Text

Issuance of Renewed Facility Operating License No NPF-68 and NPF-81 for the Vogtle Electronic Generating Plant, Units 1 and 2
	ML090920437
Person / Time
Site:	Vogtle
Issue date:	06/03/2009
From:	Ashley D; License Renewal Projects Branch 1
To:	Tynan T; Southern Nuclear Operating Co
	Ashley, D J, NRR/DLR/RPB1, 415-3191
References
	Download: ML090920437 (410)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 June 3, 2009 Mr. Tom E. Tynan Vice President - Vogtle Southern Nuclear Operating Company, Inc.

7821 River Road Waynesboro, GA 30830 SUB~IECT: ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NO t\lPF-68 AND NPF-81 FOR THE VOGTLE ELECTRIC GENERATING PLANT, UNITS 1 AND 2

Dear Mr. Tynan:

The U.S. Nuclear Regulatory Commission (NRC) has issued the Renewed Facility Operating License Nos. NPF-68 and NPF-81 for the Vogtle Electric Generating Plant (VEGP), Units 1 and 2. The NRC issued the renewed facility operating licenses based on the NRC staffs review of your application dated June 27, 2007, as supplemented by letters submitted to the NRC through February 16, 2009. Our review did not require amending the technical specifications.

The NRC sets forth the technical basis for issuing the renewed license in NUREG-1920, "Safety Evaluation Report Related to the License Renewal of the Vogtle Electric Generating Plant, Units 1 and 2," Volumes 1 and 2, issued April 2009. The results of the environmental reviews related to this license renewal appear in NUREG-1437, "Generic Environmental Impact Statement for License Renewal of Nuclear Plants," Supplement 34, "Vogtle Electric Generating Plant, Units 1 and 2," issued December 2008.

Renewed Facility Operating License No. NPF-68 for VEGP Unit 1 expires at midnight January 16, 2047.

Renewed Facility Operating License No. NPF-81 for VEGP Unit 2 expires at midnight February 9, 2049. contains the Renewed Facility Operating License No. NPF-68, Renewed Facility Operating License No. NPF-81 and attachments, Appendix A-"Technical Specifications,"

Appendix B-"Environmental Protection Plan," and Appendix C-"Antitrust Conditions."

1. Tynan -2 is a copy of the related Federal Register notice of issuance of the renewed license.

The original has been sent to the Office of the Federal Register for publication. If you have any questions regarding this issue, please feel free to contact me at 301-415-3191 or by email at donnie.ashley@nrc.gov.

Sincerely, r4J~

Donnie J. A hie , Sr. Project Mana Projects Bra, ch .

Division of License Renewal Office of Nuclear Reactor Regulation Docket Nos. 50-424 and 50-425

Enclosures:

1. Renewed Facility Operating Licenses

2. Federal Register Notice cc: Distribution via Listserv

SOUTHERN NUCLEAR OPERATING COMPANY. INC.

GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON. GEORGIA DOCKET NO. 50-424 VOGTLE ELECTRIC GENERATING PLANT. UNIT 1 RENEWED FACILITY OPERATING LICENSE Renewed License No. NPF-68

1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that:

A. The application for renewal of the license filed by the Southern Nuclear Operating Company, Inc. acting for itself. Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton. Georgia (the Owners), complies with the standards and requirements of the Atomic Energy Act of 1954. as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; and all required notifications to other agencies or bodies have been dUly made; B. Construction of the Vogtle Electric Generating Plant, Unit 1 (the facility) has been substantially completed in conformity with Construction Permit No. CPPR-108 and the application, as amended, the provisions of the of the Act and the regulations of the Commission; C. Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21 (a)(1); and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21(c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the facility, and that any changes made to the facility's current licensing basis in order to comply with 10 CFR 54.29(a) are in accordance with the Act and the Commission's regulations; D. The facility will operate in conformity with the application. as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.D below);

Renewed Operating License No. NPF-68

-2 E. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I (except as exempted from compliance in Section 2.0. below);

F. Southern Nuclear Operating Company, Inc: (herein called Southern Nuclear) is technically qualified and, together, Southern Nuclear and the Owners are financially qualified to engage in the activities authorized by this license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; G. The Owners have satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; H. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; I. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Renewed Facility Operating License No. NPF-68, subject to the conditions for protection of the environment set forth in the Environmental Protection Plan attached as Appendix B, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; J. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70.

2. Based on the foregoing findings and the Partial Initial Decision and the Concluding Partial Initial Decision issued by the Atomic Safety and Licensing Board on August 27 and December 23, 1986, respectively, regarding this facility and satisfaction of conditions therein imposed, and pursuant to approval by the Nuclear Regulatory Commission at a meeting held on March 12, 1987, Facility Operating License No. NPF-61, issued on January 16, 1987, is superseded by Facility Operating License No. NPF-68, hereby issued to Southern Nuclear, Georgia Power Company (GPC), Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the licensees) to read as follows:

A. This license applies to the Vogtle Electric Generating Plant, Unit 1, a pressurized water reactor and associated equipment (the facility) owned by GPC, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, and operated by Southern Nuclear. The facility is located in Burke

Southern Nuclear succeeds Georgia Power Company as the operator of Vogtle Electric Generating Plant, Unit 1. Southern Nuclear is authorized by the Owners to exercise exclusive responsibility and control over the physical construction, operation, and maintenance of the facility.

Renewed Operating License No. NPF-68

-3 County, Georgia, on the west bank of the Savannah River approximately 25 miles south of Augusta, Georgia, and is described in the Final Safety Analysis Report, as supplemented and amended, and in the Environmental Report, as supplemented and amended; B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Southern Nuclear, pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, manage, use, maintain, and operate the facility at the designated location in Burke County, Georgia, in accordance with the procedures and limitations set forth in this license; (2) Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, pursuant to the Act and 10 CFR Part 50, to possess but not operate the facility at the designated location in Burke County, Georgia, in accordance with the procedures and limitations set forth in this license; (3) Southern Nuclear, pursuant to the Act and 10 CFR Part 70, to receive, possess, and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30,40, and 70 to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (5) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; (6) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility authorized herein.

C. This license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect, and is subject to the additional conditions specified or incorporated below.

Renewed Operating License No. NPF-68

- 4 (1) Maximum Power Level Southern Nuclear is authorized to operate the facility at reactor core power levels not in excess of 3625.6 megawatts thermal (100 percent power) in accordance with the conditions specified herein.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 155 and the Environmental Protection Plan contained in Appendix 8, both of which are attached hereto, are hereby incorporated into this license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3) Southern Nuclear Operating Company shall be capable of establishing containment hydrogen monitoring within 90 minutes of initiating safety injection following a loss of coolant accident.

(4) Deleted (5) Deleted (6) Deleted (7) Deleted (8) Deleted (9) Deleted (10) Mitigation Strategy License Condition The licensee shall develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy Renewed Operating License No. (\JPF-68

-5

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (11) Additional Conditions The Additional Conditions contained in Appendix D, as revised through Amendment No. 154, are hereby incorporated into this license. Southern Nuclear shall operate the facility in accordance with the Additional Conditions.

D. The facility requires exemptions from certain requirements of 10 CFR Part 50 and 10 CFR Part 70. These include (a) an exemption from the requirements of 10 CFR 70.24 for two criticality monitors around the fuel storage area, and (b) an exemption from the requirements of Paragraph III.D.2(b)(ii) of Appendix J of 10 CFR 50, the testing of containment air locks at times when containment integrity is not required.

The special circumstances regarding exemption b are identified in Section 6.2.6 of SSER 5.

An exemption was previously granted pursuant to 10 CFR 70.24. The exemption was granted with NRC materials license No. SNM-1967, issued August 21, 1986, and relieved GPC from the requirement of having a criticality alarm system. GPC and Southern Nuclear are hereby exempted from the criticality alarm system provision of 10 CFR 70.24 so far as this section applies to the storage of fuel assemblies held under this license.

These exemptions are authorized by law, will not present an undue risk to the public health and safety, and are consistent with the common defense and security. The exemptions in item band c above are granted pursuant to 10 CFR 50.12. With these exemptions, the facility will operate, to the extent authorized herein, in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission.

E. Southern Nuclear shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p).

The plan, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Southern Nuclear Operating Company Security Plan, Training and Qualification Plan, and Safeguards Contingency Plan," with revisions submitted through May 15, 2006.

F. GPC shall comply with the antitrust conditions delineated in Appendix C to this license.

Renewed Operating License No. NPF-68

-6 G. Southern Nuclear shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility, and submittals dated July 2, August 4 and 13, October 10 and 24, November 5, and December 19, 1986, and January 2, 1987, as approved in the SER (NUREG-1137) through Supplement 5 subject to the following provision:

Southern Nuclear may make changes to the approved fire protection program without prior approval of the Commission, only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

H. Deleted.

I. The Owners shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

J. The Updated Safety Analysis Report supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), shall be included in the next scheduled update to the Updated Safety Analysis Report required by 10 CFR 50.71 (e)(4) following the issuance of this renewed operating license. Until that update is complete, Southern Nuclear may make changes to the programs and activities described in the supplement without prior Commission approval, provided that Southern Nuclear evaluates such changes pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

K. The Updated Safety Analysis Report supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), describes certain future activities to be completed prior to the period of extended operation. Southern Nuclear shall complete these activities no later than January 16, 2027, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.

L. All capsules in the reactor vessel that are removed and tested must meet the test procedures and reporting requirements of American Society for Testing and Materials (ASTM) E 185-82 to the extent practicable for the configuration of the specimens in the capsule. Any changes to the capsule withdrawal schedule, including spare capsules, must be approved by the NRC prior to implementation. All capsules placed in storage must be maintained for future insertion. Any changes to storage requirements must be approved by the NRC, as required by 10 CFR Part 50, Appendix H.

Renewed Operating License No. NPF-68

-7 M. This license is effective as of the date of issuance and shall expire at midnight on January 16, 2047.

FOR THE NUCLEAR REGULATORY COMMISSION cC/~J Eric J. Leeds, Director Office of Nuclear Reactor Regulation

Enclosures:

1. Attachment 1 - DELETED

2. Appendix A - Technical Specifications

3. Appendix B - Environmental Protection Plan

4. Appendix C - Antitrust Conditions

5. Appendix D- Additional Conditions Date of Issuance: June 3, 2009 Renewed Operating License No. NPF-68

ATTACHMENT 1 TO LICENSE NPF-61 TDI DIESEL ENGINE REQUIREMENTS (DELETED)

Amendment No. 81

Technical Specifications Vogtle Electric Generating Plant Unit Nos. 1 and 2 Docket Nos. 50-424 and 50-425 Appendix A to License Nos. NPF-68 and NPF-81 September 25, 1996

TABLE OF CONTENTS 1.0 USE AND APPLICATION..................................................................... 1.1-1 1.1 Definitions............................................................................................. 1.1-1 1.2 Logical Connectors 1.2-1 1.3 Completion Times 1.3-1 1.4 Frequency 1.4-1 2.0 SAFETY LIMITS (SLs) 2.0-1 2.1 SLs 2.0-1 2.2 SL Violations......................................................................................... 2.0-1 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY.... 3.0-1 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.0-4 REACTIVITY CONTROL SYSTEMS 3.1.1-1 3.1.1 SHUTDOWN MARGIN (SDM) 3.1.1-1 3.1.2 Core Reactivity 3.1.2-1 3.1.3 Moderator Temperature Coefficient (MTC)............................................ 3.1.3-1 3.1.4 Rod Group Alignment Limits 3.1.4-1 3.1.5 Shutdown Bank Insertion Limits 3.1.5-1 3.1.6 Control Bank Insertion Limits 3.1.6-1 3.1.7 Rod Position Indication 3.1.7-1 3.1.8 PHYSICS Tests Exceptions - MODE 2 3.1.8-1 POWER DISTRIBUTION LIMITS.......................................................... 3.2.1-1 3.2.1 Heat Flux Hot Channel Factor (Fa(Z)) (Fa Methodology)....................... 3.2.1-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (F~H ).................................. 3.2.2-1 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset 3.2.3-1 Control (RAOC) Methodology) 3.2.4 QUADRANT POWER TILT RATIO (QPTR) 3.2.4-1 (continued)

Vogtle Units 1 and 2 Amendment No.1 07 (Unit 1)

Amendment No. 85 (Unit 2)

TABLE OF CONTENTS INSTRUMENTATION 3.3.1-1 3.3.1 Reactor Trip System (RTS) Instrumentation.......................................... 3.3.1-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation 3.3.2-1 3.3.3 Post Accident Monitoring (PAM) Instrumentation 3.3.3-1 3.3.4 Remote Shutdown System.................................................................... 3.3.4-1 3.3.5 4.16 kV ESF Bus Loss of Power (LOP) Instrumentation........................ 3.3.5-1 3.3.6 Containment Ventilation Isolation Instrumentation................................. 3.3.6-1 3.3.7 Control Room Emergency Filtration System (CREFS)

Actuation Instrumentation 3.3.7-1 3.3.8 High Flux at Shutdown Alarm (HFASA)................................................. 3.3.8-1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1-1 3.4.1 RCS Pressure, Temperature, and Flow Departure From Nucleate Boiling (DNB) Limits 3.4.1-1 3.4.2 RCS Minimum Temperature For Criticality............................................ 3.4.2-1 3.4.3 RCS Pressure and Temperature (PIT) Limits........................................ 3.4.3-1 3.4.4 RCS Loops MODES 1 and 2............................................................. 3.4.4-1 3.4.5 RCS Loops MODE 3 3.4.5-1 3.4.6 RCS Loops MODE 4......................................................................... 3.4.6-1 3.4.7 RCS Loops MODE 5, Loops Filled 3.4.7-1 3.4.8 RCS Loops MODE 5, Loops Not Filled 3.4.8-1 3.4.9 Pressurizer............................................................................................ 3.4.9-1 3.4.10 Pressurizer Safety Valves..................................................................... 3.4.10-1 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) 3.4.11-1 3.4.12 Cold Overpressure Protection Systems (COPS) 3.4.12-1 3.4.13 RCS Operational LEAKAGE 3.4.13-1 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage 3.4.14-1 3.4.15 RCS Leakage Detection Instrumentation 3.4.15-1 3.4.16 RCS Specific Activity............. 3.4.16-1 3.4.17 Steam Generator (SG) Tube Integrity................................................... 3.4.17-1 I EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1-1 3.5.1 Accumulators 3.5.1-1 3.5.2 ECCS Operating................................................................................ 3.5.2-1 3.5.3 ECCS Shutdown................................................................................ 3.5.3-1 3.5.4 Refueling Water Storage Tank (RWST) 3.5.4-1 3.5.5 Seal Injection Flow 3.5.5-1 3.5.6 Recirculation Fluid pH Control System.............................. 3.5.6-1 (continued)

Vogtle Units 1 and 2 ii Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

TABLE OF CONTENTS CONTAINMENT SySTEMS.................................................................. 3.6.1-1 3.6.1 Containment 3.6.1-1 3.6.2 Containment Air Locks 3.6.2-1 3.6.3 Containment Isolation Valves 3.6.3-1 3.6.4 Containment Pressure 3.6.4-1 3.6.5 Containment Air Temperature 3.6.5-1 3.6.6 Containment Spray and Cooling Systems............................ 3.6.6-1 3.6.7 Deleted 3.6.7-1 3.7 PLANT SYSTEMS 3.7.1-1 3.7.1 Main Steam Safety Valves (MSSVs) 3.7.1-1 3.7.2 Main Steam Isolation Valves (MSIVs) 3.7.2-1 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs) and Associated Bypass Valves............................................................................... 3.7.3-1 3.7.4 Atmospheric Relief Valves (ARVs) 3.7.4-1 3.7.5 Auxiliary Feedwater (AFW) System....................................................... 3.7.5-1 3.7.6 Condensate Storage Tank (CST) - (Redundant CSTs) 3.7.6-1 3.7.6a Condensate Storage Tank (CST) - (Non-redundant CSTs) 3.7.6a-1 3.7.7 Component Cooling Water (CCW) System 3.7.7-1 3.7.8 Nuclear Service Cooling Water (NSCW) System 3.7.8-1 3.7.9 Ultimate Heat Sink (UHS) 3.7.9-1 3.7.10 Control Room Emergency Filtration System (CREFS) - Both Units Operating 3.7.10-1 3.7.11 Control Room Emergency Filtration System (CREFS) - One Unit Operating 3.7.11-1 3.7.12 Control Room Emergency Filtration System (CREFS) - Both Units Shutdown 3.7.12-1 3.7.13 Piping Penetration Area Filtration and Exhaust System (PPAFES)......................................................................... 3.7.13-1 3.7.14 Engineered Safety Features (ESF) Room Cooler and Safety Related Chiller System 3.7.14-1 3.7.15 Fuel Storage Pool Water Level........................................ 3.7.15-1 3.7.16 Secondary Specific Activity............................ 3.7.16-1 3.7.17 Fuel Storage Pool Boron Concentration 3.7.17-1 3.7.18 Fuel Assembly Storage in the Fuel Storage Pool.................................. 3.7.18-1 (continued)

Vogtle Units 1 and 2 iii Amendment No. 134 (Unit 1)

Amendment No. 113 (Unit 2)

TABLE OF CONTENTS 3.8 ELECTRICAL POWER SYSTEMS 3.8.1-1 3.8.1 AC Sources Operating....................................................................... 3.8.1-1 3.8.2 AC Sources Shutdown 3.8.2-1 3.8.3 Diesel Fuel Oil, Lube Oil, Starting Air, and Ventilation 3.8.3-1 3.8.4 DC Sources Operating 3.8.4-1 3.8.5 DC Sources Shutdown 3.8.5-1 3.8.6 Battery Parameters.......... 3.8.6-1 3.8.7 Inverters Operating.... 3.8.7-1 3.8.8 Inverters Shutdown............................................................................ 3.8.8-1 3.8.9 Distribution Systems - Operating 3.8.9-1 3.8.10 Distribution Systems Shutdown 3.8.10-1 REFUELING OPERATIONS................................................................. 3.9.1-1 3.9.1 Boron Concentration 3.9.1-1 3.9.2 Unborated Water Source Isolation Valves............................................. 3.9.2-1 3.9.3 Nuclear Instrumentation 3.9.3-1 3.9.4 Containment Penetrations..................................................................... 3.9.4-1 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation

- High Water Level....................................................................... 3.9.5-1 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation

- Low Water Level........................................................................ 3.9.6-1 3.9.7 Refueling Cavity Water Level................................................................ 3.9.7-1 4.0 DESIGN FEATURES 4.0-1 4.1 Site 4.0-1 4.2 Reactor Core 4.0-1 4.3 Fuel Storage 4.0-2 5.0 ADMINISTRATIVE CONTROLS........................................................... 5.1-1 5.1 Responsibility........................................................................................ 5.1-1 5.2 Organization 5.2-1 5.3 Unit Staff Qualifications......................................................................... 5.3-1 5.4 Procedures 5.4-1 5.5 Programs and Manuals 5.5-1 5.6 Reporting Requirements 5.6-1 5.7 High Radiation Area.............................................................................. 5.7-1 (continued)

Vogtle Units 1 and 2 iv Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

TABLE OF CONTENTS (continued)

LIST OF TABLES 1.1-1 MODES 1.1-7 3.3.1-1 Reactor Trip System Instrumentation 3.3.1-14 3.3.2-1 Engineered Safety Feature Actuation System Instrumentation 3.3.2-9 3.3.3-1 Post Accident Monitoring Instrumentation 3.3.3-6 3.3.4-1 Remote Shutdown System Instrumentation and Controls........... 3.3.4-3 3.3.6-1 Containment Ventilation Isolation Instrumentation................................. 3.3.6-5 3.3.7-1 CREFS Actuation Instrumentation......................................................... 3.3.7-6 3.7.1-1 Maximum Allowable Power Range Neutron Flux High Trip Setpoint with Inoperable Main Steam Safety Valves...................... 3.7.1-3 3.7.1-2 Main Steam Safety Valve Lift Settings 3.7.1-4 (continued)

Vogtle Units 1 and 2 v Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

TABLE OF CONTENTS LIST OF FIGURES 2.1.1-1 Reactor Core Safety Limits....................................... 2.0-2 3.4.16-1 Reactor Coolant Dose Equivalent 1-131 Reactor Coolant Specific Activity Limit Versus Percent of Rated Thermal Power with the Reactor Coolant Specific Activity> 1 IJCi/gram Dose Equivalent 1-131 .. 3.4.16-4 3.7.18-1 Vogtle Unit 1 Burnup Credit Requirements for All Cell Storage............................................................................... 3.7.18-3 3.7.18-2 Vogtle Unit 2 Burnup Credit Requirements for All Cell Storage 3.7.18-4 4.3.1-1 Vogt/e Units 1 and 2 Empty Cell Checkerboard Storage Configurations.......................... 4.0-6 4.3.1-2 Vogtle Unit 2 3x3 Checkerboard Storage Configuration 4.0-7 4.3.1-3 Vogtle Units 1 and 2 Interface Requirements (All Cell to Checkerboard Storage)........................................ ......... 4.0-8 4.3.1-4 Vogtle Unit 2 Interface Requirements (Checkerboard Storage Interface) 4.0-9 4.3.1-5 Vogtle Unit 2 Interface Requirements (3x3 Checkerboard to All Cell Storage) 4.0-10 4.3.1-6 Vogt/e Unit 2 Interface Requirements (3x3 to Empty Cell Checkerboard Storage)...... 4.0-11 4.3.1-7 Vogtle Unit 1 IFBA Credit Requirements for All Cell Storage......... 4.0-12 4.3.1-8 Vogtle Unit 2 Burnup Credit Requirements for 3-out-of-4 Storage 4.0-13 4.3.1-9 Vogtle Unit 2 IFBA Credit Requirements for Center Assembly for 3x3 Storage 4.0-14 4.3.1-10 Vogtle Unit 2 Burnup Credit Requirements for Peripheral Assemblies for 3x3 Storage 4.0-15 5.5.6-1 Deleted.

