth of these assemblies must be accounted for in the determination of SDM; and

b.

In MODES 1 and 2, the fuel and moderator temperatures are changed to the nominal zero power design level.

In MODE 2 with keff < 1.0, and MODES 3, 4, and 5, the worth of verified fully inserted Gray Rod Cluster Assemblies (GRCAs) which have passed the acceptance criteria for GRCA bank worth measurements performed during startup physics testing may be included in the SDM calculation.

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function.

THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

Technical Specifications Rod Group Alignment Limits 3.1.4 VEGP Units 3 and 4 3.1.4 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4) 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 Each rod cluster control assembly (RCCA) shall be OPERABLE.

AND Individual indicated rod positions of each RCCA and Gray Rod Cluster Assembly shall be within 12 steps of their group step counter demand position.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more RCCA(s) inoperable.

A.1.1 Verify SDM to be within the limits specified in the COLR.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR A.1.2 Initiate boration to restore SDM within limit.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND A.2 Be in MODE 3.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> B.

One rod not within alignment limits.

B.1 Restore rod to within alignment limits.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with the On-Line Power Distribution Monitoring System not monitoring parameters AND 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> OR

Technical Specifications Rod Group Alignment Limits 3.1.4 VEGP Units 3 and 4 3.1.4 - 2 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.2.1.1 Verify SDM to be within the limits specified in the COLR.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR B.2.1.2 Initiate boration to restore SDM within limit.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND B.2.2 Reduce THERMAL POWER to 75% RTP.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> AND B.2.3.1 Perform SR 3.2.5.1.

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR B.2.3.2.1 Verify SDM is within the limits specified in the COLR.

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> AND B.2.3.2.2 Perform SR 3.2.1.1 and SR 3.2.1.2.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND B.2.3.2.3 Perform SR 3.2.2.1.

72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND B.2.4 Re-evaluate safety analyses and confirm results remain valid for duration of operation under these conditions.

5 days

Technical Specifications Rod Group Alignment Limits 3.1.4 VEGP Units 3 and 4 3.1.4 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C.

Required Action and associated Completion Time of Condition B not met.

C.1 Be in MODE 3.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> D.

More than one rod not within alignment limit.

D.1.1 Verify SDM is within the limits specified in the COLR.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR D.1.2 Initiate boration to restore required SDM to within limit.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND D.2 Be in MODE 3.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1

- NOTE -

Not required to be performed for rods associated with inoperable digital rod position indication or demand position indication.

Verify individual rod positions within alignment limit.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.1.4.2 Verify rod freedom of movement (trippability) by moving each RCCA not fully inserted in the core 10 steps in either direction.

92 days

Technical Specifications Rod Group Alignment Limits 3.1.4 VEGP Units 3 and 4 3.1.4 - 4 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.4.3 Verify rod drop time of each RCCA, from the fully withdrawn position, is 2.7 seconds from the beginning of decay of stationary gripper coil voltage to dashpot entry, with:

a.

Tavg 500°F, and

b.

All reactor coolant pumps operating.

Once prior to reactor criticality after each removal of the reactor head, and after each earthquake requiring plant shutdown

Technical Specifications Control Bank Insertion Limits 3.1.6 VEGP Units 3 and 4 3.1.6 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4) 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence, and overlap limits specified in the COLR.

APPLICABILITY:

MODE 1.

MODE 2 with keff 1.0.

- NOTES -

1.

This LCO is not applicable while performing SR 3.1.4.2.

2.

This LCO is not applicable to Gray Rod Cluster Assembly (GRCA) banks for up to one hour during GRCA bank sequence exchange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Control Bank insertion limits not met.

A.1.1 Verify SDM is within the limits specified in the COLR.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR A.1.2 Initiate boration to restore SDM to within limits.

1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> AND A.2 Restore control bank(s) to within insertion limits.

2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />

Technical Specifications Rod Position Indication 3.1.7 VEGP Units 3 and 4 3.1.7 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4) 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1.7 The Digital Rod Position Indication (DRPI) for each control rod and the Bank Demand Position Indication for each group shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS

- NOTE -

Separate Condition entry is allowed for each inoperable DRPI and each demand position indication.

CONDITION REQUIRED ACTION COMPLETION TIME A.

One DRPI per group inoperable in one or more groups.

A.1 Verify the position of the rods with inoperable DRPI indirectly by using the incore detectors.

Once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> OR A.2 Reduce THERMAL POWER to 50% RTP.

8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> B.

More than one DRPI per group inoperable in one or more groups.

B.1 Place the control rods under manual control.

