ML18100A116

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Attachment to Amendment No. 137 - Vogtle Electric Generating Plant Unit 4 LAR 17-024
ML18100A116
Person / Time
Site: Vogtle Southern Nuclear icon.png
Issue date: 08/23/2018
From:
NRC/NRO/DLSE/LB4
To:
Southern Nuclear Operating Co
gleaves w/415-5848
Shared Package
ML18100A110 List:
References
EPID L-2017-LLA-0127, LAR-17-024
Download: ML18100A116 (16)
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Text

ATTACHMENT TO LICENSE AMENDMENT NO. 137 TO FACILITY COMBINED LICENSE NO. NPF-92 DOCKET NO.52-026 Replace the following pages of the Facility Combined License No. NPF-92 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-92 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 hours1 days <br />0.143 weeks <br />0.0329 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. 137, 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. 137

Technical Specifications Definitions 1.1 1.1 Definitions REACTOR TRIP SYSTEM The RTS RESPONSE TIME shall be that time interval from (RTS) RESPONSE TIME 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.

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

Amendment No. 137 (Unit 4)

Technical Specifications Rod Group Alignment Limits 3.1.4 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) A.1.1 Verify SDM to be within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable. limits specified in the COLR.

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

AND A.2 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> B. One rod not within B.1 Restore rod to within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> with the alignment limits. alignment limits. On-Line Power Distribution Monitoring System not monitoring parameters AND 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> OR VEGP Units 3 and 4 3.1.4 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2.1.1 Verify SDM to be within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits specified in the COLR.

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

AND B.2.2 Reduce THERMAL 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> POWER to 75% RTP.

AND B.2.3.1 Perform SR 3.2.5.1. Once per 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> OR B.2.3.2.1 Verify SDM is within the Once per 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> limits specified in the COLR.

AND B.2.3.2.2 Perform SR 3.2.1.1 and 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> SR 3.2.1.2.

AND B.2.3.2.3 Perform SR 3.2.2.1. 72 hours3 days <br />0.429 weeks <br />0.0986 months <br /> AND B.2.4 Re-evaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

VEGP Units 3 and 4 3.1.4 - 2 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> associated Completion Time of Condition B not met.

D. More than one rod not D.1.1 Verify SDM is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> within alignment limit. limits specified in the COLR.

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

AND D.2 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 ----------------------------------------------------------------------- 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br />

- 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.

SR 3.1.4.2 Verify rod freedom of movement (trippability) by 92 days moving each RCCA not fully inserted in the core 10 steps in either direction.

VEGP Units 3 and 4 3.1.4 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.4.3 Verify rod drop time of each RCCA, from the fully Once prior to withdrawn position, is 2.7 seconds from the reactor criticality beginning of decay of stationary gripper coil voltage to after each removal dashpot entry, with: of the reactor head, and after

a. Tavg 500°F, and each earthquake requiring plant
b. All reactor coolant pumps operating. shutdown VEGP Units 3 and 4 3.1.4 - 4 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Control Bank Insertion Limits 3.1.6 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 A.1.1 Verify SDM is within the 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> limits not met. limits specified in the COLR.

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

AND A.2 Restore control bank(s) to 2 hours0.0833 days <br />0.0119 weeks <br />0.00274 months <br /> within insertion limits.

VEGP Units 3 and 4 3.1.6 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Rod Position Indication 3.1.7 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 A.1 Verify the position of the Once per 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> inoperable in one or rods with inoperable DRPI more groups. indirectly by using the incore detectors.

OR A.2 Reduce THERMAL 8 hours0.333 days <br />0.0476 weeks <br />0.011 months <br /> POWER to 50% RTP.

B. More than one DRPI B.1 Place the control rods Immediately per group inoperable in under manual control.

one or more groups.

AND B.2 Restore inoperable 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> DRPI(s) to OPERABLE status such that a maximum of one DRPI per group is inoperable.

VEGP Units 3 and 4 3.1.7 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 2)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS 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 1,2 4 D SR 3.3.1.6 Positive Rate 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.