Vogtle Units 1 and 2 vi Amendment No. 147 (Unit 1)

Amendment No. 127 (Unit 2)

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

~----------------------------------------------NOTE-----------------------------------------------------------

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.

AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux (AFD) signals between the top and bottom halves of a two section excore neutron detector.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel so that it responds within the required range and accuracy to known inputs. The CHAI\INEL CALIBRATION shall encompass the entire channel, including the required sensor, alarm, interlock, and trip functions. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping calibrations or total channel steps so that the entire channel is calibrated.

(conti nued)

Vogtle Units 1 and 2 1.1-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Definitions 1.1 1.1 Definitions (continued)

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

CHANNEL OPERATIONAL A COT shall be the injection of a simulated or TEST (COT) actual signal into the channel as close to the sensor as practicable to verify the OPERABII~ITY of required alarm, interlock, and trip functions. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints so that the setpoints are within the required range and accuracy.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or other reactivity control components within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the unit specific document that REPORT (COLR) provides cycle specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Unit operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132,1-133,1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in EPA Federal Guidance Report No. 11, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion," EPA-520/1-88-020, September 1988.

(continued)

Vogtle Units 1 and 2 1.1-2 Amendment No. 149 (Unit 1)

Amendment No. 129 (Unit 2)

Definitions 1.1 1.1 Definitions (continued)

E- AVERAGE E shall be the average (weighted in proportion to DISINTEGRATION ENERGY the concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half lives> 14 minutes, making up at least 95% of the total noniodine activity in the coolant.

ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time FEATURE (ESF) RESPONSE interval from when the monitored parameter exceeds its TIME ESF actuation setpoint at the channel sensor until the ESF equipment is capable of performing its safety function (Le.,

the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. 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 the methodology for verification have been previously reviewed and approved by the NRC.

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);

(continued)

Vogtle Units 1 and 2 1.1-3 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

Definitions 1.1 1.1 Definitions LEAKAGE b. Unidentified LEAKAGE (continued)

All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE;

c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing each master relay and verifying the OPERABILITY of each relay.

The MASTER RELAY TEST shall include a continuity check of each associated slave relay.

MODE A MODE shall correspond to anyone inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

OPERABLE- OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, SUbsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation. These tests are:

(continued)

Vogtle Units 1 and 2 1.1-4 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

Definitions 1.1 1.1 Definitions PHYSICS TESTS a. Described in Chapter 14 of the FSAR; (continued)

b. Authorized under the provisions of 10 CFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

PRESSURE AND The PTLR is the unit specific document that provides the TEMPERATURE LIMITS reactor vessel pressure and temperature limits, including REPORT (PTLR) heatup and cooldown rates, Cold Overpressure Protection System (COPS) arming temperature and the nominal PORV setpoints for the COPS, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.6. Unit operation within these operating limits is addressed in individual specifications.

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper RATIO (QPTR) excore detector calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the (RTP) reactor coolant of 3625.6 MWt.

REACTOR TRIP The RTS RESPONSE TIME shall be that time interval SYSTEM (RTS) RESPONSE from when the monitored parameter exceeds its RTS TIME trip setpoint at the channel sensor until loss of stationary gripper coil 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 the methodology for verification have been previously reviewed and approved by the NRC.

(continued)

Vogtle Units 1 and 2 1.1-5 Amendment No. 149 (Unit 1)

Amendment No. 129 (Unit 2)

Definitions 1.1 1.1 Definitions (continued)

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 RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA 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 hot zero power temperatures.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing each slave relay and verifying the OPERABILITY of each slave relay.

The SLAVE RELAY TEST shall include, as a minimum, a continuity check of associated testable actuation devices.

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.

TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip actuating device OPERATIONAL TEST and verifying the OPERABILITY of required alarm, (TADOT) interlock, and trip functions. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the required accuracy.

Vogtle Units 1 and 2 1.1-6 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES

% RATED AVERAGE REACTIVITY THERMAL MODE TITLE REACTOR COOLANT CONDITION pOWER(a) TEMPERATURE (kef!) (OF) 1 Power Operation ~ 0.99 >5 NA 2 Startup ~ 0.99 ~5 NA 3 Hot Standby < 0.99 NA ~ 350 4 Hot Shutdown(b) < 0.99 NA 350> T avg > 200 5 Cold Shutdown(b) < 0.99 NA ~ 200 6 Refueling(c) NA NA NA (a) Excluding decay heat.

(b) All reactor vessel head closure bolts fully tensioned.

(c) One or more reactor vessel head closure bolts less than fully tensioned.

Vogtle Units 1 and 2 1.1-7 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (Le., left justified with the number of the Required Action).

The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.

When logical connectors are used to state a Condition Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

(continued)

Vogtle Units 1 and 2 1.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-1 LOGICAL CONNECTORS (conti nued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify ...

A.2 Restore ...

In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

(continued)

Vogtle Units 1 and 2 1.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES EXAMPLE 1.2-2 MULTIPLE LOGICAL CONNECTORS (continued)

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, LCO not met. A.1 Trip ...

OR A.2.1 Verify ...

AND A.2.2.1 Reduce ...

OR A,2.2.2 Perform ...

OR A,3 Align ...

This example represents a more complicated use of logical connectors.

Required Actions A.1 , A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and the left justified placement. Anyone of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A,2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A,2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A,2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

Vogtle Units 1 and 2 1.2-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time. An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent trains, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition, unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.

(continued)

Vogtle Units 1 and 2 1.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times DESCRIPTION However, when a subsequent train, subsystem, component, or (continued) variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (Le., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery ..." Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

(continued)

Vogtle Units 1 and 2 1.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times (continued)

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 COMPLETION TIMES ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3. the time allowed for reaching MODE 5 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

(continued)

Vogtle Units 1 and 2 1.3-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 CONDITIONS AND LCO 3.0.3 ENTRY/COMPLETION (continued) TIME CLOCK/COMPLETION TIME EXTENSION ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

When a pump is declared inoperable, Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Conditions A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while the first pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

(continued)

Vogtle Units 1 and 2 1.3-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES While in LCO 3.0.3, if one of the inoperable pumps is restored to (continued) OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for> 7 days.

(continued)

Vogtle Units 1 and 2 1.3-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 MULTIPLE FUNCTION COMPLETION TIMES/

(continued) SEPARATE COMPLETION TIMES ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Restore 7 days Function X Function X train train to OPERABLE AND inoperable. status.

10 days from discovery of failure to meet the LCO B. One B.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y train train To OPERABLE AND inoperable. Status.

10 days from discovery of failure to meet the LCO C. One C.1 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function X Function X train train To OPERABLE inoperable. Status.

AND OR One C.2 Restore 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Function Y Function Y train train To OPERABLE inoperable. Status.

(continued)

Vogtle Units 1 and 2 1.3-6 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions Band C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).

The Completion Times of Conditions A and B are modified by a logical connector with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock." In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.

(continued)

Vogtle Units 1 and 2 1.3-7 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 MULTIPLE COMPONENT CONDITIONS/

(continued) COMPLETION TIMES/COMPLETION TIME EXTENSIONS ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves To OPERABLE inoperable. Status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months met.

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for> 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (including the extension) expires while one or more valves are still inoperable, Condition B is entered.

(continued)

Vogtle Units 1 and 2 1.3-8 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 SEPARATE CONDITION ENTRY (continued)

ACTIONS

NOTE---------------------------------------------

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE inoperable. status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not met. B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months The Note above the ACTIONS table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific condition, the Note would appear in that Condition, rather than at the top of the ACTIONS table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

(continued)

Vogtle Units 1 and 2 1.3-9 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued)

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

(continued)

Vogtle Units 1 and 2 1.3-10 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 MULTIPLE ACTIONS WITHIN A CONDITIONI (continued) COMPLETION TIME EXTENSIONS ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable.

OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to

~ 50% RTP.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated Completion Time not met.

Entry into Condition A offers a choice between Required Action A.1 or A.2. Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8-hour interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8-hour interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition B is entered.

If after entry into Condition B, Required Action A.1 or A.2 is met, Condition B is exited and operation may then continue in Condition A.

(continued)

Vogtle Units 1 and 2 1.3-11 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 MULTIPLE ACTIONS WITHIN A CONDITION/

(continued) COMPLETION TIME EXTENSIONS ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months sUbsystem sUbsystem isolated.

inoperable. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to OPERABLE status.

B. Required B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action and associated AND Completion Time not B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months met.

Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered, and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

(continued)

Vogtle Units 1 and 2 1.3-12 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-7 (continued)

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8-hour interval from the previous performance (plus the extension allowed by SR 3.0.2),

Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When "Immediately" is used as a Completion Time, the COMPLETION TIME Required Action should be pursued without delay and in a controlled manner.

Vogtle Units 1 and 2 1.3-13 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR)

Applicability. The "specified Frequency" consists of the requirements of the Frequency column of each SR as well as certain Notes in the Surveillance column that modify performance requirements.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (Le., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

(continued)

Vogtle Units 1 and 2 1.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 SINGLE FREQUENCY (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Perform CHAI\II\IEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time. Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility. The measurement of this interval continues at all times, even when the SR is not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, then SR 3.04 becomes applicable. The Surveillance must be performed within the Frequency requirements of SR 3.0.2, as modified by SR 3.0.3, prior to entry into the MODE or other specified condition or the LCO is considered not met (in accordance with SR 3.0.1) and LCO 3.0.4 becomes applicable.

(continued)

Vogtle Units 1 and 2 1.4-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-2 MULTIPLE FREQUENCIES (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after

~ 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met. Each time reactor power is increased from a power level

< 25% RTP to ~ 25% RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND").

This type of Frequency does not qualify for the extension allowed by SR 3.0.2. "Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to

< 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25% RTP.

(continued)

Vogtle Units 1 and 2 1.4-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-3 FREQUENCY BASED ON A SPECIFIED CONDITION (continued)

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE---------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after 225% RTP.

Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches 2 25% RTP to perform the Surveillance.

The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was

< 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power 2 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval, there would then be a failure to perform a Surveillance within the specified Frequency and the provisions of SR 3.0.3 would apply.

Vogtle Units 1 and 2 1.4-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.1.1 Reactor Core SLs In MODES 1 and 2, the combination of THERMAL POWER, Reactor Coolant System (RCS) highest loop average temperature, and pressurizer pressure shall not exceed the SLs specified in Figure 2.1.1-1.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, the RCS pressure shall be maintained s 2735 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes.

2.2.3 Within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months notify the NRC Operations Center, in accordance with 10 CFR 50.72.

2.2.4 Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , notify the Plant Manager and Vice President - Vogtle.

2.2.5 Within 30 days a Licensee Event Report (LER) shall be prepared and submitted to the NRC pursuant to 10 CFR 50.73.

2.2.6 Operation of the unit shall not be resumed until authorized by the NRC.

Vogtle Units 1 and 2 2.0-1 Amendment No. 148 (Unit 1)

Amendment No. 128 (Unit 2)

SLs 2.0 670 660

--- t--

r---

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2425 pslg

~r--.

\ \

DO NOT OPERATE IN THIS AREA

\

650

--- ----- ~pslg r-- .......

--r--.t---t---..

~

W II:

~

640

--.. r--. -r---. I---

to--. --- ~

l\.

II:

W D.

E 630 620 r--.. ~r--.

. 1920 psIg I---

1965 pslg r--- -...

r--.:

--- r--. r--- ~

r--- t---

I!!w t--. r--. '- .....

C!J

.D.

610 600

--- r--. r--.

t---r--- to--

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Ii 8...1 590 a% 580 ACCEPTABLE

~ 570 OPERATION 560 550 o 10 20 30 40 50 60 70 80 90 100 110 120 PERCENT OF RATED THERMAL POWER Figure 2.1.1-1 Reactor Core Safety Limits Vogtle Units 1 and 2 2.0-2 Amendment No. 128 (Unit 1)

Amendment NO.1 06 (Unit 2)

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2 and LCO 3.0.8.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 3 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ;

b. MODE 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 5 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications.

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; or (continued)

Vogtle Units 1 and 2 3.0-1 Amendment No. 141 (Unit 1)

Amendment No. 121 (Unit 2)

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 b. After performance of a risk assessment addressing inoperable (continued) systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications; or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, additional evaluations and limitations may be required in accordance with Specification 5.5.15, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

(continued)

VogUe Units 1 and 2 3.0-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.7 Test Exception LCO 3.1.8 allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with the Test Exception LCO is optional. When the Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When the Test Exception LCO is not desired to be met, entry into a MODE or other specified condition shall be made in accordance with the other applicable specifications.

LCO 3.0.8 When one or more required snubbers are unable to perform their associated support function(s), any affected supported LCO(s) are not required to be declared not met solely for this reason if risk is assessed and managed, and:

a. the snubbers not able to perform their associated support function(s) are associated with only one train or subsystem of a multiple train or subsystem supported system or are associated with a single train or subsystem supported system and are able to perform their associated support function within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months ; or

b. the snubbers not able to perform their associated support function(s) are associated with more than one train or subsystem of a multiple train or subsystem supported system and are able to perform their associated support function within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

At the end of the specified period the required snubbers must be able to perform their associated support function(s), or the affected supported system LCO(s) shall be declared not met.

LCO 3.0.9 Unless specifically noted, all the information provided in the LCO including the associated ACTION requirements shall apply to each unit individually.

In those cases where a specification makes reference to systems or components which are shared by both units, the affected systems or components will be clearly identified in parentheses or footnotes declaring the reference to be "common." Whenever the LCO refers to systems or components which are common, the ACTION requirements will apply to both units simultaneously. (This will be indicated in the ACTION section.)

Whenever certain portions of a specification refer to systems, components, operating parameters, setpoints, etc., which are different for each unit, this will be identified in parentheses or footnotes or in the Applicability section as appropriate.

Vogtle Units 1 and 2 3.0-3 Amendment No. 141 (Unit 1)

Amendment 1\10. 121 (Unit 2)

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR.

Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per ..."

basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

(continued)

Vogtle Units 1 and 2 3.0-4 Amendment No. 125 (Unit 1)

Amendment NO.1 03 (Unit 2)

SR Applicability 3.0 3.0 SR APPLICABILITY SR 3.0.3 When the Surveillance is performed within the delay period (continued) and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

Vogtle Units 1 and 2 3.0-5 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

SDM 3.1.1 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM)

LCO 3.1.1 SDM shall be ~ the limit specified in the COLR.

APPLICABILITY: MODES 3, 4, and 5.

ACTIONS

NOTE---------------------------------------------------------

While this LCO is not met, transition to a lower MODE within the Applicability is not permitted.

CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM is ~ the limit specified in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Vogtle Units 1 and 2 3.1.1-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within +/- 1% ~k/k of predicted values.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Measured core reactivity A.1 Reevaluate core design 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months not within limit. and safety analysis, and determine that the reactor core is acceptable for continued operation.

AND A.2 Establish appropriate 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months operating restrictions and SRs.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.1.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.2.1 ------------------------------N()TE-----------------------------

The predicted reactivity values may be adjusted (normalized) to correspond to the measured core reactivity prior to exceeding a fuel burnup of 60 effective full power days (EFPD) after each fuel loading.

Verify measured core reactivity is within +/- 1% L'lklk ()nce prior to of predicted values. entering M()DE 1 after each refueling 31 EFPD thereafter upon achieving 60 EFPD Vogtle Units 1 and 2 3.1.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC) lCO 3.1.3 The MTC shall be maintained within the beginning of cycle life (BOl) limit and the end of cycle life (EOl) limit specified in the COlR. The maximum upper limit shall be less positive than + 0.7 x 10-4 L1k/kloF for power levels up to 70% RATED THERMAL POWER with a linear ramp to 0 L1k/kloF at 100% RATED THERMAL POWER.

APPLICABILITY: MODE 1 and MODE 2 with keff ::::: 1.0 for the BOl limit, MODES 1, 2, and 3 for the EOl limit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within BOl A.1 Establish administrative 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limit. withdrawal limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met.

C. MTC not within EOl' C.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

Vogtle Units 1 and 2 3.1.3-1 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

MTC 3.1.3 SURVEilLANCE REQUIREMENTS SURVEillANCE FREQUENCY SR 3.1.3.1 Verify MTC is within BOl limit. Once prior to entering MODE 1 after each refueling SR 3.1.3.2 -------------------------------NOTES-----------------------------

1. Not required to be performed until 7 EFPD after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm.

2. If the MTC is more negative than the 300 ppm Surveillance limit (not lCO limit) specified in the COlR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

3. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of :::; 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COlR.

Verify MTC is within EOl limit. Once each cycle Vogtle Units 1 and 2 3.1.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE, with all individual indicated rod positions 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 rod(s) A.1.1 Verify SDM is ~ the limit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months untrippable. specified in the COLR.

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

AND A.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One rod not within B.1.1 Verify SDM is ~ the limit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months alignment limits. specified in the COLR.

OR (continued)

Vogtle Units 1 and 2 3.1.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Rod Group Alignment Limits 3.1.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

8. (continued) 8.1.2 Initiate boration to restore 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND 8.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to ~ 75% RTP.

AND 8.3 Verify SDM is ~ the limit Once per specified in the COLR. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND 8.4 Perform SR 3.2.1.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 8.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND 8.6 Reevaluate safety 5 days analyses and confirm results remain valid for duration of operation under these conditions.

(contin ued)

Vogtle Units 1 and 2 3.1.4-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not met.

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

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

AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limit.

Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod position deviation monitor is inoperable (continued)

Vogtle Units 1 and 2 3.1.4-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Rod Group Alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.4.2 Verify rod freedom of movement by moving each 92 days rod not fully inserted in the core ~ 10 steps in either direction.

SR 3.1.4.3 Verify rod drop time of each rod, from the physical Prior to reactor fUlly withdrawn position, is ~ 2.7 seconds from the criticality after beginning of decay of stationary gripper coil each removal of voltage to dashpot entry, with: the reactor head

b. All reactor coolant pumps operating.

Vogtle Units 1 and 2 3.1.4-4 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR.

APPLICABILITY: MODES 1 and 2

NOTE------------------------------------------------

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM is ~ the limit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months banks not within limits. specified in the COLR.

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

AND A.2 Restore shutdown banks 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.1.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the insertion 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits specified in the COLR.

Vogtle Units 1 and 2 3.1.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

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 kef! ~ 1.0.

NOTE-----------------------------------------------

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Control bank insertion A.1.1 Verify SDM is ~ the limit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months limits not met. specified in the COLR.

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

AND A.2 Restore control bank(s) 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to within limits.

(contin ued)

Vogtle Units 1 and 2 3.1.6-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Control Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Control bank sequence B.1.1 Verify SDM is ~ the limit 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or overlap limits not met. specified in the COLR.

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

AND B.2 Restore control bank 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months sequence and overlap to within limits.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.6.1 Verify estimated critical control bank position is Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to within the limits specified in the COLR. achieving criticality (continued)

Vogtle Units 1 and 2 3.1.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Control Bank Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.1.6.2 Verify each control bank insertion is within the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months limits specified in the COLR.

Once within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months and every 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months thereafter when the rod insertion limit monitor is inoperable SR 3.1.6.3 Verify sequence and overlap limits specified in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COLR are met for control banks not fully withdrawn from the core.

Vogtle Units 1 and 2 3.1.6-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

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) System and the Demand Position Indication System shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.

ACTIONS

NOTE----------------------------------------------------------

Separate Condition entry is allowed for each group with no more than one inoperable rod position indicator in the group and for each bank with no more than one inoperable demand position indicator in the bank.

CONDITION REQUIRED ACTION COMPLETION TIME A. One DRPI per group A.1 Verify the position of the Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for one or rods with inoperable more groups. position indicators by using movable incore detectors.

OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to"'; 50% RTP.

B. One or more rods with B.1 Verify the position of the 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable DRPls have rods with inoperable been moved in excess DRPls by using movable of 24 steps in one incore detectors.

direction since the last determination of the rod's position. OR (continued)

Vogtle Units 1 and 2 3.1.7-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Rod Position Indication 3.1.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to:-:;; 50% RTP.