Immediately AND B.2 Restore inoperable DRPI(s) to OPERABLE status such that a maximum of one DRPI per group is inoperable.

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />

Technical Specifications RTS Instrumentation 3.3.1 VEGP Units 3 and 4 3.3.1 - 6 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Table 3.3.1-1 (page 1 of 2)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS

1. Power Range Neutron Flux

a. High Setpoint 1,2 4

D SR 3.3.1.1 SR 3.3.1.2 SR 3.3.1.6 SR 3.3.1.9 SR 3.3.1.11

b. Low Setpoint 1(a),2 4

D SR 3.3.1.1 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.11

2. Power Range Neutron Flux High Positive Rate 1,2 4

D SR 3.3.1.6 SR 3.3.1.9 SR 3.3.1.11

3. Overtemperature T 1,2 4 (2/loop)

D SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

4. Overpower T 1,2 4 (2/loop)

D SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

5. Pressurizer Pressure

a. Low 2 Setpoint 1(b) 4 E

SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

b. High 2 Setpoint 1,2 4

D SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

6. Pressurizer Water Level - High 3 1(b) 4 E

SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11 (a) Below the P-10 (Power Range Neutron Flux) interlocks.

(b) Above the P-10 (Power Range Neutron Flux) interlock.

Technical Specifications RTS Instrumentation 3.3.1 VEGP Units 3 and 4 3.3.1 - 7 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Table 3.3.1-1 (page 2 of 2)

Reactor Trip System Instrumentation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS CONDITIONS SURVEILLANCE REQUIREMENTS

7. Reactor Coolant Flow - Low 2 1(b) 4 per hot leg E

SR 3.3.1.1 SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

8. Reactor Coolant Pump (RCP)

Bearing Water Temperature -

High 2 1,2 4 per RCP D

SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

9. RCP Speed - Low 2 1(b) 4 (1/pump)

E SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

10. Steam Generator (SG) Narrow Range Water Level - Low 2 1,2 4 per SG D

SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

11. Steam Generator (SG) Narrow Range Water Level - High 3 1,2(c) 4 per SG D

SR 3.3.1.1 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11

12. Passive Residual Heat Removal Actuation 1,2 4 per valve D

SR 3.3.1.10 SR 3.3.1.11 (b) Above the P-10 (Power Range Neutron Flux) interlock.

(c) Above the P-11 (Pressurizer Pressure) interlock.

Technical Specifications RTS Manual Actuation 3.3.5 VEGP Units 3 and 4 3.3.5 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Table 3.3.5-1 (page 1 of 1)

Reactor Trip System Manual Actuation FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CHANNELS

1. Manual Reactor Trip 1,2,3(a),4(a),5(a) 2

2. Safeguards Actuation Input from Engineered Safety Feature Actuation System - Manual 1,2 2

3. ADS Stages 1, 2, and 3 Actuation Input from Engineered Safety Feature Actuation System -

Manual 1,2,3(a),4(a),5(a) 2 switch sets

4. Core Makeup Tank Actuation Input from Engineered Safety Feature Actuation System -

Manual 1,2,3(a),4(a),5(a) 2 (a) With Plant Control System capable of rod withdrawal or one or more rods not fully inserted.

Technical Specifications PAM Instrumentation 3.3.17 VEGP Units 3 and 4 3.3.17 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Table 3.3.17-1 (page 1 of 1)

Post-Accident Monitoring Instrumentation FUNCTION REQUIRED CHANNELS CONDITION REFERENCED FROM REQUIRED ACTION D.1

1.

Neutron Flux (Intermediate Range) 2 E

2.

Reactor Coolant System (RCS) Hot Leg Temperature (Wide Range) 2 E

3.

RCS Cold Leg Temperature (Wide Range) 2 E

4.

RCS Pressure (Wide Range) 2 E

5.

RCS Subcooling 2

E

6.

Containment Water Level 2

E

7.

Containment Pressure 2

E

8.

Containment Pressure (Extended Range) 2 E

9.

Containment Area Radiation (High Range) 2 E

10.

Pressurizer Level and Associated Reference Leg Temperature 2

E

11.

In-Containment Refueling Water Storage Tank (IRWST)

Wide Range Water Level 2

E

12.

Passive Residual Heat Removal (PRHR) Heat Removal 2

E

13.

Core Exit Temperature -- Quadrant 1 2(a)

E

14.

Core Exit Temperature -- Quadrant 2 2(a)

E

15.

Core Exit Temperature -- Quadrant 3 2(a)

E

16.

Core Exit Temperature -- Quadrant 4 2(a)

E

17.

Passive Containment Cooling System (PCS) Heat Removal 2

E

18.