VEGP Units 3 and 4 3.3.1 - 6 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 2)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE FUNCTION CONDITIONS CHANNELS CONDITIONS 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) 1,2 4 per RCP D SR 3.3.1.1 Bearing Water Temperature - SR 3.3.1.6 High 2 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 1,2 4 per SG D SR 3.3.1.1 Range Water Level - Low 2 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11
11. Steam Generator (SG) Narrow 1,2(c) 4 per SG D SR 3.3.1.1 Range Water Level - High 3 SR 3.3.1.6 SR 3.3.1.8 SR 3.3.1.11
12. Passive Residual Heat Removal 1,2 4 per valve D SR 3.3.1.10 Actuation SR 3.3.1.11 (b) Above the P-10 (Power Range Neutron Flux) interlock.

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

VEGP Units 3 and 4 3.3.1 - 7 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications RTS Manual Actuation 3.3.5 Table 3.3.5-1 (page 1 of 1)

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

1. Manual Reactor Trip 1,2,3(a),4(a),5(a) 2
2. Safeguards Actuation Input from Engineered 1,2 2 Safety Feature Actuation System - Manual
3. ADS Stages 1, 2, and 3 Actuation Input from 1,2,3(a),4(a),5(a) 2 switch sets Engineered Safety Feature Actuation System -

Manual

4. Core Makeup Tank Actuation Input from 1,2,3(a),4(a),5(a) 2 Engineered Safety Feature Actuation System -

Manual (a) With Plant Control System capable of rod withdrawal or one or more rods not fully inserted.

VEGP Units 3 and 4 3.3.5 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications PAM Instrumentation 3.3.17 Table 3.3.17-1 (page 1 of 1)

Post-Accident Monitoring Instrumentation CONDITION REFERENCED REQUIRED FROM REQUIRED FUNCTION CHANNELS 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) 2 E Wide Range Water Level
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 (a)
15. Core Exit Temperature -- Quadrant 3 2 E (a)
16. Core Exit Temperature -- Quadrant 4 2 E
17. Passive Containment Cooling System (PCS) Heat Removal 2 E
18. Penetration Flow Path Remotely Operated Containment Isolation Valve 2 per penetration E Position flow path(b)(c)(d)
19. IRWST to Normal Residual Heat Removal System (RNS) Suction Valve 2 E Status
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).

VEGP Units 3 and 4 3.3.17 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications DAS Manual Controls 3.3.19 Table 3.3.19-1 (page 1 of 1)

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

1. Reactor trip manual controls 1,2 2 switches
2. Passive Residual Heat Removal Heat 1,2,3,4,5(a) 2 switches Exchanger (PRHR HX) control and In-Containment Refueling Water Storage Tank (IRWST) gutter control valves
3. Core Makeup Tank (CMT) isolation valves 1,2,3,4,5(a) 2 switches
4. Automatic Depressurization System (ADS) 1,2,3,4,5(a) 2 switches stage 1 valves
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.

VEGP Units 3 and 4 3.3.19 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications PRHR HX - Operating 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 Verify the PRHR HX outlet manual isolation valve is 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> fully open.

SR 3.5.4.2 Verify the PRHR HX inlet motor operated isolation 12 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> valve is open.

SR 3.5.4.3 Verify the volume of noncondensible gases in the 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> PRHR HX inlet line has not caused the high-point water level to drop below the sensor.

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 hours0.5 days <br />0.0714 weeks <br />0.0164 months <br /> SR 3.5.4.5 Verify power is removed from the PRHR HX inlet 31 days motor operated isolation valve.

SR 3.5.4.6 Verify both PRHR HX air operated outlet isolation In accordance with valves stroke open and both IRWST gutter isolation the Inservice valves stroke closed. Testing Program SR 3.5.4.7 Verify by visual inspection that the IRWST gutter and 24 months downspout screens are not restricted by debris.

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

SR 3.5.4.9 Verify PRHR HX heat transfer performance in 10 years accordance with the System Level OPERABILITY Testing Program.

VEGP Units 3 and 4 3.5.4 - 3 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

Technical Specifications Inverters - Operating 3.8.3 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 hours3 days <br />0.429 weeks <br />0.0986 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) A.1 ------------------------------------

within one division - NOTE -

inoperable. 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 24 hours1 days <br />0.143 weeks <br />0.0329 months <br /> OPERABLE status.

B. Required Action B.1 Be in MODE 3. 6 hours0.25 days <br />0.0357 weeks <br />0.00822 months <br /> and associated Completion Time AND not met.

B.2 Be in MODE 5. 36 hours1.5 days <br />0.214 weeks <br />0.0493 months <br /> VEGP Units 3 and 4 3.8.3 - 1 Amendment No. 138 (Unit 3)

Amendment No. 137 (Unit 4)

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