C. One demand position C.1.1 Verify by administrative Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months indicator per bank means all DRPls for the inoperable for one or affected banks are more banks. OPERABLE.

AND C.1.2 Verify the most withdrawn Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months rod and the least withdrawn rod of the affected banks are

-:;; 12 steps apart.

OR C.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to:-:;; 50% RTP.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.1.7-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Rod Position Indication 3.1.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the 18 months group demand position for the full indicated range of rod travel.

Vogtle Units 1 and 2 3.1.7-3 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

PHYSICS TESTS Exceptions - MODE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions MODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1.3, "Moderator Temperature Coefficient (MTC)";

LCO 3.1.4, "Rod Group Alignment Limits";

LCO 3.1.5, "Shutdown Bank Insertion Limits";

LCO 3.1.6, "Control Bank Insertion Limits"; and LCO 3.4.2, "RCS Minimum Temperature for Criticality" may be suspended, provided:

a. THERMAL POWER is maintained :0::; 5% RTP.

b. RCS lowest loop average temperature is 2': 541°F; and

c. SDM is 2': the limit specified in the COLR.

APPLICABILITY: MODE 2 during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore 15 minutes SDM to within limit.

AND A.2 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months TESTS exceptions.

B. THERMAL POWER not B.1 Open reactor trip Immediately within limit. breakers.

(continued)

Vogtle Units 1 and 2 3.1.8-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

PHYSICS TESTS Exceptions - MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest loop C.1 Restore RCS lowest loop 15 minutes average temperature not average temperature to within limit. within limit.

D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATIONAL TEST on Within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior power range and intermediate range channels per to initiation of SR 3.3.1.7, SR 3.3.1.8, and Table 3.3.1-1. PHYSICS TESTS SR 3.1.8.2 Verify the RCS lowest loop average temperature 30 minutes is ~ 541°F.

SR 3.1.8.3 Verify SDM is ~ the limit specified in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Vogtle Units 1 and 2 3.1.8-2 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

Fa{Z) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (Fa{Z)) (Fa Methodology)

LCO 3.2.1 Fa{Z) shall be within the steady state and transient limits specified in the COLR.

APPLICABILITY: MODE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fa(Z) not within steady A. 1 Reduce THERMAL 15 minutes state limit. POWER ~ 1% RTP for each 1% Fa{Z) exceeds steady state limit.

AND A.2 Reduce Power Range 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Neutron Flux High trip setpoints ~ 1% for each 1% Fa{Z) exceeds steady state limit.

AND A.3 Reduce Overpower ilT 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trip setpoints ~ 1% for each 1% Fa{Z) exceeds steady state limit.

AND AA Perform SR 3.2.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

Vogtle Units 1 and 2 3.2.1-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Fa(Z) 3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Fa(Z) not within transient B.1 Reduce AFD limits ~ 1% 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limit. for each 1% Fa(Z) exceeds transient limit and control AFD within reduced limits.

C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.2.1-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Fa{Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify Fa{Z) is within steady state limit. Once after each refueling after achieving equilibrium conditions at any power level exceeding 50% RTP Once after achieving equilibrium conditions after exceeding, by

~ 20% RTP, the THERMAL POWER at which Fa{Z) was last verified AND 31 EFPD thereafter (continued)

Vogtle Units 1 and 2 3.2.1-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Fa(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 -------------------------------N()TE------------------------------

If measurements indicate maximum over Z [Fa (Z) l K(Z) has increased since the previous evaluation of Fa(Z):

a. Increase Fa(Z) by an appropriate penalty factor specified in the C()LR and verify this value is within the transient limits; or

b. Repeat SR 3.2.1.2 once per 7 EFPD until either

a. above is met or two successive flux maps indicate maximum over Z [Fa(Z)l K(Z) has not increased.

Verify Fa(Z) is within transient limit. ()nce after each refueling after achieving equilibrium conditions at any power level exceeding 50% RTP (continued)

Vogtle Units 1 and 2 3.2.1-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Fa(Z) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once after achieving equilibrium conditions after exceeding, by

~ 20% RTP, the THERMAL POWER at which Fa(Z) was last verified 31 EFPD thereafter Vogtle Units 1 and 2 3.2.1-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (F~H)

LCO 3.2.2 F~H shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. ------------NOTE----------- A.1.1 Restore F~H to within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Required Actions A.2 limits.

and A.3 must be completed whenever OR Condition A is entered.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months A.1.2.1 Reduce THERMAL POWER to < 50% RTP.

F~H not within limits.

AND A.1.2.2 Reduce Power Range 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months Neutron Flux - High trip setpoints to ~ 55% RTP.

AND A.2 Perform SR 3.2.2.1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND (continued)

Vogtle Units 1 and 2 3.2.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

F~H 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 ------------N 0 TE-------------

THERMAL POWER does not have to be reduced to comply with this Required Action.

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching ~ 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.2.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

F~H 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify F~H is within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND 31 EFPD thereafter Vogtle Units 1 and 2 3.2.2-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AFD (RAOC Methodology) 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology)

LCO 3.2.3 The AFD shall be maintained within the limits specified in the COLR.

NOTE----------------------------------------------

The AFD shall be considered outside limits when two or more OPERABLE excore channels indicate AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER ~ 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD within limits for each OPERABLE 7 days excore channel.

AND Once within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and every 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months thereafter with the AFD monitor alarm inoperable Vogtle Units 1 and 2 3.2.3-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be ~ 1.02.

APPLICABILITY: MODE 1 with THERMAL POWER> 50% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -----------NOTE------------ A.1 Limit THERMAL POWER 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months Required Action A.6 to ;::: 3% below RTP for must be completed each 1% of QPTR > 1.00.

whenever Required Action A.5 is AND implemented.

A.2.1 Perform SR 3.2.4.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months QPTR not within limit. AND A.2.2 Limit THERMAL POWER ----------NOTE---------

to;::: 3% below RTP for For performances of each 1% QPTR > 1.00. Required Action A.2.2 the Completion Time is measured from the completion of SR 3.2.4.1.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.3 Perform SR 3.2.1.1 and Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.2.1. achieving equilibrium conditions with THERMAL POWER limited by Required Actions A.1 and A.2.2 (continued)

Vogtle Units 1 and 2 3.2.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) AND Once per 7 days thereafter AND A.4 Reevaluate safety Prior to increasing analyses and confirm THERMAL POWER results remain valid for above the limit of duration of operation Required Action under this condition. A.1 and A.2.2 AND A.5 -------------NOTE------------

Perform Required Action A.5 only after Required Action A.4 is completed.

Calibrate excore detectors Prior to increasing to show QPTR = 1.00. THERMAL POWER above the limit of Required Action A.1 and A.2.2 AND (continued)

Vogtle Units 1 and 2 3.2.4-2 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 -------------NOTE------------

Perform Required Action A.6 only after Required Action A.5 is completed.

Perform SR 3.2.1.1 and -----------NOTE---------

SR 3.2.2.1. Only one of the following Completion Times, whichever becomes applicable first, must be met.

Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reaching RTP OR Within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Action A.1 and A.2.2 B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POW ER to ~ 50% RTP.

Time not met.

Vogtle Units 1 and 2 3.2.4-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1 ---------------------------NOTE-----------------------------

With one power range channel inoperable, the remaining three power range channels can be used for calculating QPTR.

Verify QPTR is within limit by calculation. 7 days Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and every 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter with the QPTR alarm inoperable SR 3.2.4.2 ----------------------------NOTE----------------------------

Only required to be performed if input to QPTR from one or more Power Range Neutron Flux channels is inoperable with THERMAL POWER

~ 75% RTP.

Confirm that the normalized symmetric power Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months distribution is consistent with QPTR.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Vogtle Units 1 and 2 3.2.4-4 Amendment No. 143 (Unit 1)

Amendment No. 123 (Unit 2)

RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.

ACTIONS

NOTE------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more referenced in required channels Table 3.3.1-1 for the inoperable. channel(s).

B. One Manual Reactor Trip B.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months channel inoperable. OPERABLE status.

OR B.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months C. ----------N0 TE------------- C.1 Restore channel or train 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months While this LCO is not met to OPERABLE status.

for Functions 1, 17, 18, or 19 in MODES 3, 4, OR or 5, closing the reactor trip breakers is not C.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months permitted.

One channel or train inoperable.

(continued)

Vogtle Units 1 and 2 3.3.1-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One Power Range ---------------------NOTES-----------------

Neutron Flux - High 1. A channel may be channel inoperable. bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing and setpoint adjustment.

2. Refer to LCO 3.2.4 for an inoperable power range channel.

D.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR D.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

Vogtle Units 1 and 2 3.3.1-2 Amendment No. 143 (Unit 1)

Amendment No. 123 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One channel inoperable. --------------------NOTE--------------------

A channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

E.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months F. THERMAL POWER F.1 Reduce THERMAL 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> P-6 and < P-10, one POWER to < P-6.

Intermediate Range Neutron Flux channel OR inoperable.

F.2 Increase THERMAL 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months POWER to > P-10.

G. THERMAL POWER G.1 Suspend operations Immediately

> P-6 and < P-10, two involving positive reactivity Intermediate Range additions.

Neutron Flux channels inoperable. AND G.2 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months POWER to < P-6.

H. THERMAL POWER H.1 Restore channel(s) to Prior to increasing

< P-6, one or two OPERABLE status. THERMAL POWER Intermediate Range to> P-6 Neutron Flux channels inoperable.

(continued)

Vogtle Units 1 and 2 3.3.1-3 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. One Source Range 1.1 Suspend operations Immediately Neutron Flux channel involving positive reactivity inoperable. additions.

J. Two Source Range J.1 Open RTBs. Immediately Neutron Flux channels inoperable.

K. One Source Range K.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Neutron Flux channel OPERABLE status.

inoperable.

OR K.2 Open RTBs. 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months L. Required Source Range ---------------------NOTE-------------------

Neutron Flux channel Enter Applicable Conditions and inoperable. Required Actions of LCO 3.3.8, "High Flux at Shutdown Alarm" (HFASA) for HFASA channels made inoperable by the Source Range instrumentation.

L.1 Suspend operations Immediately involving positive reactivity additions.

(continued)

Vogtle Units 1 and 2 3.3.1-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M. One channel inoperable. --------------------NOTES------------------

1. For RCP bus undervoltage or underfrequency instrument functions; the inoperable channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing of other channels.

2. For other instrument functions; a channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

M.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M.2 Reduce THERMAL 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months POWER to < P-7.

N. One Reactor Coolant ---------------------NOTE-------------------

Flow-Low (single loop) A channel may be bypassed for up channel inoperable. to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

N.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR N.2 Reduce THERMAL 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months POWER to < P-8.

(continued)

Vogtle Units 1 and 2 3.3.1-5 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME O. One Low Fluid oil ---------------------NOTE-------------------

pressure Turbine Trip A channel may be bypassed for up channel inoperable. to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

0.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 0.2 Reduce THERMAL 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months POWER to < P-9.

P. One or more Turbine P.1 Place channel(s) in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months stop valve Closure Turbine Trip channels OR inoperable.

P.2 Reduce THERMAL 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months POWER to < P-9.

Q. One train inoperable. ---------------------NOTE-------------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Q.1 Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR Q.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months (continued)

Vogtle Units 1 and 2 3.3.1-6 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME R. One or more channels R.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit conditions.

OR R.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months S. One or more channels S.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. required state for existing unit conditions.

OR S.2 Be in MODE 2. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months T. One RTB train -------------------NOTE-------------------

inoperable. One train may be bypassed for I up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing, provided the other train is OPERABLE.

T.1 Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR T.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months (continued)

Vogtle Units 1 and 2 3.3.1-7 Amendment No. 145 (Unit 1)

Amendment No. 125 (Unit 2)

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME U. One trip mechanism U.1 Restore inoperable trip 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable for one RTB. mechanism to OPERABLE status.

OR U.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months V. An inoperable trip V.1 Enter LCO 3.0.3. Immediately mechanism, RTB, or Automatic Trip Logic occurs on opposite trains concurrently.

Vogtle Units 1 and 2 3.3.1-8 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS

NOTE----------------------------------------------------------

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.1.2 ----------------------------NOTES----------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER is ~ 15% RTP.

Compare results of calorimetric heat balance 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months calculation to power range channel output. Adjust power range channel output if calorimetric heat balance calculation results exceed power range channel output by more than +2% RTP.

SR 3.3.1.3 ---------------------------No-rES-----------------------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is ~ 15% RTP.

Compare results of the incore detector 31 effective full measurements to Nuclear Instrumentation System power days (EFPD)

(NIS) AFD. Adjust I\IIS channel if absolute difference is ~ 3%.

(continued)

Vogtle Units 1 and 2 3.3.1-9 Amendment No. 131 (Unit 1)

Amendment No. 110 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 ----------------------------NOTE---------------------------:..--

This Surveillance must be performed on the reactor trip bypass breaker prior to placing the bypass breaker in service.

Perform TADOT. 62 days on a STAGGERED TEST BASIS SR 3.3.1.5 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.1.6 -----------------------------NOTES---------------------------

1. Not required to be performed until 7 days after THERMAL POWER is:::- 75% RTP.

2. Neutron detectors are excluded from CHANNEL CALIBRATION.

Calibrate excore channels to agree with incore 92 EFPD detector measurements.

SR 3.3.1.7 -----------------------------NOTES---------------------------

1. For the Source Range Instrumentation this surveillance shall include verification that interlocks P-6 and P-10 are in their required state for existing unit conditions.

2. Not required to be performed for Source Range Instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

Perform COT. 184 days (continued)

Vogtle Units 1 and 2 3.3.1-10 Amendment No. 145 (Unit 1)

Amendment No. 125 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 -------------------------------NOTE---------------------------

Only required when not performed within previous 31 days.

Perform COT. Prior to Reactor Startup SR 3.3.1.9 -------------------------------NOTE---------------------------

Verification of setpoint is not required.

Perform TADOT. 92 days SR 3.3.1.10 ------------------------------NOTE----------------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.1.11 --------------------------NOTE-----------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months (continued)

Vogtle Units 1 and 2 3.3.1-11 Amendment No.1 04 (Unit 1)

Amendment No. 82 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.12 Perform COT. 18 months SR 3.3.1.13 -------------------------------NOTE---------------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.1.14 -----------------------------NOTES---------------------------

1. Only required when not performed within previous 31 days.

2. Verification of setpoint is not required.

Perform TADOT. After each MODE 3 entry for unit shutdown and prior to exceeding the P-9 interlock trip setpoint.

SR 3.3.1.15 ------------------------------NOTE----------------------------

Neutron detectors are excluded from response time testing.

Verify RTS RESPONSE TIME is within limits. 18 months on a STAGGERED TEST BASIS (continued)

Vogtle Units 1 and 2 3.3.1-12 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RTS Instrumentation 3.3.1 SURVEILLANCE FREQUENCY SR 3.3.1.16 -------------------------------NOTES-------------------------

1. Only required when not performed within previous 31 days.

2. Verification of setpoint is not required.

Perform COT. After each MODE 3 entry for unit shutdown and prior to exceeding the P-9 interlock trip setpoint.

Vogtle Units 1 and 2 3.3.1-13 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 10(9)

Reactor Trip System Instrumentation APPLICABLE MODES OR NOMINAL OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(n)

1. Manual Reactor 1,2 2 B SR3.3.1.13 NA NA Trip 2 C SR 3.31.13 NA NA

2. Power Range Neutron Flux

a. High 1,2 4 D SR 3.3.11 <:; 111.3% RTP 109% RTP SR 3.3.1.2 SR 3.3.1.7 SR 3.3.111 SR 3.3.1.15

b. Low 4 E SR 3.3.1.1 <:;27.3% RTP 25% RTP SR 3.3.1.8 SR 33.111 SR 3.3.1.15

3. Power Range 1,2 4 E SR 3.3.1.7 <:; 6.3% RTP 5% RTP Neutron Flux High SR3.3.1.11 with time with time Positive Rate constant constant

~ 2 sec ~ 2 sec

4. Intermediate 1(b),2(c) 2 F,G SR 3.3.1.1 <:;41.9% RTP 25% RTP Range Neutron SR 33.1.8 Flux SR3.31.11 2 H SR 3.3.1.1 <:; 41.9% RTP 25% RTP 2(d)

SR 33.1.8 SR 3.31.11 (continued)

(a) With Reactor Trip Breakers (RTBs) closed and Rod Control System capable of rod withdrawal.

(b) Below the P-10 (Power Range Neutron Flux) interlocks.

(c) Above the P-6 (Intermediate Range Neutron Flux) interlocks.

(d) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

(n) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.1-14 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 9)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER NOMINAL TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CONDITIONS REQUIREMENTS VALUE SETPOINT(n)

CHANNELS

5. Source Range 2(d) 2 I,J SR 3.3.1.1 s 1.7 E5 1.0 E5 Neutron Flux SR 3.3.1.8 cps cps SR 3.3.1.11 3(a), 4(a), 5(a) 2 J,K SR 3.3.1.1 s 1.7 E5 1.0 E5 SR 3.3.1.7 cps cps SR 3.3.1.11 L SR 3.3.11 3(e), 4(e), 5(e) SR 3.3.1.11 NA NA

6. Overtemperature "'T 1,2 4 E SR 3.3.1.1 Refer to Note 1 Refer to Note 1 SR 3.3.1.3 (Page 3.3.1-20) (Page 3.3.1-20)

SR 3.3.1.6 SR 3.3.1.7 SR 3.3.110 SR 3.3.1.15

7. Overpower "'T 1,2 4 E SR 3.3.1.1 Refer to Note 2 Refer to Note 2 SR 3.3.1.7 (Page 3.3.1-21) (Page 3.3.1-21)

SR 3.3.1.10 SR 3.3.1.15 (continued)

(a) With RTBs closed and Rod Control System capable of rod withdrawaL (d) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

(e) With the RTBs open. In this condition, source range Function does not provide reactor trip but does provide input to the High Flux at Shutdown Alarm System (LCO 3.3.8) and indication.

(n) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.1-15 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 9)

Reactor Trip System Instrumentation APPLICABLE MODES OR NOMINAL OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT(n)

FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE

8. Pressurizer Pressure

a. Low 4 M SR 3.3.1.1 ~ 1950 psig 1960(g) psig SR 3.3.1.7 SR3.3.1.10 SR 3.31.15

b. High 1,2 4 E SR 3.3.1.1 $ 2395 psig 2385 psig SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.15

9. Pressurizer Water 3 M SR 3.3.1.1 $ 93.9% 92%

Level- High SR 3.3.17 SR 3.3.1.10

10. Reactor Coolant Flow - Low

a. Single Loop 3 per loop N SR 3.31.1 ~ 89.4% 90%

SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.15

b. Two Loops 3 per loop M SR 3.3.1.1 ~ 89.4% 90%

SR 3317 SR 3.3.1.10 SR 3.31.15 (continued)

(I) Above the P-7 (Low Power Reactor Trips Block) interlock.

(g) Time constants utilized in the lead-lag controller for Pressurizer Pressure-Low are 10 seconds for lead and 1 second for lag.

(h) Above the P-8 (Power Range Neutron Flux) interlock.

(i) Above the P-7 (Low Power Reactor Trips Block) interlock and below the P-8 (Power Range Neutron Flux) interlock.

(n) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.1-16 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 9)

Reactor Trip System Instrumentation APPLICABLE MODES OR NOMINAL OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE SETPOINT(n)

FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE

11. Undervoltage 1(f) 2 per bus M SR 3.3.1.9 ~ 9481 V 9600 V RCPs SR 3.3.1.10 SR 3.3.1.15

12. Underfrequency 1(f) 2 per bus M SR 3.3.1.9 ~ 57.1 Hz 57.3 Hz RCPs SR 3.3.110 SR 3.3.1.15

13. Steam Generator 1,2 4 per SG E SR 3.311 ~ 35.9% 37.8%

(SG) Water Level SR 33.1.7 Low Low SR 3.3.1.10 SR 3.3.1.15 (continued)

(f) Above the P-7 (Low Power Reactor Trips Block) interlock.

(n) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.1-17 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 9)

Reactor Trip System Instrumentation APPLICABLE MODES OR NOMINAL OTHER TRIP SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CHANNELS REQUIREMENTS VALUE SETPOINT(n)

CONDITIONS CONDITIONS

14. Turbine Trip

a. Low Fluid Oil 1m 3 0 SR 3.3.1.10 <: 500 ps;g 580 psig Pressure SR 3.3.1.16

b. Turbine Stop 1m 4 P SR 3.3.110 <: 90% open 96.7% open Valve Closure SR 3.3.1.14

15. Safety Injection (S I) 1,2 2 trains Q SR 3.3.1.13 NA NA Input from Engineered Safety Feature Actuation System (ESFAS)

16. Reactor Trip System Interlocks

a. Intermediate 2(d) 2 R SR 3.3.1.11 <: 1.2E-5% RTP 2.0E-5% RTP Range SR 3.3.1.12 Neutron Flux, P-6

b. Low Power 1 per train S SR 33.1.5 NA NA Reactor Trips Block, P-7

c. Power Range 4 S SR 3.3.1.11 ::; 50.3% RTP 48% RTP Neutron Flux, SR 3.3.112 P-8

d. Power Range 4 S SR 3.3.1.11 ::;40.6% RTP 40% RTP Neutron Flux, SR 331.12 P-9

e. Power Range 1,2 4 R SR 3.3.111 (I,m) (I,m)

Neutron Flux, SR 3.3.1.12 P-10 and input to P-7

f. Turbine 2 S SR 3.3.1.10 ::; 12.3% Impulse 10% Impulse Impulse SR 3.3.1.12 Pressure Pressure Pressure, Equivalent Equivalent P-13 turbine turbine (continued)

(d) Below the P-6 (Intermediate Range Neutron Flux) interlocks.

m Above the P-9 (Power Range Neutron Flux) interlock.