Penetration Flow Path Remotely Operated Containment Isolation Valve Position 2 per penetration flow path(b)(c)(d)

E

19.

IRWST to Normal Residual Heat Removal System (RNS) Suction Valve Status 2

E

20.

Pressurizer Pressure 2

E (a) A channel consists of two thermocouples within a single division. Each quadrant contains two divisions. The minimum requirement is two OPERABLE thermocouples in each of the two divisions.

(b) Not required for isolation valves whose associated penetration is isolated by at least one closed and deactivated automatic valve, closed manual valve, blind flange, or check valve with flow through the valve secured.

(c) Only one position indication channel is required for penetration flow paths with only one installed control room indication channel.

(d) Penetration Flow Path Remotely Operated Containment Isolation Valve Position applies to components that receive the ESF containment isolation signal (T signal).

Technical Specifications DAS Manual Controls 3.3.19 VEGP Units 3 and 4 3.3.19 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Table 3.3.19-1 (page 1 of 1)

DAS Manual Controls FUNCTION APPLICABLE MODES OR OTHER SPECIFIED CONDITIONS REQUIRED CONTROLS

1.

Reactor trip manual controls 1,2 2 switches

2.

Passive Residual Heat Removal Heat Exchanger (PRHR HX) control and In-Containment Refueling Water Storage Tank (IRWST) gutter control valves 1,2,3,4,5(a) 2 switches

3.

Core Makeup Tank (CMT) isolation valves 1,2,3,4,5(a) 2 switches

4.

Automatic Depressurization System (ADS) stage 1 valves 1,2,3,4,5(a) 2 switches

5.

ADS stage 2 valves 1,2,3,4,5(a) 2 switches

6.

ADS stage 3 valves 1,2,3,4,5(a) 2 switches

7.

ADS stage 4 valves 1,2,3,4,5,6(c) 2 switches

8.

IRWST injection squib valves 1,2,3,4,5,6 2 switches

9.

Containment recirculation valves 1,2,3,4,5,6 2 switches

10.

Passive containment cooling drain valves 1,2,3,4,5(b),6(b) 2 switches

11.

Selected containment isolation valves 1,2,3,4,5,6 2 switches (a) With Reactor Coolant System (RCS) pressure boundary intact.

(b) With the reactor decay heat > 7.0 MWt.

(c) With upper internals in place.

Technical Specifications PRHR HX - Operating 3.5.4 VEGP Units 3 and 4 3.5.4 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify the PRHR HX outlet manual isolation valve is fully open.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.5.4.2 Verify the PRHR HX inlet motor operated isolation valve is open.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.5.4.3 Verify the volume of noncondensible gases in the PRHR HX inlet line has not caused the high-point water level to drop below the sensor.

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> SR 3.5.4.4

- NOTE -

Only required to be met when one or more reactor coolant pumps (RCPs) are in operation.

Verify one Loop 1 RCP is in operation.

12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SR 3.5.4.5 Verify power is removed from the PRHR HX inlet motor operated isolation valve.

31 days SR 3.5.4.6 Verify both PRHR HX air operated outlet isolation valves stroke open and both IRWST gutter isolation valves stroke closed.

In accordance with the Inservice Testing Program SR 3.5.4.7 Verify by visual inspection that the IRWST gutter and downspout screens are not restricted by debris.

24 months SR 3.5.4.8 Verify both PRHR HX air operated outlet isolation valves actuate to the open position and both IRWST gutter isolation valves actuate to the isolation position on an actual or simulated actuation signal.

24 months SR 3.5.4.9 Verify PRHR HX heat transfer performance in accordance with the System Level OPERABILITY Testing Program.

10 years

Technical Specifications Inverters - Operating 3.8.3 VEGP Units 3 and 4 3.8.3 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4) 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Inverters - Operating LCO 3.8.3 The Division A, B, C, and D inverters shall be OPERABLE.

- NOTES -

One inverter may be disconnected from its associated DC bus for 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to perform an equalizing charge on its associated battery, providing:

1.

The associated instrument and control bus is energized from its Class 1E constant voltage source transformer; and

2.

All other AC instrument and control buses are energized from their associated OPERABLE inverters.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One or two inverter(s) within one division inoperable.

A.1

- NOTE -

Enter applicable Conditions and Required Actions of LCO 3.8.5 Distribution Systems -

Operating with any instrument and control bus de-energized.

Restore inverter(s) to OPERABLE status.

24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B.

Required Action and associated Completion Time not met.

B.1 AND B.2 Be in MODE 3.

Be in MODE 5.

6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> 36 hours