(I) For the P-10 input to P-7, the Allowable Value is::; 12.3% RTP and the Nominal Trip Setpoint is 10% RTP.

(m) For the Power Range Neutron Flux, P-10, the Allowable Value is <: 7.7% RTP and the Nominal Trip Setpoint is 10% RTP.

(n) A channel ;s OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3,3.1-18 Amendment No. 149 (Unit 1)

Amendment No. 129 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 of 9)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(n)

17. Reactor Trip 1,2 2 trains T,V SR 3.3.1.4 NA NA Breakers(k) 3(a), 4(a), 5(a) 2 trains C SR 3.3.1.4 NA NA

18. Reactor Trip 1,2 1 each per U,V SR 3.3.1.4 NA NA Breaker RTB Undervoltage and Shunt Trip 3(a), 4(a), 5(a) 1 each per C SR 3.3.1.4 NA NA Mechanisms RTB

19. Automatic Trip 1,2 2 trains Q,V SR 3.3.1.5 NA NA Logic 3(a), 4(a), 5(a) 2 trains C SR 3.3.1.5 NA NA (a) With RTBs closed and Rod Control System capable of rod withdrawal.

(k) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

(n) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.1-19 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 7 of 9)

Reactor Trip System Instrumentation Note 1: Overlemperature Delta-T The Allowable Value of each input to the Overlemperature Delta-T function as defined by the equation below shall not exceed its as-left value by more than the following:

(1) 0.5% t.T span for the t.T channel (2) 0.5% t.T span for the Ta,g channel (3) 0.5% t.T span for the pressurizer pressure channel (4) 0.5% t.T span for the f,(AFD) channel Where: t.T measured loop specific RCS differential temperature, degrees F t.To indicated loop specific RCS differential at RTP, degrees F 1+'1 S lead-lag compensator on measured differential temperature 1+'2S 1'1, 1'2 time constants utilized in lead-lag compensator for differential temperature: ') = 0 seconds,

'2 = 0 seconds

_1_

1+'3S lag compensator on measured differential temperature

'3 time constant utilized in lag compensator for differential temperature, S 6 seconds K1 fundamental setpoint, S 114.9% RTP K2 modifier for temperature, = 2.24% RTP per degree F 1 +'4S 1+'5S lead-lag compensator on dynamic temperature compensation 1'4, "['5 time constants utilized in lead-lag compensator for temperature compensation: '4 ~ 28 seconds,

'5 S 4 seconds T measured loop specific RCS average temperature, degrees F

_1_

1+'6S lag compensator on measured average temperature

'6 time constant utilized in lag compensator for average temperature, S 6 seconds T' indicated loop specific ReS average temperature at RTP. S 588.4 degrees F K3 modifier for pressure, = 0.177% RTP per psig P measured RCS pressurizer pressure, psig P' reference pressure. ~ 2235 psig s Laplace transform variable. inverse seconds Vogtle Units 1 and 2 3.3.1-20 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 8 of 9)

Reactor Trip System Instrumentation Note 1: Overtemperature Delta-T (continued) f,(AFD) modifier for Axial Flux Difference (AFD)

1. for AFD between -23% and +10%, = 0% RTP

2. for each % AFD is below -23%, the trip setpoint shall be reduced by 3.3% RTP

3. for each % AFD is above +10%, the trip setpoint shall be reduced by 1.95% RTP (0) The compensated temperature difference

{1+t 4 s}

{I + t5s}

[I T

{I + t6s}

- T'

] shall be no more negative than 3 degrees F.

Note 2: Overpower Delta-T The Allowable Value of each input to the Overpower Delta-T function as defined by the equation below shall not exceed its as-left value by more than the following:

(1) 0.5% tlT span for the tlT channel (2) 0.5% tlT span for the T. v" channel Where: tlT measured loop specific RCS differential temperature, degrees F tlT o indicated loop specific RCS differential at RTP, degrees F 1+t1S lead-lag compensator on measured differential temperature 1+t2S t1. t2 time constants utilized in lead-lag compensator for differential temperature: t, = 0 seconds, t2 = 0 seconds

_1_

1+t3S lag compensator on measured differential temperature t3 time constant utilized in lag compensator for differential temperature, ~ 6 seconds K, fundamental setpoint, ~ 110% RTP Ks modifier for temperature change: ;> 2% RTP per degree F for increasing temperature, ;> 0% RTP per degree F for decreasing temperature

--!Z.L 1+t7S rate-lag compensator on dynamic temperature compensation t7 time constant utilized in rate-lag compensator for temperature compensation, ;> 10 seconds T measured loop specific RCS average temperature, degrees F

_1_

1+t6S lag compensator on measured average temperature Vogtle Units 1 and 2 3.3.1-21 Amendment No. 128 (Unit 1)

Amendment 1\10. 106 (Unit 2)

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 9 of 9)

Reactor Trip System Instrumentation Note 2: Overtemperature Delta-T (continued) time constant utilized in lag compensator for average temperature, <:; 6 seconds K6 modifier for temperature: <': 0.244% RTP per degree F for T > T", =0% RTP for T <:; T" T" indicated loop specific ReS average temperature at RTP, <:; 588.4 degrees F s Laplace transform variable, inverse seconds modifier for Axial Flux Difference (AFD), = 0% RTP for all AFD Vogtle Units 1 and 2 3.3.1-22 Amendment No. 128 (Unit 1)

Amendment No. 106 (Unit 2)

ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2 1.

ACTIONS

NOTE----------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Enter the Condition Immediately with one or more required referenced in Table channels inoperable. 3.3.2-1 for the channel(s) or train(s).

B. One channel inoperable. B.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OPERABLE status.

OR B.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND B.2.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

Vogtle Units 1 and 2 3.3.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train inoperable. --------------------NOTE------------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

C.1 Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR C.2.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND C.2.2 Be in MODE 5. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months D. One channel inoperable. --------------------NOTE------------------

A channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

D.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR D.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND D.2.2 Be in MODE 4. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

Vogtle Units 1 and 2 3.3.2-2 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Containment ---------------------NO-rE-----------------

Pressure High-3 channel One additional channel may be inoperable. bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

E.1 Place channel in bypass. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND E.2.2 Be in MODE 4. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months F. One channel inoperable. F.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months OPERABLE status.

OR F.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND F.2.2 Be in MODE 4. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (continued)

Vogtle Units 1 and 2 3.3.2-3 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. One train inoperable. --------------------NOTE------------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

G.1 Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR G.2.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND G.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. One train inoperable. --------------------NOTE------------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

H.1 Restore train to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

OR H.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months (continued)

Vogtle Units 1 and 2 3.3.2-4 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. One channel inoperable. --------------------NOTE------------------

A channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

1.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 1.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months J. One Main Feedwater J.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Pumps trip channel OPERABLE status.

inoperable.

OR J.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months K. One RWST Level- Low --------------------NOTE------------------

Low channel inoperable. One additional channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

K.1 Place channel in bypass. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR K.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND K.2.2 Be in MODE 5. 108 hours0.00125 days 0.03 hours 1.785714e-4 weeks 4.1094e-5 months (continued)

Vogtle Units 1 and 2 3.3.2-5 Amendment No. 116 (Unit 1)

Amendment No. 94 (Unit 2)

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME L. One or more Pressurizer L.1 Verify interlock is in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Pressure, P-11 channels required state for existing inoperable. unit condition.

OR L.2.1 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months L.2.2 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months Vogtle Units 1 and 2 3.3.2-6 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS

NOTE--------------------------------------------------------

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.2.2 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.2.3 Perform MASTER RELAY TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.2.4 Perform COT. 184 days SR 3.3.2.5 Perform SLAVE RELAY TEST. 18 months SR 3.3.2.6 ----------------------------NOTE------------------------------

Verification of setpoint not required for manual initiation functions.

Perform TADOT. 18 months (continued)

Vogtle Units 1 and 2 3.3.2-7 Amendment No. 145 (Unit 1)

Amendment No. 125 (Unit 2)

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.7 ----------------------------NOTE------------------------------

This Surveillance shall include verification that the time constants used for the Steam Line Pressure instrument functions are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.2.8 ----------------------------NOTE------------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is

~ 900 psig.

Verify ESFAS RESPONSE TIMES are within limit. 18 months on a STAGGERED TEST BASIS SR 3.3.2.9 ----------------------------NOTE------------------------------

Verification of setpoint not required.

Perform TADOT. 18 months Vogtle Units 1 and 2 3.3.2-8 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

1. Safety Injection

a. Manual 1.2,3,4 2 B SR 3.32.6 NA NA Initiation

b. Automatic 1,2,3,4 2 C SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.25 Relays

c. Containment 1,2,3 3 D SR 3.3.2.1 ::; 4.4 psig 3.8 psig Pressure SR 3.3.2.4 High 1 SR 3.3.2.7 SR 3.3.2.8

d. Pressurizer 1,2,3(a) 4 D SR 33.2.1 ;:: 1856 psig 1870 psig Pressure - Low SR 3.3.2.4 SR 33.2.7 SR 3.3.28

e. Steam Line 1,2,3(a) 3 per steam D SR 3.3.2.1 ;:: 570(b) psig 585(b) psig Pressure - Low line SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.8 (continued)

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

(b) Time constants used in the lead/lag controller are t, ~ 50 seconds and 12 ,; 5 seconds.

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.2-9 Amendment NO.101 (Unit 1)

Amendment No. 79 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 33.2-1 (page 2 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

2. Containment Spray

a. Manual 1,2,3,4 2 B SR 3.3.2.6 NA NA Initiation

b. Automatic 1,2,3,4 2 C SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.25 Relays

c. Containment Pressure High - 3 1,2,3 4 E SR 3.32.1 ~ 22.4 psig 21.5 psig SR 3.3.2.4 SR 3.3.2.7 SR 3.3.2.8 (continued)

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.2-10 Amendment No.1 01 (Unit 1)

Amendment 1\10. 79 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

3. Phase A Containment Isolation (a) Manual 1,2,3,4 2 B SR 33.2.6 NA NA Initiation (b) Automatic 1,2,3,4 2 trains C SR 3.3.22 NA NA Actuation Logic SR 3.32.3 and Actuation SR 3.3.2.5 Relays (c) Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

4. Steam Line Isolation

a. Manual 1,2(c),3(c) 2 F SR 3.3.2.6 NA NA Initiation

b. Automatic 1,2(c),3(c) 2 G SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays (continued)

(c) Except when one main steam isolation valve and associated bypass isolation valve per steam line is closed.

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3,3.2-11 Amendment No.101(Unit 1)

Amendment No. 79 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.32-1 (page 4 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

4. Steam Line Isolation (continued)

c. Containment 3 D SR 332.1 ~ 15.4 psig 14.5 psig Pressure SR 3.3.2.4 High 2 SR 3.3.2.7 SR 3.3.2.8

d. Steam Line Pressure (1) Low 3 per steam D SR 3.3.2.1 ~ 570 (b) psig 585 (b) psig line SR 3.3.2.4 SR 33.27 SR 3.3.2.8 (2) Negative 3 per steam D SR 3.3.2.1 ~125(e) 100 (e)

Rate line SR 3.3.2.4 High psi/sec psi/sec SR 3.3.2.7 SR 3.3.2.8 (continued)

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

(b) Time constants used in the lead/lag controller are t, ~ 50 seconds and t2 ~ 5 seconds.

(c) Except when one main steam isolation valve and associated bypass isolation valve per steam line is closed.

(d) Below the P-11 (Pressurizer Pressure) interlock.

(e) Time constant utilized in the rate/lag controller is ~ 50 seconds.

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.2-12 Amendment NO.1 01 (Unit 1)

Amendment No. 79 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

5. Turbine Trip and Feedwater Isolation

a. Automatic 2 trains H SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays

b. Low RCS T 4 SR 3.3.2.1 ;:: 561.5 OF 564 OF avg SR 3.3.24 SR 3.3.2.7 Coincident with Refer to Function 8a for all P-4 requirements.

Reactor Trip, P-4

c. SG Water 4 per SG SR 3.3.2.1 5, 87.9% 86.0%

Level-High High SR 3.3.24 (P-14) SR 33.2.7 SR 3.3.2.8

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

6. Auxiliary Feedwater

a. Automatic 1,2,3 2 trains G SR 33.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays

b. SG Water 1,2,3 4 per SG D SR 3.3.2.1 ;:: 35.9% 37.8%

Level-Low Low SR 3.3.24 SR 3.3.2.7 SR 3.3.2.8 (continued)

(f) Except when one MFIV or MFRV, and its associated bypass valve per feedwater line is closed and deactivated or isolated by a closed manual valve.

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.2-13 Amendment NO.1 01 (Unit 1)

Amendment No. 79 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

6. Auxiliary Feedwater (continued)

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

d. Trip of all Main 1 per pump J SR 3.3.2.6 NA NA Feedwater Pumps

7. Semi-automatic Switchover to Containment Sump

a. Automatic 1,2,3,4(h) 2 C SR 3.3.2.2 NA NA Actuation Logic SR 3.3.2.3 and Actuation SR 3.3.2.5 Relays

b. Refueling 1,2,3,4 4 K SR 3.3.2.1 $ 216.6 in. 213.5 in.

Water Storage SR 3.3.2.4 and Tank (RWST) SR 3.3.2.7 ~ 210.4 in.

Level-Low SR 3.3.2.8 LowU)

Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection (continued)

(g) When the Main Feedwater System is operating to supply the SGs.

(h) In MODE 4, only 1 train is required to be OPERABLE to support semi-automatic switchover for the RHR pump that is required to be OPERABLE in accordance with Specification 3.5.3, ECCS-shutdown.

(i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

U) Two channels may be inoperable for a limited period of time during implementation of Amendments ill and 132 until four Required Channels have been adjusted for each unit.

Vogtle Units 1 and 2 3.3.2-14 Amendment No. 151 (Unit 1)

Amendment No. 132 (Unit 2)

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 7 of 7)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER NOMINAL SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE TRIP FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE SETPOINT(i)

8. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 1 per train, 2 F SR 3.3.2.9 NA NA trains

b. Pressurizer 1,2,3 3 L SR 33.2.4 ~ 2010 psig 2000 psig Pressure, P-11 SR 3.3.2.7 (i) A channel is OPERABLE with an actual Trip Setpoint value outside its calibration tolerance band provided the Trip Setpoint value is conservative with respect to its associated Allowable Value and the channel is readjusted to within the established calibration tolerance band of the Nominal Trip Setpoint. A Trip Setpoint may be set more conservative than the Nominal Trip Setpoint as necessary in response to plant conditions.

Vogtle Units 1 and 2 3.3.2-15 Amendment NO.1 01 (Unit 1)

Amendment No. 79 (Unit 2)

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE--------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more functions A.1 Enter the applicable Immediately with one or more Condition referenced in required channels Table 3.3.3-1 for the inoperable. channels.

B. -----------NOTE----------- B.1 Restore the channel to 30 days For containment OPERABLE status.

isolation valve position indication, separate Condition entry is allowed for each penetration flow path.

One required channel inoperable.

(continued)

Vogtle Units 1 and 2 3.3.3-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One RCS T hot channel C.1 Restore the channel to 30 days inoperable. OPERABLE status.

AND One channel of core exit temperature per quadrant OPERABLE.

D. One RCS T co1d channel D.1 Restore the channel to 30 days inoperable. OPERABLE status.

AND One channel of steam line pressure OPERABLE in the affected loop.

E. One SG Water Level E.1 Restore the channel to 30 days (wide range) channel OPERABLE status.

inoperable.

AND One channel of AFW flow to the affected SG OPERABLE.

(continued)

Vogtle Units 1 and 2 3.3.3-2 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One Steam Line F.1 Restore the channel to 30 days Radiation Monitor OPERABLE status.

channel inoperable.

AND One channel of SG Water Level (narrow range) OPERABLE in the affected loop.

G. Required Actions and G.1 Initiate action in accordance Immediately associated Completion with Specification 5.6.8.

Times of Conditions B, C, D, E, or F not met.

H. -----------NOTE----------- H.1 Restore at least one 7 days For containment channel to OPERABLE isolation valve position status.

indication, separate Condition entry is allowed for each penetration flow path.

Two channels inoperable.

OR (continued)

Vogtle Units 1 and 2 3.3.3-3 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

PAM Instrumentation 3.3.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME H. (continued)

NOTE----------

Applicable to those functions with only one required channel per loop, SG, or steam line.

One channel inoperable and no diverse channel OPERABLE.

I. ---------- NOTE------ ---- 1.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Not applicable to Containment Radiation and RVLlS functions.

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

J. -----------NOTE----------- J.1 Initiate action in accordance Immediately Applicable to with Specification 5.6.8.

Containment Radiation and RVLlS functions only.

Required Action and asociated Completion Time of Condition H not met.

Vogtle Units 1 and 2 3.3.3-4 Amendment No. 134 (Unit 1)

Amendment No. 113 (Unit 2)

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

NOTE-----------------------------------------------------------

SR 3.3.3.1 and SR 3.3.3.2 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel.

SR 3.3.3.2 ----------------------------NOTE------------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months Vogtle Units 1 and 2 3.3.3-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post Accident Monitonng Instrumentation FUNCTION REQUIRED CHANNELS CONDITIONS

1. Reactor Coolant System (RCS) Pressure (wide range) 2 B,G,H,I

2. RCS Too, (wide range) 1/100p C,G,H,I

3. RCS T cold (wide range) 1/100p D,G,H,I

4. Steam Generator (SG) Water Level (wide range) 1/SG E,G,H,I

5. SG Water Level (narrow range) 21SG B,G,H,I

6. Pressurizer Level 2 B,G,H,I

7. Containment Pressure 2 B,G,H,I

8. Steam line Pressure 21steam line B,G,H,I

9. Refueling Water Storage Tank (RWST) Level 2 B,G,H,I

10. Containment Normal Sumps Level (narrow range) 2 B,G,H,I

11. Containment Water Level (wide range) 2 B,G,H,I

12. Condensate Storage Tank Level 2/tanklal B,G,H,I

13. Auxiliary Feedwater Flow 21SG B,G,H,I

14. Containment Radiation Level (high range) 2 B,G,H,J

15. Steam line Radiation Monitor 1/steam line F,G,H,I

16. RCS Subcooling 2 B,G,H,I

17. Neutron Flux (extended range) 2 B,G,H,I

18. Reactor Vessel Water Level (RVLlS) 2 B,G,H,J

19. Deleted

20. Containment Pressure (extended range) 2 B,G,H,I

21. Containment Isolation Valve Position 2/penetration flow path 1b ) lei B,G,H,I

22. Core Exit Temperature* Quadrant 1 2(dl B,G,H,I

23. Core Exit Temperature - Quadrant 2 21d ) B,G,H,I

24. Core Exit Temperature* Quadrant 3 2 1d ) B,G,H,I

25. Core Exit Temperature - Quadrant 4 21dl B,G,H,I (a) Only required for the OPERABLE tank.

(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.

Applicable for containment isolation valve position indication designated as post-accident monitoring instrumentation (containment isolation valves which receive containment isolation phase A or containment ventilation isolation signals).

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

(d) A channel consists of two core exit thermocouples (CETs).

Vogtle Units 1 and 2 3.3.3-6 Amendment No. 134 (Unit 1)

Amendment No. 113 (Unit 2)

Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remote Shutdown System Functions in Table 3.3.4-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE-----------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function 30 days Functions inoperable. to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.3.4-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required 31 days monitoring instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required control circuit and transfer 18 months switch is capable of performing the intended function.

SR 3.3.4.3 ----------------------------N()TE------------------------------

Neutron detectors are excluded from CHANNEL CALIBRATI()N.

Perform CHANNEL CALIBRATI()N for each 18 months required monitoring instrumentation channel.

Vogtle Units 1 and 2 3.3.4-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of 1)

Remote Shutdown System Instrumentation and Controls FUNCTION/INSTRUMENT REQUIRED OR CONTROL PARAMETER NUMBER OF CHANNELS MONITORING INSTRUMENTATION

1. Source Range Neutron Flux

2. Extended Range Neutron Flux

3. RCS Cold Leg Temperature 1/loop

4. RCS Hot Leg Temperature 2

5. Core Exit Thenmocouples 2

6. RCS Wide Range Pressure 2

7. Steam Generator Level Wide Range 1/loop

8. Pressurizer Level 2

9. RWST Level

10. BAST level

11. CST Level 1/tank!a) lei

12. Auxiliary Feedwater Flow 1/loop

13. Steam Generator Pressure 1/loop TRANSFER AND CONTROL CIRCUITS

1. Reactivity Control (b)

2. RCS Pressure Control (b)

3. Decay Heat Removal

a. Auxiliary Feedwater (b)

b. Steam Generator Atmospheric Relief Valve ld ) (b)

4. RCS Inventory/Charging System (b)

5. Safety support systems required for the above functions (b)

(a) Alternate local level indication may be established 10 fulfill the required number of channels.

(b) The required channels include the transfer switches and control circuits necessary to place and maintain the unit in a safe shutdown condition using safety grade components.

(c) Only required for the OPERABLE tank.

(d) Refer also to LCO 3.7.4.

Vogtle Units 1 and 2 3.3.4-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

LOP Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 4.16 kV ESF Bus Loss of Power (LOP) Instrumentation LCO 3.3.5 Four channels per bus of the loss of voltage Function and four channels per bus of the degraded voltage Function shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4, When associated Diesel Generator is required to be OPERABLE by LCO 3.8.2, "AC Sources-Shutdown."

ACTIONS

NOTE-----------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions --------------------NOTE------------------

with only one channel on A channel may be bypassed for up one or both buses to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing.

inoperable. -----------------------------------------------

A.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B. One or more Functions B.1 Restore at least three 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with two or more channels to OPERABLE channels on one bus status.

inoperable.

C. One or more Functions C.1 Restore at least three 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two or more channels on one bus to channels on two buses OPERABLE status.

inoperable.

(continued)

Vogtle Units 1 and 2 3.3.5-1 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

LOP Instrumentation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Actions and 0.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times not met in MODES AND 1,2,3, or 4.

0.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Required Action and E.1 Enter applicable Immediately associated Completion Condition(s) and Time not met when the Required Action(s) for the associated DG is associated DG made required OPERABLE by inoperable by LOP DG LCO 3.8.2. start instrumentation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform COT. 92 days SR 3.3.5.2 Perform CHANNEL CALIBRATION with Nominal Trip 18 months Setpoint and Allowable Value as follows:

A. Loss of voltage Allowable Value ~ 2912 V with a time delay of ~ 0.8 second.

Loss of voltage Nominal Trip Setpoint 2975 V with a time delay of ~ 0.8 second.

B. Degraded voltage Allowable Value ~ 3683 V with a time delay of ~ 20 seconds.

Degraded voltage Nominal Trip Setpoint 3746 V with a time delay of ~ 20 seconds.

(continued)

Vogtfe Units 1 and 2 3.3.5-2 Amendment No. 111 (Unit 1)

Amendment No. 89 (Unit 2)

LOP Instrumentation 3.3.5 SURVEILLANCE FREQUENCY SR 3.3.5.3 -----------------------------NOTE--------------------------------

Not required to be performed for the turbine-driven Auxiliary Feedwater (AFW) pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after Steam Generator pressure is ~ 900 psig.

Verify AFW system ESF RESPONSE TIME for loss 18 months on a of voltage and degraded voltage on the 4.16 kV ESF STAGGERED buses within limit. TEST BASIS Vogtle Units 1 and 2 3.3.5-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Ventilation Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Containment Ventilation Isolation Instrumentation LCO 3.3.6 The Containment Ventilation Isolation instrumentation for each Function in Table 3.3.6-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6-1.

ACTIONS

NO-rE-------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. Only one radiation A.1 Restore at least two channels 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months monitoring channel to OPERABLE status.

OPERABLE.

(continued)

Vogtle Units 1 and 2 3.3.6-1 Amendment No. 105 (Unit 1)

Amendment No. 83 (Unit 2)

Containment Ventilation Isolation Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. ------------NOTE------------- B.1 Enter applicable Immediately Only applicable in Conditions and Required MODE 1, 2, 3, or 4. Actions of LCO 3.6.3, "Containment Isolation Valves," for containment One or more Functions purge supply and exhaust with one or more manual isolation valves made or automatic actuation inoperable by isolation channels inoperable. instrumentation.

No radiation monitoring channels OPERABLE.

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

(continued)

Vogtle Units 1 and 2 3.3.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Ventilation Isolation Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ------------NOTE------------- C.1 Place and maintain Immediately Only applicable during containment purge and CORE ALTERATIONS or exhaust valves in closed movement of irradiated position.

fuel assemblies within containment. OR No radiation monitoring C.2 Enter applicable Immediately channels OPERABLE. Conditions and Required Actions of LCO 3.9.4, "Containment Penetrations," for Required Action and containment purge supply associated Completion and exhaust isolation Time for Condition A not penetrations not in met. required status.

Vogtle Units 1 and 2 3.3.6-3 Amendment No. 105 (Unit 1)

Amendment No. 83 (Unit 2)

Containment Ventilation Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS

NOTE--------------------------------------------------------

Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Purge and Exhaust Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.6.2 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.6.3 Perform MASTER RELAY TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.6.4 Perform COT. 92 days SR 3.3.6.5 Perform SLAVE RELAY TEST. 18 months SR 3.3.6.6 -----------------------NOTE-----------------------------------

Verification of setpoint not required.

Perform TADOT. 18 months SR 3.3.6.7 Perform CHANNEL CALIBRATION. 18 months SR 3.3.6.8 Verify RESPONSE TIMES are within limits. 18 months on a STAGGERED TEST BASIS Vogtle Units 1 and 2 3.3.6-4 Amendment 1\10. 145 (Unit 1)

Amendment No. 125 (Unit 2)

Containment Ventilation Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)

Containment Ventilation Isolation Instrumentation APPLICABLE MODES OR OTHER REQUIRED SURVEILLANCE FUNCTION SPECIFIED CHANNELS REQUIREMENTS TRIP SETPOINT CONDITIONS

1. Manual Initiation 1,2,3,4 2 SR 3.36.6 NA

2. Automatic Actuation Logic SR 3.3.6.2 NA and Actuation Relays 1,2,3,4 2 SR 33.63 SR 3.3.6.5

3. Containment Radiation SR 3.3.6.1 SR 3.3.6.4 1,2,3,4,6(c) SR 3.3.6.7 SR 3.3.68 (b)

a. Gaseous (RE-2565C)

(b)

b. Particulate (RE-2565A)

(b)

c. Iodine (RE-2565B)

~ 15 mr/h(c)

d. Area Low Range

~ 50x background(d)

(RE-0002, RE-0003)

4. Safety Injection(d) 1,2,3,4 Refer to LCO 3.3.2, "ESFAS Instrumentation,"Function 1, for all initiation functions and requirements.

(a) Containment ventilation radiation (RE-2565) is treated as one channel and is considered OPERABLE if the particulate (RE-2565A) and iodine monitors (RE-2565B) are OPERABLE or the noble gas monitor (RE-2565C) is OPERABLE.

(b) Setpoints will not exceed the limits of Specifications 5.5.4.h and 5.5.4.i of the Radioactive Effluent Controls Program.

(c) During CORE ALTERATIONS and movement of irradiated fuel assemblies within containment.

(d) During MODES 1, 2, 3, and 4.

Vogtle Units 1 and 2 3.3.6-5 Amendment No. 105 (Unit 1)

Amendment No. 83 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 3.3 INSTRUMENTATION 3.3.7 Control Room Emergency Filtration System (CREFS) Actuation Instrumentation LCO 3.3.7 The CREFS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

APPLICABILITY: Either unit in MODES 1, 2, 3, or 4, During movement of irradiated fuel assemblies in either unit, During CORE ALTERATIONS in either unit.

ACTIONS

NOTE-------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. Required manual A.1 Restore channel to 7 days initiation channel OPERABLE status.

inoperable.

B. Required Action and B.1 Place one CREFS train in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion the emergency mode.

Time for Condition A not met.

C. One automatic actuation C.1 Restore the channel to 7 days logic/relay channel OPERABLE status.

inoperable in one unit.

D. Required Action and D.1 Place one CREFS train in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion the unaffected unit in the Time for Condition C not emergency mode.

met.

(continued)

Vogtle Units 1 and 2 3.3.7-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One automatic actuation E.1 Restore both channels to 7 days logic/relay channel OPERABLE status.

inoperable in each unit.

F. Required Action and F.1 Place one CREFS train in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion each unit in the Time for Condition E not emergency mode.

met.

G. Two automatic actuation G.1 Place two CREFS trains in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months logic/relay channels the unaffected unit in the inoperable in one unit. emergency mode.

OR G.2 Place one CREFS train in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months each unit in the emergency mode.

H. Three automatic H.1 Place two CREFS trains in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months actuation logic/relay the unit with one channels inoperable. inoperable channel in the emergency mode.

I. Four automatic 1.1 Place two CREFS trains in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months actuation logic/relay the emergency mode.

channels inoperable.

J. One intake radiogas J.1 Restore channel to 7 days monitor channel OPERABLE status.

inoperable in one unit.

(contInued)

Vogtle Units 1 and 2 3.3.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME K. Required Action and K.1 Lock closed the affected 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion and lock open the Time for Condition J not unaffected outside air met. (OSA) intake dampers.

OR K.2 Place one train of CREFS 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months in the emergency mode.

L. One intake radiogas L.1 Restore both channels to 7 days monitor channel OPERABLE status.

inoperable in each unit.

M. Required Action and M.1 Place one CREFS train in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion the emergency mode.

Time for Condition L not met.

N. Two intake radiogas N.1 Lock closed the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months monitor channels and lock open the inoperable in one unit. unaffected OSA intake dampers.

OR N.2 Place one CREFS train in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months each unit in the emergency mode.

(continued)

Vogtle Units 1 and 2 3.3.7-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME O. Three intake radiogas 0.1 Place one CREFS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months monitor channels train in each unit in the inoperable. emergency mode.

OR 0.2.1 Lock closed the OSA 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months intake dampers of the unit with two inoperable channels and lock open the other OSA intake dampers.

AND 0.2.2.1 Restore the single 7 days inoperable channel associated with the locked open OSA intake dampers to OPERABLE status.

OR 0.2.2.2 Place one CREFS 7 days train in the emergency mode.

P. Four intake radiogas P.1 Place one CREFS train in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months monitor channels each unit in the inoperable. emergency mode.

Vogtle Units 1 and 2 3.3.7-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS

NOTE------------------------------------------------

Refer to Table 3.3.7-1 to determine which SRs apply for each CREFS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.7.2 Perform COT. 92 days SR 3.3.7.3 Perform ACTUATION LOGIC TEST. 31 days on a STAGGERED TEST BASIS SR 3.3.7.4 -------------------------NOTE-------------------------------

Verification of setpoint is not required.

Perform TADOr. 18 months SR 3.3.7.5 Perform CHANNEL CALIBRATION. 18 months SR 3.3.7.6 Verify ESF RESPONSE TIME for radio-gas 18 months on a monitors within limit. STAGGERED TEST BASIS Vogtle Units 1 and 2 3.3.7-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS Actuation Instrumentation 3.3.7 Table 3.3.7-1 (page 1 of 1)

CREFS Actuation Instrumentation SURVEILLANCE FUNCTION REQUIRED CHANNELS REQUIREMENTS TRIP SETPOINT

1. Manual Initiation SR 3.3.7.4 NA

2. Automatic Actuation Logic and 4 (2 per unit) SR 3.3.7.3 NA Actuation Relays

3. Control Room Air Intake 4 (2 per unit) SR 3.3.7.1 3 x background Radiogas Monitors SR 3.3.7.2 SR 3.3.7.5 SR 3.3.7.6

4. Safety Injection Refer to LeO 3.3.2, "ESFAS Instrumentation," Function 1, for all initiation functions and requirements.

Vogtle Units 1 and 2 3.3.7-6 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

High Flux at Shutdown Alarm 3.3.8 3.3 INSTRUMENTATION 3.3.8 High Flux at Shutdown Alarm (HFASA)

LCO 3.3.8 Two channels of HFASA shall be OPERABLE.

APPLICABILITY: MODES 3, 4, and 5

NOTE----------------------------------------

The HFASA may be blocked in MODE 3 during reactor startup.

ACTIONS COMPLETION CONDITION REQUIRED ACTION TIME A. One channel of HFASA A.1 ------------------N 0 TE---------------

inoperable. LCO 3.0Ac is applicable provided Required Actions B.1 and B.2 are met.

Restore channel to OPERABLE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months status.

B. Required Action and B.1 Perform SR 3.1.1.1 (verify 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion SDM).

Time of Condition A not AND met.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter OR Two channels of AND HFASA inoperable.

B.2 Perform SR 3.9.2.1 (verify 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months unborated water source isolated). AND Once per 14 days thereafter Vogtle Units 1 and 2 3.3.8-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

High Flux at Shutdown Alarm 3.3.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

NOTE----------------------------

Not required to be performed prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

SR 3.3.8.1 Perform COT. 184 days SR 3.3.8.2 Perform CHANNEL CALIBRATION. 18 months Vogtle Units 1 and 2 3.3.8-2 Amendment No. 145 (Unit 1)

Amendment No. 125 (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified below:

a. Pressurizer pressure;::: 2199 psig;

b. RCS average temperature ~ 592.5 F; and 0

c. RCS total flow rate;::: 384,509 gpm.

APPLICABILITY: MODE 1.

NOTE--------------------------------------------------

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp> 5% RTP per minute; or

b. THERMAL POWER step> 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months parameters not within parameter(s) to within limits. limit.

B. RCS total flow rate B.1. Perform SR 3.4.1.4. 7 days degraded.

C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

Vogtle Units 1 and 2 3.4.1-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is ~ 2199 psig. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.2 Verify RCS average temperature is ~ 592.5°F. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.3 Monitor RCS total flow rate for degradation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.1.4 ---------------------------NOTE------------------------------

Not required to be performed until 7 days after

~ 90% RTP.

Verify by precision heat balance that RCS total 18 months flow rate is ~ 384,509 gpm.

Vogtle Units 1 and 2 3.4.1-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop average temperature (T avg ) shall be ~ 551°F.

APPLICABILITY: MODE 1, MODE 2 with kef! ~ 1.0.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. T avg in one or more RCS A.1 Be in MODE 3. 30 minutes loops not within limit.

SURVEILLANCE REQUIREMENTS SU RVEI LLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each loop ~ 551°F. Once within 30 minutes and every 30 minutes thereafter when the T avg - T ref deviation alarm is not reset and any RCS loop Tavg < 561°F Vogtle Units 1 and 2 3.4.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIT Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR.

APPLICABILITY: At all times.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -----------NOTE------------ A.1 Restore parameter(s) to 30 minutes Required Action A.2 within limits.

shall be completed whenever this Condition AND is entered.

A.2 Determine RCS is 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months acceptable for continued Requirements of LCO operation.

not met in MODE 1, 2, 3, or 4.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5 with RCS 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months pressure < 500 psig.

(continued)

Vogtle Units 1 and 2 3.4.3-1 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

RCS PIT Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. ------------NOTE----------- C.1 Initiate action to restore Immediately Required Action C.2 parameter(s) to within shall be completed limits.

whenever this Condition is entered. AND C.2 Determine RCS is Prior to entering Requirements of LCO acceptable for continued MODE 4 not met any time in other operation.

than MODE 1, 2, 3, or 4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ----------------------------NOTE-----------------------------

Only required to be performed during RCS heatup and cooldown operations and RCS inservice leak and hydrostatic testing.

Verify RCS pressure, RCS temperature, and RCS 30 minutes heatup and cooldown rates are within the limits specified in the PTLR.

Vogtle Units 1 and 2 3.4.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY; MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.4.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops - MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either:

a. Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal; or

b. One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.

NOTE--------------------------------------------

All reactor coolant pumps may be de-energized for ~ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

APPLICABILITY: MODE 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required RCS loop A.1 Restore required RCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. loop to OPERABLE status.

B. Required Action and B.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

(continued)

Vogtle Units 1 and 2 3.4.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop C.1 Restore required RCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not in operation, and loop to operation.

reactor trip breakers closed and Rod Control OR System capable of rod withdrawal. C.2 De-energize all control 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months rod drive mechanisms (CRDMs).

D. Two required RCS loops D.1 De-energize all CRDMs. Immediately inoperable.

AND OR D.2 Suspend all operations Immediately No RCS loop in involving a reduction of operation. RCS boron concentration.

AND D.3 Initiate action to restore Immediately one RCS loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Vogtle Units 1 and 2 3.4.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.5.2 Verify steam generator secondary side water 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months levels are above the highest point of the steam generator U-tubes for required RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated 7 days power are available to the required pump that is not in operation.

Vogtle Units 1 and 2 3.4.5-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops - MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

NOTES---------------------------------------------

1. All reactor coolant pumps (RCPs) and RHR pumps may be de-energized for :-:; 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. An RCP shall not be started with any RCS cold leg temperature :-:; the Cold Overpressure Protection System (COPS) arming temperature specified in the PTLR, unless the secondary side water temperature of each steam generator (SG) is < 50°F above each of the RCS cold leg temperatures. With the RHR suction isolation valves open, this value is reduced to 25°F at an RCS temperature of 350°F and varies linearly to 50°F at an RCS temperature of 200°F.

APPLICABILITY: MODE 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required RCS loop A.1 Initiate action to restore a Immediately inoperable. second loop to OPERABLE status.

Two RHR loops inoperable.

(continued)

Vogtle Units 1 and 2 3.4.6-1 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

RCS Loops - MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required RHR loop B.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable.

AND Two required RCS loops inoperable.

C. Both required RCS or C.1 Suspend all operations Immediately RHR loops inoperable. involving a reduction of RCS boron concentration.

OR AND No RCS or RHR loop in operation. C.2 Initiate action to restore Immediately one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side water levels are above 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the highest point of the steam generator U-tubes for required RCS loops.

(continued)

Vogtle Units 1 and 2 3.4.6-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

RCS Loops - MODE 4 3.4.6 FREQUENCY SR 3.4.6.3 Verify correct pump breaker alignment and 7 days indicated power are available to the required pump that is not in operation.

Vogtle Units 1 and 2 3.4.6-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops-MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side water level of at least two steam generators (SGs) shall be above the highest point of the steam generator U tubes.

NOTES-------------------------------------------

1. The RHR pump of the loop in operation may be de-energized for

$ 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause reduction of the RCS boron concentration; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. One required RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. No reactor coolant pump shall be started unless the secondary side water temperature of each SG is < 50°F above each of the RCS cold leg temperatures.

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled.

Vogtle Units 1 and 2 3.4.7-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, One RHR loop A,1 Initiate action to restore a Immediately inoperable. second RHR loop to OPERABLE status.

AND OR Required SGs secondary side water A,2 Initiate action to restore Immediately levels not within limits. required SG secondary side water levels to within limits.

B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving a reduction of RCS boron concentration.

OR AND No RHR loop in operation. B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is above the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months highest point of the steam generator U-tubes for the required SGs.

(conti nued)

Vogtle Units 1 and 2 3.4.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE FREQUENCY SR 3.4.7.3 Verify correct breaker alignment and indicated 7 days power are available to the required RHR pump that is not in operation.

Vogtle Units 1 and 2 3.4.7-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Loops - MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops - MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation. Each valve used to isolate unborated water sources shall be secured in the closed position.

NOTES------------------------------------------

1. All RHR pumps may be de-energized for ~ 15 minutes when switching from one loop to another provided:

a. The core outlet temperature is maintained> 10°F below saturation temperature.

b. No operations are permitted that would cause a reduction of the RCS boron concentration; and

c. No draining operations to further reduce the RCS water volume are permitted.

2. One RHR loop may be inoperable for ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided that the other RHR loop is OPERABLE and in operation.

3. Valves in the flowpath from the RMWST, through the chemical mixing tank, to the suction of the charging pumps may be open under administrative control provided the RCS is in compliance with the SHUTDOWN MARGIN requirements of LCO 3.1.1 and the high flux at shutdown alarm is OPERABLE.

APPLICABILITY: MODE 5 with RCS loops not filled.

(continued)

Vogtle Units 1 and 2 3.4.8-1 Amendment No. 108 (Unit 1)

Amendment No. 86 Unit 2)

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable. A.1 Initiate action to restore Immediately RHR loop to OPERABLE status.

B. Required RHR loops B.1 Suspend all operations Immediately inoperable. involving reduction in RCS boron concentration.

OR AND No RHR loop in operation.

B.2 Initiate action to restore Immediately one RHR loop to OPERABLE status and to operation.

C. One or more valves used C.1 Initiate action to secure Immediately to isolate unborated water valve(s) in closed sources not secured in position.

closed position.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power 7 days are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify each valve that isolates unborated water 31 days sources is secured in the closed position.

Vogtle Units 1 and 2 3.4.8-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level ~ 92%; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group ~ 150 kW and capable of being powered from an emergency power supply.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level A.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months not within limit. reactor trip breakers open.

AND A.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. One required group of B.1 Restore required group of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer heaters pressurizer heaters to inoperable. OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not AND met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.4.9-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer 3.4.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is ~ 92%. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.9.2 Verify capacity of each required group of 18 months pressurizer heaters is ~ 150 kW.

Vogtle Units 1 and 2 3.4.9-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings

~ 2410 psig and :s; 2510 psig.

APPLICABILITY: MODES 1, 2, and 3.

MODE 4 with all RCS cold leg temperatures> the COPS arming temperature specified in the PTLR.

NOTE-------------------------------------------------

The lift settings are not required to be within the LCO limits during MODE 3 and MODE 4 with all RCS cold leg temperatures> the COPS arming temperature specified in the PTLR for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RCS cold leg temperature Two or more pressurizer s the COPS arming safety valves inoperable. temperature specified in the PTLR.

Vogtle Units 1 and 2 3.4.10-1 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is In accordance with OPERABLE in accordance with the Inservice the Inservice Testing Program. Following testing, lift settings Testing Program shall be within +/- 1%.

Vogtle Units 1 and 2 3.4.10-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Pressurizer PORVs 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE-----------------------------------------------------------

Separate Condition entry is allowed for each PORV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain power 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and capable to associated block valve.

of being manually cycled.

B. One PORV inoperable B.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being valve.

manually cycled.

AND B.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valve.

AND B.3 Restore PORV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

Vogtle Units 1 and 2 3.4.11-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One block valve C.1 Place associated PORV 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. in manual control.

AND C.2 Restore block valve to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, B, AND or C not met.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two PORVs inoperable E.1 Close associated block 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and not capable of being valves.

manually cycled.

AND E.2 Remove power from 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated block valves.

AND E.3 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.4 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. More than one block F.1 Place associated PORVs 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months valve inoperable. in manual control.

AND (continued)

Vogtle Units 1 and 2 3.4.11-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) F.2 Restore one block valve 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to OPERABLE status.

AND F.3 Restore remaining 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months block valve to OPERABLE status.

G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition F not AND met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 --------------------------NOTE-------------------------------

Not required to be performed with block valve closed in accordance with the Required Action of Conditions A, B, or E.

Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 Perform a complete cycle of each PORV. 18 months Vogtle Units 1 and 2 3.4.11-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Cold Overpressure Protection Systems (COPS)

LCO 3.4.12 A COPS shall be OPERABLE with all safety injection pumps incapable of injecting into the RCS and the accumulators isolated and either a or b below.

a. Two RCS relief valves, as follows:

1. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

2. Two residual heat removal (RHR) suction relief valves with setpoints

~ 440 psig and ~ 460 psig, or

3. One PORV with a lift setting within the limits specified in the PTLR and one RHR suction relief valve with a setpoint within specified limits.

b. The RCS depressurized and an RCS vent of ~ 1.5 square inches (based on an equivalent length of 10 feet of pipe).

APPLICABILITY: MODE 4 with any RCS cold leg temperature :s; the COPS arming temperature specified in the PTLR, MODE 5, MODE 6 when the reactor vessel head is on.

NOTE---------------------------------------------

Accumulator isolation is only required when accumulator pressure is greater than or equal to the maximum RCS pressure for the eXisting RCS cold leg temperature allowed by the PIT limit curves provided in the PTLR.

Vogtle Units 1 and 2 3.4.12-1 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

COPS 3.4.12 ACTIONS

NOTE---------------------------------------------------------------

LCO 3.0.4b is not applicable for entry into MODE 4, entry into MODE 6 with reactor vessel head on from MODE 6, and entry into MODE 5 from MODE 6 with the reactor vessel head on.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safety A.1 Render all safety injection 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months injection pumps capable pumps incapable of injecting of injecting into the RCS. into the RCS.

B. An accumulator not B.1 Isolate affected accumulator. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months isolated when the accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

C. Required Action and C.1 Increase RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion temperature to > the COPS Time of Condition B not arming temperature specified met. in the PTLR.

OR C.2 Depressurize affected 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator to less than the maximum RCS pressure for eXisting cold leg temperature allowed in the PTLR.

D. One required RCS relief D.1 Restore required RCS relief 7 days valve inoperable in valve to OPERABLE status.

MODE 4 with any RCS cold leg temperature S the COPS arming temperature specified in the PTLR.

(continued)

Vogtle Units 1 and 2 3.4.12-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

COPS 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One required RCS relief E.1 Restore required RCS 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable in relief valve to OPERABLE MODE 5 or6. status.

F. Two required RCS relief F.1 Depressurize RCS and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months valves inoperable. establish RCS vent size within specified limits.

OR Required Action and associated Completion Time of Condition A, C, D, or E not met.

OR COPS inoperable for any reason other than Condition A, B, D, or E.

Vogtle Units 1 and 2 3.4.12-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

COPS 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify both safety injection pumps are incapable 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of injecting into the RCS.

SR 3.4.12.2 Verify each accumulator is isolated. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.12.3 Verify RHR suction valves are open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required RHR suction relief valve.

SR 3.4.12.4 ---------------------------NOTE------------------------------

Only required to be performed when complying with LCO 3.4.12.b.

Verify RCS vent size within specified limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent valve(s) 31 days for locked open vent valve(s)

(continued)

Vogtle Units 1 and 2 3.4.12-4 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

COPS 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.5 Verify PORV block valve is open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required PORV.

SR 3.4.12.6 -----------------------------NOTE----------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing RCS cold leg temperature to ~ the COPS arming temperature specified in the PTLR.

Perform a COT on each required PORV, 31 days excluding actuation.

SR 3.4.12.7 Perform CHANNEL CALIBRATION for each 18 months required PORV actuation channel.

Vogtle Units 1 and 2 3.4.12-5 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational A.1 Reduce LEAKAGE to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months LEAKAGE not within within limits.

limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limit.

Vogtle Units 1 and 2 3.4.13-1 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ------------------------------NOTES-------------------------

1. Not required to be performed in MODE 3 or 4 until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of steady state operation.

2. Only required to be performed during steady state operation.

3. Not applicable to primary to secondary LEAKAGE.

Perform RCS water inventory balance. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after achieving steady state operation 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months thereafter SR 3.4.13.2 -----------------------------NOTE--------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is :s; 150 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months gallons per day through anyone SG.

Vogtle Units 1 and 2 3.4.13-2 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from the RHR mode of operation.

ACTIONS

NOTES-----------------------------------------------------------

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths --------------------NOTE------------------

with leakage from one or Each valve used to satisfy Required more RCS PIVs not Action A.1 and Required Action A.2 within limit. must have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

(continued)

Vogtle Units 1 and 2 3.4.14-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIV Leakage 3.4.14 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1 Isolate the high pressure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months portion of the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND A.2 Isolate the high pressure 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months portion of the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. RHR System suction C.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months isolation valve penetration by use of one interlock function closed manual or inoperable. deactivated automatic valve.

Vogtle Units 1 and 2 3.4.14-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 ----------------------------N()TES---------------------------

1. Not required to be performed in M()DES 3 and 4.

2. Not required to be performed on the RCS PIVs located in the RHR flow path when in the shutdown cooling mode of operation.

3. RCS PIVs actuated during the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent In accordance with to :5 0.5 gpm per nominal inch of valve size up to the Inservice Testing a maximum of 5 gpm at an RCS pressure Program, and

~ 2215 psig and :5 2255 psig. 18 months Prior to entering M()DE 2 whenever the unit has been in M()DE 5 for 7 days or more, if leakage testing has not been performed in the previous 9 months (except for valves HV 8701A1B and HV 8702A1B)

AND Vogtle Units 1 and 2 3.4.14-3 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 (continued) For systems rated at less than 50% RCS design pressure, within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation (except for valves HV-8701A/B and HV-8702A/B).

SR 3.4.14.2 Verify RHR System suction isolation valve 18 months interlock prevents the valves from being opened with a simulated or actual RCS pressure signal

~ 450 psig.

Vogtle Units 1 and 2 3.4.14-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. The containment normal sumps level and reactor cavity sump monitors;

b. One containment atmosphere radioactivity monitor (gaseous or particulate); and

c. Either the containment air cooler condensate flow rate or a containment atmosphere gaseous or particulate radioactivity monitoring system not taken credit for in item b.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment sump A.1 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months monitor inoperable.

B. Two or more B.1 Perform SR 3.4.13.1 Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months containment sump monitors inoperable AND B.2 Restore at least two 30 days containment sump monitors to OPERABLE status.

(continued)

Vogtle Units 1 and 2 3.4.15-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required containment C.1.1 Analyze grab samples of Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere radioactivity the containment monitor(s) inoperable. atmosphere.

OR C.1.2 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND C.2.1 Restore required 30 days containment atmosphere radioactivity monitor(s) to OPERABLE status.

OR C.2.2 Verify containment air 30 days cooler condensate flow rate monitor is OPERABLE.

D. Required containment D.1 Perform SR 3.4.15.2. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months air cooler condensate flow rate monitor OR inoperable.

D.2 Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (continued)

Vogtle Units 1 and 2 3.4.15-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required containment E.1 Restore required 30 days atmosphere radioactivity containment atmosphere monitor inoperable. radioactivity monitor to OPERABLE status.

AND OR Required containment air cooler condensate E.2 Restore required 30 days flow rate monitor containment air cooler inoperable. condensate flow rate monitor to OPERABLE status.

F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND F.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months G. All required leakage G.1 Enter LCO 3.0.3. Immediately detection systems inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months normal sumps level and reactor cavity sump level monitors.

(continued)

Vogtle Units 1 and 2 3.4.15-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.15.2 Perform CHANNEL CHECK of the required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months containment atmosphere radioactivity monitor.

SR 3.4.15.3 Perform COT of the required containment 92 days atmosphere radioactivity monitor.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the 18 months containment sump monitors.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the 18 months required containment atmosphere radioactivity monitor.

SR 3.4.15.6 Perform CHANNEL CALIBRATION of the 18 months required containment air cooler condensate flow rate monitor.

Vogtle Units 1 and 2 3.4.15-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS average temperature (T avg ) ~ 500°F.

ACTIONS

NOTE---------------------------------------------------------

LCO 3.0.4c is applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT A.1 Verify DOSE Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months 1-131 > 1.0 I-lCi/gm. EQUIVALENT 1-131 within the acceptable region of Figure 3.4.16-1.

AND A.2 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT 1-131 to within limit.

B. Gross specific activity of B.1 Perform SR 3.4.16.2. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the reactor coolant not within limit. AND B.2 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months T avg < 500°F.

(continued)

Vogtle Units 1 and 2 3.4.16-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3 with 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion T avg < 500°F.

Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific 7 days activity ~ 1OOIE jlCi/gm.

SR 3.4.16.2 ----------------------------NOTE----------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 14 days specific activity ~ 1.0 jlCi/gm.

Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of ~ 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

Vogtle Units 1 and 2 3.4.16-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 FREQUENCY SR 3.4.16.3 -----------------------------NOTE---------------------------

Not required to be performed until 31 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 2': 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine E from a sample taken in MODE 1 184 days after a minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for 2': 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Vogtle Units 1 and 2 3.4.16-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RCS Specific Activity 3.4.16 250 E

~

U

~

I

~ 200 f----+-----1~.____+_----'--UNACCEPTABLE -+--___1

~ OPERATION

~

I

~

U u:::

U

~

en 150 I

~

o-'

o u

1l:

~ 100 a..

I Z

UJ , ACCEP ABLE

~

> 50 OPE :nON r-----+------'----j---~---'---_+--+_-___1 a

UJ UJ en oo 0'------"-------'-------'-------'-------'

20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER FIGURE 3.4.16-1 REACTOR COOLANT DOSE EQUIVALENT 1-131 REACTOR COOLANT SPECIFIC ACTIVITY LIMIT VERSUS PERCENT OF RATED THERMAL POWER WITH THE REACTOR COOLANT SPECIFIC ACITVITY >1 mCi/gram DOSE EQUIVALENT 1-131 Vogtle Units 1 and 2 3.4.16-4 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

All SG tubes satisfying the tube repair criteria shall be plugged in accordance with the Steam Generator Program.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

NOTE--------------------------------------------------------------

Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the 7 days satisfying the tube repair affected tube(s) is maintained criteria and not plugged until the next refueling outage in accordance with the or SG tube inspection.

Steam Generator Program. AND A.2 Plug the affected tube(s) in Prior to entering accordance with the Steam MODE 4 following the Generator Program. next refueling outage or SG tube inspection B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

Vogtle Units 1 and 2 3.4.17-1 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

SG Tube Integrity 3.4.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the In accordance with Steam Generator Program. the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies Prior to entering the tube repair criteria is plugged in accordance MODE 4 following a with the Steam Generator Program. SG tube inspection Vogtle Units 1 and 2 3.4.17-2 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with pressurizer pressure> 1000 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to boron concentration to within concentration not within limits.

limits.

B. One accumulator B.1 Restore accumulator to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable for reasons OPERABLE status.

other than Condition A.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B AND not met.

C.2 Reduce pressurizer 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months pressure to:<:: 1000 psig.

D. Two or more 0.1 Enter LCO 3.0.3. Immediately accumulators inoperable.

Vogtle Units 1 and 2 3.5.1-1 Amendment No. 129 (Unit 1)

Amendment No. 107 (Unit 2)

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months open.

SR 3.5.1.2 Verify borated water volume in each accumulator 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months is ~ 6555 gallons and s 6909 gallons.

SR 3.5.1.3 Verify nitrogen cover pressure in each 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months accumulator is ~ 617 psig and s 678 psig.

SR 3.5.1.4 Verify boron concentration in each accumulator is 31 days

~ 1900 ppm and s 2600 ppm.

For each affected accumulator, once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of ~ 67 gallons, that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator 31 days isolation valve operator when pressurizer pressure is > 1000 psig.

Vogtle Units 1 and 2 3.5.1-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ECCS - Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS - Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

NOTE---------------------------------------------

In MODE 3, either residual heat removal pump to cold legs injection flow path may be isolated by closing the isolation valve to perform pressure isolation valve testing per SR 3.4.14.1.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more trains A.1 Restore train(s) to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.5.2-1 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months position with the power lockout switches in the lockout position.

Valve Number Valve Function Valve Position HV-8835 SI Pump Cold Leg Inj. OPEN HV-8840 RHR Pump Hot Leg Inj. CLOSED HV-8813 SI Pump Mini Flow Isol. OPEN HV-8806 SI Pump Suction from RWST OPEN HV-8802A, B SI Pump Hot Leg Inj. CLOSED HV-8809A, B RHR Pump Cold Leg Inj. OPEN SR 3.5.2.2 Verify each ECCS manual, power operated, and 31 days automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS piping is full of water. 31 days SR 3.5.2.4 Verify each ECCS pump's developed head at the In accordance with test flow point is greater than or equal to the the Inservice Testing required developed head. Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow 18 months path that is not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

(continued)

Vogtle Units 1 and 2 3.5.2-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

ECCS - Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each ECCS pump starts automatically on 18 months an actual or simulated actuation signal.

SR 3.5.2.7 Verify, by visual inspection, each ECCS train 18 months containment sump suction inlet is not restricted by debris and the suction inlet trash racks and screens show no evidence of structural distress or abnormal corrosion.

Vogtle Units 1 and 2 3.5.2-3 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

ECCS - Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS - Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.

APPLICABILITY: MODE 4.

ACTIONS

NOTE------------------------------------------------------

LCO 3.0Ab is not applicable to ECCS centrifugal charging pump subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore Immediately heat removal (RHR) required ECCS RHR subsystem inoperable. sUbsystem to OPERABLE status.

B. Required ECCS B.1 Restore required ECCS 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months centrifugal charging centrifugal charging subsystem inoperable. subsystem to OPERABLE status.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

C. Required ECCS C.1 Restore required ECCS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months centrifugal charging centrifugal charging subsystem inoperable. subsystem to OPERABLE status.

D. Required Actions and D.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months associated Completion Times of Conditions B or C not met.

Vogtle Units 1 and 2 3.5.3-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

ECCS - Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 ---------------------------NOTE------------------------------

An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

The following SRs are applicable for all In accordance with equipment required to be OPERABLE: applicable SRs SR 3.5.2.3 SR 3.5.2.7 SR 3.5.2.4 Vogtle Units 1 and 2 3.5.3-2 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)

LCO 3.5.4 The RWST shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron A.1 Restore RWST to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months concentration not within OPERABLE status.

limits.

OR RWST borated water temperature not within limits.

B. One or more sludge B.1 Restore the valve(s) to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months mixing pump isolation OPERABLE status.

valves inoperable.

C. Required Action and C.1 Isolate the sludge mixing 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion system.

Time of Condition B not met.

D. RWST inoperable for D.1 Restore RW ST to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months reasons other than OPERABLE status.

Condition A or B.

(continued)

Vogtle Units 1 and 2 3.5.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RWST 3.5.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or D AND not met.

E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 --------------------------NOTE------------------------------

Only required to be performed when ambient air temperature is < 40°F.

Verify RWST borated water temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

~ 44°F and ~ 116°F.

SR 3.5.4.2 Verify RWST borated water volume is ~ 686,000 7 days gallons.

SR 3.5.4.3 Verify RWST boron concentration is ~ 2400 ppm 7 days and ~ 2600 ppm.

SR 3.5.4.4 Verify each sludge mixing pump isolation valve 18 months automatically closes on an actual or simulated RWST Low-Level signal.

Vogtle Units 1 and 2 3.5.4-2 Amendment No. 151 (Unit 1)

Amendment No. 132 (Unit 2)

Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump seal injection flow shall be within limits.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Seal injection flow not A.1 Adjust manual seal 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months within limit. injection throttle valves in accordance with SR 3.5.5.1.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.5.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Seal Injection Flow 3.5.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 ------------------------------N()TE--------------------------

Not required to be performed until 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months after the Reactor Coolant System pressure stabilizes at ~ 2215 psig and ~ 2255 psig.

Verify manual seal injection throttle valves are 31 days adjusted to give a flow within the ECCS safety analysis limits.

Vogtle Units 1 and 2 3.5.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ECCS Recirculation Fluid pH Control System 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.6 Recirculation Fluid pH Control System LCO 3.5.6 The Recirculation Fluid pH Control System shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Recirculation Fluid pH A.1 Restore system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Control System OPERABLE status.

inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months Vogtle Units 1 and 2 3.5.6-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ECCS Recirculation Fluid pH Control System 3.5.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Perform a visual inspection of the Recirculation 18 months Fluid pH Control System and verify the following:

a) Three storage baskets are in place, and b) have maintained their integrity, and c) the baskets contain a total of

~ 11,484 pounds (220 cubic feet) and

~ 14,612 pounds (260 cubic feet) of trisodium phosphate crystals.

Vogtle Units 1 and 2 3.5.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment 3.6.1 3.6 CONTAINMENT SYSTEIVIS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.6.1-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Containment 3.6.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1 Perform required visual examinations and In accordance with leakage rate testing except for containment air the Containment lock testing, in accordance with the Containment Leakage Rate Testing Leakage Rate Testing Program. Program SR 3.6.1.2 Verify containment structural integrity In accordance with in accordance with the Containment Tendon the Containment Surveillance Program. Tendon Surveillance Program Vogtle Units 1 and 2 3.6.1-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEMS 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

NOTES---------------------------------------------------------

1. Entry and exit are permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when air lock leakage results in exceeding the overall containment leakage rate.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more -----------------NOTES-------------------

containment air locks 1. Required Actions A.1 , A.2, and with one containment air A.3 are not applicable if both lock door inoperable. doors in the same air lock are inoperable and Condition C is entered.

2. Entry and exit are permissible for 7 days under administrative controls if both air locks are inoperable.

(continued)

Vogtle Units 1 and 2 3.6.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Locks 3.6.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.1 Verify the OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

AND A.2 Lock the OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months door closed in the affected air lock.

AND A.3 ------------NOTE-------------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify the OPERABLE Once per 31 days door is locked closed in the affected air lock.

(continued)

Vogtle Units 1 and 2 3.6.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more -------------------N 0 T ES-----------------

containment air locks 1. Required Actions B.1, B.2, and with containment air lock B.3 are not applicable if both interlock mechanism doors in the same air lock are inoperable. inoperable and Condition C is entered.

2. Entry and exit of containment are permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months door is closed in the affected air lock.

B.2 Lock an OPERABLE door 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months closed in the affected air lock.

AND B.3 -------------N0 TE------------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify an OPERABLE Once per 31 days door is locked closed in the affected air lock.

(continued)

Vogtle Units 1 and 2 3.6.2-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more C.1 Initiate action to evaluate Immediately containment air locks overall containment inoperable for reasons leakage rate per LCO other than Condition A 3.6.1.

or B.

AND C.2 Verify a door is closed in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the affected air lock.

AND C.3 Restore air lock to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.6.2-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 ----------------------------NOTE S---------------------------

1. An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2. Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rage the Containment Testing Program. Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened 18 months at a time.

Vogtle Units 1 and 2 3.6.2-5 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

NOTES----------------------------------------------------------

1. Penetration flow path(s) (except for 24 inch purge valves) may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.

4. Enter applicable Conditions and Required Actions ot" LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more penetration A.1 Isolate the affected 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months flow paths with one penetration flow path by containment isolation use of at least one closed valve inoperable except and de-activated for purge valve leakage automatic valve, closed not within limit. manual valve, blind flange, or check valve with flow through the valve secured.

(continued)

Vogtle Units 1 and 2 3.6.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 -----------NOTE--------------

Isolation devices in high radiation areas may be verified by use of administrative means.

Verify the affected Once per 31 days for penetration flow path is isolation devices isolated. outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment B. One or more penetration B.1 Isolate the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months flow paths with two penetration flow path by containment isolation use of at least one closed valves inoperable except and de-activated for purge valve leakage automatic valve, closed not within limit. manual valve, or blind flange.

(continued)

Vogtle Units 1 and 2 3.6.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more penetration C.1 Isolate the affected 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months flow paths with one or penetration flow path by more containment purge use of at least one closed valves not within purge and de-activated valve leakage limits. automatic valve, closed manual valve, or blind flange.

AND C.2 -------------NOTE------------

Isolation devices in high radiation areas may be verified by use of administrative means.

Verify the affected Once per 31 days for penetration flow path is isolation devices isolated. outside containment Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment (continued)

Vogtle Units 1 and 2 3.6.3-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 24 inch purge valve is sealed closed, 31 days except for one purge valve in a penetration flow path while in Condition C of this LCO.

SR 3.6.3.2 Verify each 14 inch purge valve is closed, except 31 days when the associated penetration(s) is (are) permitted to be open for purge or venting operations and purge system surveillance and maintenance testing under administrative control.

SR 3.6.3.3 ------------------------------NOTE---------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative controls.

Verify each containment isolation manual valve 31 days and blind flange that is located outside containment and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

(continued)

Vogtle Units 1 and 2 3.6.3-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4 ----------------------------N()-rES---------------------------

1. Valves and blind flanges in high radiation areas may be verified by use of administrative means.

2. The fuel transfer tUbe blind flange is only required to be verified closed once after refueling prior to entering M()DE 4 from M()DE 5.

Verify each containment isolation manual valve Prior to entering and blind flange that is located inside containment M()DE 4 from and required to be closed during accident M()DE 5 if not conditions is closed, except for containment performed within the isolation valves that are open under previous 92 days administrative controls.

SR 3.6.3.5 Verify the isolation time of each power operated In accordance and each automatic containment isolation valve is with the Inservice within limits. Testing Program SR 3.6.3.6 Perform leakage rate testing for containment 18 months purge valves with resilient seals.

SR 3.6.3.7 Verify each automatic containment isolation valve 18 months that is not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

Vogtle Units 1 and 2 3.6.3-5 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be ~ -0.3 psig and ~ +1.8 psig.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure A.1 Restore containment 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not within limits. pressure to within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.6.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be ~ 120°F.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within average air temperature limit. to within limit.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months within limit.

Vogtle Units 1 and 2 3.6.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Spray and Cooling Systems 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray and Cooling Systems LCO 3.6.6 Two containment spray trains and two containment cooling trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A.1 Restore containment 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*

train inoperable. spray train to OPERABLE status. AND 6 days from discovery of failure to meet the LCO*

B. One containment B.1 Restore containment 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months cooling train inoperable. cooling train to OPERABLE status. AND 6 days from discovery of failure to meet the LCO C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months

For the VEGP Unit 2 June 23, 2008 entry into Technical Specification 3.6.6, the Containment Spray Pump B may be inoperable for a period not to exceed 7 days.

Vogtle Units 1 and 2 3.6.6-1 Amendment No. 96 (Unit 1)

Amendment No. 131 (Unit 2)

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power 31 days operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.6.2 Operate each containment cooling train fan unit 31 days for ~ 15 minutes.

SR 3.6.6.3 Verify each pair of containment fan coolers 31 days cooling water flow rate is ~ 1359 gpm.

SR 3.6.6.4 Verify each containment spray pump's developed In accordance with head at the flow test point is greater than or equal the Inservice Testing to the required developed head. Program SR 3.6.6.5 Verify each automatic containment spray valve in 18 months the flow path that is not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.6 Verify each containment spray pump starts 18 months automatically on an actual or simulated actuation signal.

(continued)

Vogtle Units 1 and 2 3.6.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Spray and Cooling Systems 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.7 Verify each containment cooling train starts 18 months automatically on an actual or simulated actuation signal.

SR 3.6.6.8 Verify each spray nozzle is unobstructed. 10 years Vogtle Units 1 and 2 3.6.6-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Hydrogen Recombiners 3.6.7 DELETED Vogtle Units 1 and 2 3.6.7-1 Amendment No. 134 (Unit 1)

Amendment No. 113 (Unit 2)

MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

LCO 3.7.1 The MSSVs shall be OPERABLE as specified in Table 3.7.1-1 and Table 3.7.1-2.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE---------------------------------------------------------

Separate Condition entry is allowed for each MSSV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MSSVs A.1 Reduce power to less 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable. than or equal to the applicable % RTP listed in Table 3.7.1-1.

A.2 Reduce the Power Range 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Neutron Flux-High trip setpoint to less than or equal to the applicable

% RTP listed in Table 3.7.1-1.

(continued)

Vogtle Units 1 and 2 3.7.1-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MSSVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months One or more steam generators (SG) with four or more MSSVs per SG inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.1.1 ----------------------------NOTE-----------------------------

Only required to be performed in MODES 1 and 2.

Verify each required MSSV lift setpoint per In accordance with Table 3.7.1-2 in accordance with the Inservice the Inservice Testing Testing Program. Following testing, lift settings Program shall be within +/- 1%.

Vogtle Units 1 and 2 3.7.1-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

Maximum Allowable Power Range Neutron Flux High Trip Setpoint with Inoperable Main Steam Safety Valves MAXIMUM ALLOWABLE POWER RANGE NEUTRON FLUX HIGH NUMBER OF INOPERABLE TRIP SETPOINT MSSVs PER STEAM GENERATOR (% RTP) 1 71 2 51 3 31 Vogtle Units 1 and 2 3.7.1-3 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING (psig + 2%, -3%)

STEAM GENERATOR

1 #2 #3 #4

1. PSV3001 PSV3011 PSV3021 PSV3031 1185 psig

2. PSV3002 PSV3012 PSV3022 PSV3032 1200 psig

3. PSV3003 PSV3013 PSV3023 PSV3033 1210 psig

4. PSV3004 PSV3014 PSV3024 PSV3034 1220 psig

5. PSV3005 PSV3015 PSV3025 PSV3035 1235 psig Vogtle Units 1 and 2 3.7.1-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MSIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2 Two MSIV systems per steam line shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 except when one MSIV system in each steam line is closed.

ACTIONS

NOTE----------------------------------------------------------

Separate Condition entry is allowed for each steam line.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam line A.1 Restore MSIV to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months with one MSIV system OPERABLE status.

inoperable in MODE 1.

B. One or more steam lines B.1 Restore one MSIV 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months with two MSIV systems system to OPERABLE inoperable in MODE 1. status in affected steam line.

C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A or B not met.

(continued)

Vogtle Units 1 and 2 3.7.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MSIVs 3.7.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more steam lines D.1 Verify one MSIV system 7 days with one MSIV system closed in affected steam inoperable in MODE 2 or AND

3. line.

Once per 7 days thereafter.

E. One or more steam lines E.1 Verify one MSIV system 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months with two MSIV systems closed in affected steam inoperable in MODE 2 or line. AND 3.

Once per 7 days thereafter F. Required Action and F.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition D or AND E not met.

F.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 ----------------------------NOTE----------------------------

Only required to be performed in MODES 1 and 2.

Verify closure time of each MSIV system is In accordance with the

~ 5 seconds on an actual or simulated actuation Inservice Testing signal. Program Vogtle Units 1 and 2 3.7.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Main Feedwater Isolation Valves (MFIVs) and Main Feedwater Regulation Valves (MFRVs) and Associated Bypass Valves LCO 3.7.3 Four MFIVs, four MFRVs, and associated bypass valves shall be OPERABLE.

APPLICABILITY: MODES 1 and 2 except when MFIV, MFRV, or associated bypass valve is closed and de-activated or isolated by a closed manual valve.

ACTIONS

NOTE-----------------------------------------------------------

Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more MFIVs A.1 Close or isolate MFIV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND A.2 Verify MFIV is closed or Once per 7 days isolated.

B. One or more MFRVs B.1 Close or isolate MFRV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND B.2 Verify MFRV is closed or Once per 7 days isolated.

(continued)

Vogtle Units 1 and 2 3.7.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

MFIVs and MFRVs and Associated Bypass Valves 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more MFRV or C.1 Close or isolate bypass 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months MFIV bypass valves valve.

inoperable.

AND C.2 Verify bypass valve is Once per 7 days closed or isolated.

D. Both isolation systems D.1 Isolate affected feedwater 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable in one or line.

more feedwater lines.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 -----------------------------~()TE:-----------------------------

Only required to be performed in MODE 1.

Verify the closure time of each MFIV, MFRV. and In accordance with associated bypass valve is :s; 5 seconds on an the Inservice Testing actual or simulated actuation signal. Program Vogtle Units 1 and 2 3.7.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

ARVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Relief Valves (ARVs)

LCO 3.7.4 Three ARV lines shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ARV line A.1 Restore required ARV line 30 days inoperable. to OPERABLE status.

B. Two or more required B.1 Restore at least two ARV 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ARV lines inoperable. lines to OPERABLE status.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 4 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months Vogtle Units 1 and 2 3.7.4-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

ARVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ARV. 18 months Vogtle Units 1 and 2 3.7.4-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3.

ACTIONS

NOTE-------------------------------------------------------

LCO 3.0Ab is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One steam supply to A.1 Restore steam supply to 7 days turbine driven AFW OPERABLE status.

pump inoperable. AND 10 days from discovery of failure to meet the LCO B. One AFW train B.1 Restore AFW train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable for reasons OPERABLE status.

other than Condition A. AND 10 days from discovery of failure to meet the LCO (continued)

Vogtle Units 1 and 2 3.7.5-1 Amendment No. 142 (Unit 1)

Amendment No. 122 (Unit 2)

AFW System 3.7.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A AND or B not met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR Two AFW trains inoperable.

D. Three AFW trains D.1 -------------NOTE------------

inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate action to restore Immediately one AFW train to OPERABLE status.

Vogtle Units 1 and 2 3.7.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual, power operated, and 31 days automatic valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.5.2 ------------------------------NOTE---------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 900 psig in the steam generator.

Verify the developed head of each AFW pump at 31 days on a the flow test point is greater than or equal to the STAGGERED TEST required developed head. BASIS SR 3.7.5.3 Verify each AFW automatic valve that is not 18 months locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.5.4 ----------------------------NOTE-----------------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after ~ 900 psig in the steam generator.

Verify each AFW pump starts automatically on an 18 months actual or simulated actuation signal.

(continued)

Vogtle Units 1 and 2 3.7.5-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5.5 Verify that each AFW pumphouse ESF supply fan 18 months starts and associated dampers actuate on a simulated or actual actuation signal.

SR 3.7.5.6 Verify that the ESF outside air intake and exhaust 18 months dampers for the turbine-driven AFW pump actuate on a simulated or actual actuation signal.

Vogtle Units 1 and 2 3.7.5-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CST 3.7.6 THIS PAGE APPLICABLE TO UNIT 1 ONLY 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 One CST shall be OPERABLE with a safety-related volume

>

340,000 gallons.

APPLICABILITY: MODES 1, 2, and 3, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST volume not within A.1 Align Auxiliary Feedwater 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limit. pumps to OPERABLE CST.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST volume is within limit. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.7.6-1 Amendment No. 105 (Unit 1)

CST 3.7.6 THIS PAGE APPLICABLE TO UNIT 2 ONLY 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 Two CSTs shall be OPERABLE with:

a. A combined safety-related volume of ~ 378,000 gallons; and

b. The CST aligned to supply the auxiliary feedwater pumps shall have a safety-related volume ~ 340,000 gallons.

APPLICABILITY: MODES 1, 2, and 3, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST volume(s) not A.1 Restore volume(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months within limit(s). within Iimit(s).

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify CST volumes within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Vogtle Units 1 and 2 3.7.6-1 Amendment No. 120 (Unit 2)

CCW System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Component Cooling Water (CCW) System LCO 3.7.7 Two CCW trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, One CCW train A,1 -------------NOTE------------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4,"

for residual heat removal loops made inoperable by CCW.

Restore CCW train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. Required Action and B.1 .Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.7.7-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

CCW System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 ------------------------------N()TE---------------------------

Isolation of CCW flow to individual components does not render the CCW System inoperable.

Verify each CCW manual, power operated, and 31 days automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.7.2 Verify each CCW pump starts automatically on an 18 months actual or simulated actuation signal.

Vogtle Units 1 and 2 3.7.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

NSCW 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Nuclear Service Cooling Water (NSCW) System LCO 3.7.8 Two NSCW trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A, One NSCW train --------------------NOTES------------------

inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources - Operating," for I

emergency diesel generator made inoperable by NSCW system.

2. Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops - MODE 4," for residual heat removal loops made inoperable by NSCW system.

A,1 Restore NSCW system to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not AI\ID met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.7.8-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

NSCW 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ----------------------------N()TE-----------------------------

Isolation of NSCW system flow to individual components does not render the NSCW system inoperable.

Verify each NSCW system manual, power 31 days operated, and automatic valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.8.2 Verify each NSCW system automatic valve in the 18 months flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.8.3 Verify each NSCW system pump starts 18 months automatically on an actual or simulated actuation signal.

Vogtle Units 1 and 2 3.7.8-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS shall be OPERABLE. With ambient wet-bulb temperature

> 63°F, four fans and four spray cells per train shall be OPERABLE. With ambient wet-bulb temperature :S 63°F, three fans and four spray cells per train shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Nuclear A.1 Restore water 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Service Cooling Water temperature(s) and water (NSCW) basins with level(s) to within limits.

water temperature and/or water level not within limits.

B. One NSCW cooling B.1 Restore fan(s) and spray 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months tower with one or more cell(s) to OPERABLE required fans and/or status.

spray cells inoperable.

(continued)

Vogtle Units 1 and 2 3.7.9-1 Amendment No. 140 (Unit 1)

Amendment No. 119 (Unit 2)

UHS 3.7.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One NSCW basin C.1 Restore the transfer 8 days transfer pump pump to OPERABLE inoperable. status.

OR C.2.1 Implement an alternate 8 days method of basin transfer.

AND C.2.2 Restore the transfer 31 days pump to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months UHS inoperable for reasons other than Conditions A, B, or C.

Vogtle Units 1 and 2 3.7.9-2 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

UHS 3.7.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify water level of NSCW basin is ~ 80.25 ft. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.7.9.2 Verify water temperature of NSCW basin is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

90°F.

SR 3.7.9.3 Operate each required NSCW cooling tower fan 31 days for ~ 15 minutes.

SR 3.7.9.4 Verify NSCW basin transfer pump operation. In accordance with the Inservice Testing Program SR 3.7.9.5 Verify ambient wet-bulb temperature::::: 63°F 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months when one NSCW tower fan is out-of-service and daily high temperature (dry-bulb) is forecasted to be> 48°F.

Vogtle Units 1 and 2 3.7.9-3 Amendment No. 140 (Unit 1)

Amendment No. 119 (Unit 2)

CREFS - Both Units Operating 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Emergency Filtration System (CREFS) - Both Units Operating LCO 3.7.10 Four CREFS trains shall be OPERABLE.

I'J 0 TE---------------------------------------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: Both Units in MODES 1, 2, 3, or 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREFS train A. 1 Place one CREFS train in 7 days inoperable for reasons the unaffected unit in the other than Condition D. emergency mode.

B. One CREFS train B.1 Place two OPERABLE 7 days inoperable in each unit CREFS trains in the for reasons other than emergency mode.

Condition D.

C. Two CREFS trains C.1 Place two CREFS trains Immediately inoperable in one unit for in the unaffected unit in reasons other than the emergency mode.

Condition D.

(continued)

Vogtle Units 1 and 2 3.7.10-1 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - Both Units Operating 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more CREFS D.1 Initiate action to Immediately trains inoperable due to implement mitigating inoperable CRE actions.

boundary.

AND D.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND D.3 Restore CRE boundary to 90 days OPERABLE status.

E. Control room air E.1 Restore control room air 7 days temperature not within temperature to within limit. limit.

(continued)

Vogtle Units 1 and 2 3.7.10-2 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - Both Units Operating 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 -------------NOTE------------

associated Completion Required Action F.1 is not Time not met. applicable when entering this Condition from Condition B, D, or E.

Lock closed the outside 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months air (OSA) intake dampers of the affected unit and lock open the OSA intake dampers of the unaffected unit.

F.2 Place the affected units(s) 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months in MODE 3.

F.3 Place the affected unit(s) 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months in MODE 5.

Vogtle Units 1 and 2 3.7.10-3 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - Both Units Operating 3.7.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify control room air temperature ~ 85°F. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.7.10.2 Operate each CREFS train for ~ 10 continuous 31 days hours with the heater control circuit energized.

SR 3.7.10.3 Perform required CREFS filter testing in In accordance with accordance with the Ventilation Filter Testing the VFTP Program (VFTP).

SR 3.7.10.4 Verify each CREFS train actuates (switches to 18 months emergency mode) on an actual or simulated actuation signal.

SR 3.7.10.5 Perform required CRE unfiltered air inleakage In accordance with testing in accordance with the Control Room the Control Room Envelope Habitability Program. Envelope Habitability Program Vogtle Units 1 and 2 3.7.10-4 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - One Unit Operating 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room Emergency Filtration System (CREFS) - One Unit Operating LCO 3.7.11 Four CREFS trains shall be OPERABLE.

NOTE---------------------------------------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: Only one Unit in MODES 1, 2, 3, or 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREFS train A.1 Place one CREFS train in 7 days inoperable in operating the shutdown unit in the unit for reasons other emergency mode.

than Condition F.

B. One CREFS train B.1 Lock closed the outside 7 days inoperable in shutdown air (OSA) intake dampers unit for reasons other of the shutdown unit and than Condition F. lock open the OSA intake dampers of the operating unit.

OR B.2 Place one CREFS train in 7 days the operating unit in the emergency mode.

(continued)

Vogtle Units 1 and 2 3.7.11-1 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - One Unit Operating 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One CREFS train C.1 Lock closed the shutdown 7 days inoperable in each unit unit's OSA intake for reasons other than dampers and lock open Condition F. the operating unit's OSA intake dampers.

AND C.2 Place the OPERABLE 7 days CREFS train in the shutdown unit in the emergency mode.

D. Two CREFS trains D.1 Place both CREFS trains Immediately inoperable in operating in the shutdown unit in the unit for reasons other emergency mode.

than Condition F.

E. Two CREFS trains E.1 Lock closed the OSA Immediately inoperable in shutdown intake dampers of the unit for reasons other shutdown unit and lock than Condition F. open the OSA intake dampers of the operating unit.

OR E.2 Place both CREFS trains Immediately in the operating unit in the emergency mode.

(continued)

Vogtle Units 1 and 2 3.7.11-2 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - One Unit Operating 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One or more CREFS F.1 Initiate action to Immediately trains inoperable due to implement mitigating inoperable CRE actions.

boundary.

AND F.2 Verify mitigating actions 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ensure CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND F.3 Restore CRE boundary to 90 days OPERABLE status.

G. Control room air G.1 Restore control room air 7 days temperature not within temperature to within limit. limit.

H. Required Action and H.1 Place the unit in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met for AND operating unit.

H.2 Place the unit in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 The Surveillance Requirements of Specification In accordance with 3.7.10 are applicable. applicable SRs.

Vogtle Units 1 and 2 3.7.11-3 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - Both Units Shutdown 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Control Room Emergency Filtration System (CREFS) - Both Units Shutdown LCO 3.7.12 Four CREFS trains shall be OPERABLE.

NOTE---------------------------------------------------------

The control room envelope (CRE) boundary may be opened intermittently under administrative control.

APPLICABILITY: Both units with average Reactor Coolant Temperature:::; 200°F during movement of irradiated fuel or CORE ALTERATIONS in either unit.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREFS train A.1 Lock closed the outside 7 days inoperable. air (OSA) intake dampers of the affected unit and lock open the OSA intake dampers of the unaffected unit.

OR A.2 Place one CREFS train in 7 days the unaffected unit in the emergency mode.

B. One CREFS train B.1 Place one CREFS train in 7 days inoperable in each unit. the emergency mode.

(continued)

Vogtle Units 1 and 2 3.7.12-1 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

CREFS - Both Units Shutdown 3.7.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Two CREFS trains C.1 Lock closed the OSA Immediately inoperable in one unit. intake dampers of the affected unit and lock open the OSA intake dampers of the unaffected unit.

OR C.2 Place one CREFS train in Immediately the unaffected unit in the emergency mode.

D. Three CREFS trains 0.1 Place the remaining Immediately inoperable. CREFS train in the emergency mode.

OR 0.2.1. Lock closed the OSA Immediately intake dampers of the unit with two inoperable systems and lock open the OSA intake dampers of the unit with one inoperable system.

AND 0.2.2 Place the remaining 7 days CREFS train in the emergency mode.

(continued)

Vogtle Units 1 and 2 3.7.12-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

CREFS - Both Units Shutdown 3.7.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Four CREFS trains E.1 Suspend movement of Immediately inoperable. irradiated fuel assemblies.

OR The CREFS train AND required in the emergency mode by E.2 Suspend CORE Immediately Required Actions of ALTERATIONS.

Conditions A, B, C, or D not capable of being powered by an OPERABLE emergency power source.

OR One or more CREFS trains inoperable due to an inoperable CRE boundary.

F. Control room air F.1 Restore control room air 7 days temperature not within temperature to within limit. limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 The Surveillance Requirements of In accordance with Specification 3.7.10 are applicable. applicable SRs.

Vogtle Units 1 and 2 3.7.12-3 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

PPAFES 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Piping Penetration Area Filtration and Exhaust System (PPAFES)

LCO 3.7.13 Two PPAFES trains shall be OPERABLE.

NOTE---------------------------------------------------------

The PPAFES boundary may be opened intermittently under administrative control.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One PPAFES train A.1 Restore PPAFES train to 7 days inoperable. OPERABLE status.

B. Two PPAFES trains B.1 Restore PPAFES 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable due to boundary to OPERABLE inoperable PPAFES status.

boundary.

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.13.1 Operate each PPAFES train for ~ 15 minutes. 31 days (continued)

Vogtle Units 1 and 2 3.7.13-1 Amendment No. 121 (Unit 1)

Amendment No. 99 (Unit 2)

PPAFES 3.7.13 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.13.2 Perform required PPAFES filter testing in In accordance with the accordance with the Ventilation Filter Testing VFTP Program (VFTP).

SR 3.7.13.3 Verify each PPAFES train actuates on an actual 18 months or simulated actuation signal.

SR3.7.13.4 Verify one PPAFES train can maintain a negative 18 months on pressure ~ 0.250 inches water gauge relative to a STAGGERED atmospheric pressure during the post accident TEST BASIS mode of operation at a flow rate of 15,500 cfm +/- 10%.

Vogtle Units 1 and 2 3.7.13-2 Amendment No. 121 (Unit 1)

Amendment No. 99 (Unit 2)

ESF Room Cooler and Safety-Related Chiller System 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Engineered Safety Features (ESF) Room Cooler and Safety Related Chiller System LCO 3.7.14 Two ESF Room Cooler and Safety-Related Chiller trains shall be OPERABLE.

NOTE----------------------------------------------

One Safety-Related Chiller train may be removed from service for

~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months under administrative controls for surveillance testing of the other Safety-Related Chiller train.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One ESF room cooler A.1 Restore the ESF room 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months and safety-related chiller cooler and safety-related train inoperable. chiller train to OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.7.14-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

ESF Room Cooler and Safety-Related Chiller System 3.7.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.14.1 Verify each ESF room cooler and safety-related 31 days chiller system manual, power-operated and automatic valve servicing safety-related equipment that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.14.2 Verify each ESF room cooler and safety-related 18 months chiller system automatic valve servicing safety-related equipment that is not locked, sealed, or otherwise secured in position actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.14.3 Verify each ESF room cooler fan and safety- 18 months related chiller system (pump and chiller) start automatically on an actual or simulated actuation sjgnal.

Vogtle Units 1 and 2 3.7.14-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Fuel Storage Pool Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Pool Water Level LCO 3.7.15 The fuel storage pool water level shall be ~ 23 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY: During movement of irradiated fuel assemblies in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool water A.1 -------------NOTE-------------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of Immediately irradiated fuel assemblies in the fuel storage pool.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the fuel storage pool water level is ~ 23 ft 7 days above the top of the irradiated fuel assemblies seated in the storage racks.

Vogtle Units 1 and 2 3.7.15-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 The specific activity of the secondary coolant shall be $ 0.10 J.lCilgm DOSE EQUIVALENT 1-131.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months within limit.

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the specific activity of the secondary 31 days coolant is $ 0.10 J.lCi/gm DOSE EQUIVALENT 1-131.

Vogtle Units 1 and 2 3.7.16-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Fuel Storage Pool Boron Concentration 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Fuel Storage Pool Boron Concentration LCO 3.7.17 The fuel storage pool boron concentration shall be ~ 2000 ppm.

APPLICABILITY: When fuel assemblies are stored in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron ------------------NOTE----------------

concentration not within LCO 3.0.3 is not applicable.

limit.

A.1 Suspend movement of Immediately fuel assemblies in the fuel storage pool.

A.2.1 Initiate action to restore Immediately fuel storage pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify the fuel storqge pool boron concentration is 7 days within limit.

VogUe Units 1 and 2 3.7.17-1 Amendment No. 99 (Unit 1)

Amendment No. 77 (Unit 2)

Fuel Assembly Storage in the Fuel Storage Pool 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Fuel Assembly Storage in the Fuel Storage Pool LCO 3.7.18 The combination of initial enrichment burnup and configuration of fuel assemblies stored in the fuel storage pool shall be within the Acceptable Burnup Domain of Figures 3.7.18-1 (Unit 1), 3.7.18-2 (Unit 2), or in accordance with Specification 4.3.1.1 (Unit 1) or 4.3.1.2 (Unit 2).

APPLICABILITY: Whenever any fuel assembly is stored in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the LCO A.1 ----------NOTE-----------

not met. LCO 3.0.3 is not applicable.

Initiate action to move Immediately the noncomplying fuel assembly to an acceptable storage location.

Vogtle Units 1 and 2 3.7.18-1 Amendment NO.1 02 (Unit 1)

Amendment No. 80 (Unit 2)

Fuel Assembly Storage in the Fuel Storage Pool 3.7.18 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.18.1 Verify by a combination of visual inspection and Prior to storing administrative means that the initial enrichment, the fuel burnup, and storage location of the fuel assembly is assembly in the in accordance with Figures 3.7.18-1 (Unit 1), 3.7.18-2 fuel storage (Unit 2), or Specification 4.3.1.1 (Unit 1) or 4.3.1.2 pool location.

(Unit 2).

Vogtle Units 1 and 2 3.7.18-2 Amendment No. 102 (Unit 1)

Amendment No. 80 (Unit 2)

Fuel Assembly Storage in the Fuel Storage Pool 3.7.18

+-----!--~- l---- -- - - - - - - - ---

8, 000 ;_~_-t-+~_~-++~_--+--_--+------I------~- -------41-----+--------1--+-----+-c-_--4--_--+----1_......4_-I---I-----_~_- ~ff;."".j v

)

7,000 +--+-~_+__+___l~_!__+___l-_!_-+---r-_I__4_--r-f--I----- I--~ - --- f___ -~- ----- -~-I_-

......_4__4_J./_+-1__I

- - - ------+~+_--1-____I-+-I-I--__+-_l__-_l 1/

V

-1'---- ----1 6,000 -f--+-+-+--+--+~-+--+--+-+--+--+--1-+-..... r7~-!--+--!---1 1---+----+--HACCEPTA~LEll__-___j---f_----_+_____I-_I___----+----+-----_I__11 -I-i--t--------1--+-----+-----1--------1 1---- --~f___- --I- -- ----f___ --- -------1----1---

5,000 +-_+---4-_+__+___l~_!__+___I-_I_-+-___I-_I__4_-A , -......_4__4-4--1---1 1 - - - - ----1-- - - - - f _ _ _ - - - - -----1---- 1-- - -- -+-----[. ------ 1 -- -

4,000

--~- -- ------f-

+--+~f_+-_+___lf_+-_+____!-+_-+___!--¥-_+___+-+__+___+-+__+___1

-/

/

I;,../-+-~UNACC EPTABLE 1- ---

3,000 +----+-1----4-----+-+--I-.....,.-+--l-.....,.-...

/

2 ,000 _f_-+-+-+--+--+--I-+-_+_~-+_-+-_!___1-+-.....__1_-!__+__!___1 1---+---+---- -----1---11-- -- I---If-+---- I----~- -----+--I-~I----+----+----j--+~--

-- -+----+-------1---1 - /

1 1 ,000 +--+-I--+--+___lI-+--4J~-+_-+- __-+__+___I-_f__+___I-+__+___l f -- -- - - - ---

- - - -- -----I---!----I---- -~+___+_----+ -+----1 a _f_..............J._l...-.......-I-..L'...........1.........l.---l_+--l-....J..---J._.......+-..............J._l...-..........j 3.0 3.5 4.0 4.5 5.0 Initial Z35 U Enrichment (nominal w/o)

Figure 3.7.18-1 Vogtle Unit 1 Burnup Credit Requirements for All Cell Storage Vogtle Units 1 and 2 3.7.18-3 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Fuel Assembly Storage in the Fuel Storage Pool 3.7.18 45,000 40,000 J

35,000 I II II 30,000

J ACCEPTABLE II" I II"

IE 25,000 a V

/

~

1/

!. f ~

II Co c_ - -

...c:;, 20,000 co

c>

E ,...

cu en en 15,000 /

/

UNACCEPTABLE -

<C 1/

Qi I u.

10,000 1/

II I

5,000 I

II I o

1.0 1.5 2.0 2.5 3.0 3.5 4.0 4.5 5.0 235 Initial U Enrichment (nominal w/o)

Figure 3.7.18-2 Vogtle Unit 2 Burnup Credit Requirements for All Cell Storage Vogtle Units 1 and 2 3.7.18-4 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System; and

b. Two diesel generators (DGs) capable of supplying the onsite Class 1E power distribution subsystem(s).

Automatic load sequencers for Train A and Train B ESF buses shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS

NOTE-------------------------------------------------------

LCO 3.0Ab is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite A.1 Perform SR 3.8.1.1 for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months circuit inoperable. required OPERABLE offsite circuit. AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter (continued)

Vogtle Units 1 and 2 3.8.1-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2 Declare required feature(s) 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from with no offsite power discovery of no offsite available inoperable when power to one train its redundant required concurrent with feature(s) is inoperable. inoperability of redundant required feature(s)

AND A.3 Restore required offsite 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months circuit to OPERABLE status.

14 days from discovery of failure to meet LCO (continued)

Vogtle Units 1 and 2 3.8.1-2 Amendment NO.1 00 (Unit 1)

Amendment No. 78 Unit 2)

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months required offsite circuit(s).

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 Verify SAT available. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.3 Declare required feature(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from supported by the discovery of inoperable DG inoperable Condition B when its required concurrent with redundant feature(s) is inoperabi/ity of inoperable. redundant required feature(s)

AND B.4.1 Determine OPERABLE DG 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months is not inoperable due to common cause failure.

OR B.4.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE DG.

AND (continued)

Vogtle Units 1 and 2 3.8.1-3 Amendment NO.1 00 (Unit 1)

Amendment No. 78 Unit 2)

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) --------------------N0 TE------------------

Required Action B.5.1 is only applicable if the combined reliability of the enhanced black-start combustion turbine generators (CTG) and the black-start diesel generator is ~ 95%. Otherwise, Required Action B.5.2 applies.

B.5.1 Verify an enhanced black 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months start CTG is functional by verifying the CTG and the black-start diesel generator starts and Within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months achieves steady state prior to entry into voltage and frequency. Condition B B.5.2 Start and run at least one 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months CTG while in Condition B.

Prior to entry into Condition B for preplanned maintenance (continued)

Vogtle Units 1 and 2 3.8.1-4 Amendment NO.1 00 (Unit 1)

Amendment No. 78 Unit 2)

AC Sources - Operating 3.8.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.6 Restore DG to OPERABLE 14 days from status. discovery of failure to meet LCO C. Required Actions B.2, C.1 Restore DG to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B.5.1, or B.5.2 and status.

associated Completion Times not met.

D. Two required oftsite 0.1 Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from circuits inoperable. inoperable when its discovery of redundant feature(s) is Condition 0 inoperable. concurrent with inoperability of redundant required AND features 0.2 Restore one required 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months oftsite circuit to OPERABLE status E. One required oftsite --------------------NOTE------------------

circuit inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, AND "Distribution Systems - Operating,"

when Condition E is entered with no One DG inoperable. AC power source to one or more trains.

(continued)

Vogtle Units 1 and 2 3.8.1-5 Amendment NO.100 (Unit 1)

Amendment No. 78 Unit 2)

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. (continued) E.1 Restore required offsite 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months circuit to OPERABLE status.

OR E.2 Restore DG to OPERABLE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months status.

F. Two DGs inoperable. F.1 Restore one DG to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status.

G. One automatic load G.1 Restore automatic load 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months sequencer inoperable. sequencer to OPERABLE status.

H. Required Action and H.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A, C, AND 0, E, F, or G not met.

H.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Required Action B.1, B.3, B.4.1, B.4.2, or B.6 and associated Completion Time not met.

I. Three or more required 1.1 Enter LCO 3.0.3. Immediately AC sources inoperable.

Vogtle Units 1 and 2 3.8.1-6 Amendment NO.1 00 (Unit 1)

Amendment No. 78 Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated 7 days power availability for each required offsite circuit.

SR 3.8.1.2 ------------------------------NOTES-------------------------

1. Performance of SR 3.8.1.7 satisfies this SR.

2. All DG starts may be preceded by an engine prelube period and followed by a warmup period prior to loading.

3. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions 31 days and achieves steady state voltage;;:: 4025 V and

4330 V, and frequency;;: : 58.8 Hz and

61.2 Hz.

(continued)

Vogtle Units 1 and 2 3.8.1-7 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 -----------------------------NOTES--------------------------

1. DG loadings may include gradual loading as recommended by the manufacturer.

2. Momentary transients outside the load range do not invalidate this test.

3. This Surveillance shall be conducted on only one DG at a time.

4. This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded and 31 days operates for ~ 60 minutes at a load ~ 6500 kW and ~ 7000 kW.

SR 3.8.1.4 Verify each day tank contains ~ 650 gal of fuel oil. 31 days SR 3.8.1.5 Check for and remove accumulated water from 31 days each day tank.

SR 3.8.1.6 Verify the fuel oil transfer system operates to 31 days automatically transfer fuel oil from storage tanks to the day tank.

(continued)

Vogtle Units 1 and 2 3.8.1-8 Amendment NO.1 09 (Unit 1)

Amendment No. 87 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 ------------------------------NOTE---------------------------

All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition and 184 days achieves in ~ 11.4 seconds, voltage 2: 4025 V and

~ 4330 V, and frequency 2: 58.8 Hz and

~ 61.2 Hz.

SR 3.8.1.8 -----------------------------NOTE----------------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG rejects a load 2: its associated 18 months single largest post accident load, and:

a. Following load rejection, the frequency is

~ 64.5 Hz;

b. Within 3 seconds following load rejection, the voltage is 2: 3750 V and ~ 4330 V or

~ 4550 V when performing the test synchronized with offsite power; and

c. Within 3 seconds following load rejection, the frequency is 2: 58.8 Hz and ~ 61.2 Hz.

(contin ued)

Vogtle Units 1 and 2 3.8.1-9 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.9 ----------------------------NOTE----------------------------

Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operating as close as practicable 18 months to 3390 kVAR while maintaining voltage ~ 4330 V does not trip and voltage is maintained ~ 5000 V during and following a load rejection of ~ 6500 kW and ~ 7000 kW.

(continued)

Vogtle Units 1 and 2 3.8.1-10 Amendment No. 117 (Unit 1)

Amendment No. 95 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.10 ------------------------------NOTES-------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite 18 months power signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in s; 11.5 seconds,

2. energizes auto-connected shutdown loads through automatic load sequencer,

3. maintains steady state voltage

~ 3750 V and s; 4330 V,

4. maintains steady state frequency

~ 58.8 Hz and s; 61.2 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for

~ 5 minutes.

(continued)

Vogtle Units 1 and 2 3.8.1-11 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.11 ------------------------------NOTES-------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated Engineered 18 months Safety Feature (ESF) actuation signal each DG auto-starts from standby condition and:

a. In ~ 11.4 seconds after auto-start and during tests, achieves voltage ~ 3750 V and

~ 4330 V;

b. In ~ 11.4 seconds after auto-start and during tests, achieves frequency ~ 58.8 Hz and ~ 61.2 Hz;

c. Operates for ~ 5 minutes;

d. Permanently connected loads remain energized from the offsite power system; and

e. Emergency loads are energized or auto connected through the automatic load sequencer from the offsite power system.

(continued)

Vogtle Units 1 and 2 3.8.1-12 Amendment No. 96 (Unit 1)

Amendment 1\10. 74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 -------------------------------NOTE--------------------------

This Surveillance shall not be performed in MODE 1 or 2. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG's automatic trips are bypassed on 18 months actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except:

a. Engine overspeed;

b. Generator differential current; and

c. Low lube oil pressure; SR 3.8.1.13 -------------------------------NOTES------------------------

1. Momentary transients outside the kW and kVAR load ranges do not invalidate this test.

2. Credit may be taken for unplanned events that satisfy this SR.

Verify each DG operates for ~ 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while 24 months maintaining voltage :s; 4330 V:

a. For ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded ~ 6900 kWand

s; 7700 kW and operating as close as practicable to 3390 kVAR; and

b. For the remaining hours of the test loaded

~ 6500 kW and :s; 7000 kW and operating as close as practicable to 3390 kVAR.

(continued)

Vogtle Units 1 and 2 3.8.1-13 Amendment No. 126 (Unit 1)

Amendment NO.1 04 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 ------------------------------NOTES-------------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated ~ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded

~ 6500 kW and 0:::; 7000 kW.

Momentary transients outside of load range do not invalidate this test.

2. All DG starts may be preceded by an engine prelube period.

Verify each DG starts and achieves, in 18 months 0:::; 11.4 seconds, voltage ~ 4025 V, and 0:::; 4330 V and frequency ~ 58.8 Hz and 0:::; 61.2 Hz.

SR 3.8.1.15 -----------------------------N 0 T E----------------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify each DG: 18 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-Ioad operation.

(continued)

Vogtle Units 1 and 2 3.8.1-14 Amendment No. 117 (Unit 1)

Amendment No. 95 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 -----------------------------NOTE----------------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify, with a DG operating in test mode and 18 months connected to its bus, an actual or simulated ESF actuation signal overrides the test mode by:

a. Returning DG to ready-to-Ioad operation; and

b. Automatically energizing the emergency load from offsite power.

SR 3.8.1.17 -----------------------------NOTE----------------------------

This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify interval between each sequenced load 18 months block is within +/- 10% of design interval for each load sequencer.

(continued)

Vogtle Units 1 and 2 3.8.1-15 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.18 -----------------------------NOTES--------------------------

1. All DG starts may be preceded by an engine prelube period.

2. This Surveillance shall not be performed in MODE 1,2,3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify on an actual or simulated loss of offsite 18 months power signal in conjunction with an actual or simulated ESF actuation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in :s; 11.5 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage:

~ 3750 V and :s; 4330 V,

4. achieves steady state frequency:

~ 58.8 Hz and :s; 61.2 Hz, and

5. supplies permanently connected and auto-connected emergency loads for

~ 5 minutes.

SR 3.8.1.19 Verify fuel transfer pump transfers fuel from each 18 months fuel storage tank to the day tank of each diesel via the installed cross-connection lines.

(continued)

Vogtle Units 1 and 2 3.8.1-16 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Operating 3.8.1 SURVEILLANCE FREQUENCY SR 3.8.1.20 ------------------------------NOTE---------------------------

All DG starts may be preceded by an engine prelube period.

Verify when started simultaneously from standby 10 years condition, each DG achieves, in ~ 11.4 seconds, voltage ~ 4025 V and ~ 4330 V, and frequency

~ 58.8 Hz and ~ 61.2 Hz.

Vogtle Units 1 and 2 3.8.1-17 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources - Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown"; and

b. One diesel generator (DG) capable of supplying one train of the onsite Class 1E AC electrical power distribution subsystem(s) required by LCO 3.8.10.

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite ---------------------NOTE-------------------

circuit inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.10, with one required train de-energized as a result of Condition A.

A.1 Declare affected required Immediately feature(s) with no offsite power available inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

(contin ued)

Vogtle Units 1 and 2 3.8.2-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Initiate action to suspend Immediately operations involving positive reactivity additions.

AND A.2A Initiate action to restore Immediately required offsite power circuit to OPERABLE status.

B. One required DG B.1 Suspend CORE Immediately inoperable. ALTERATIONS.

AND B.2 Suspend movement of Immediately irradiated fuel assemblies.

AND B.3 Initiate action to suspend Immediately operations involving positive reactivity additions.

AND BA Initiate action to restore Immediately required DG to OPERABLE status.

Vogtle Units 1 and 2 3.8.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

AC Sources - Shutdown 3.8.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.2.1 -------------------------------N()TE---------------------------

The following SRs are applicable but not required to be performed:

SR 3.8.1.3 SR 3.8.1.8 SR 3.8.1.9 SR 3.8.1.1 a (except 3.8.1.1 a.c.2)

SR 3.8.1.13 SR 3.8.1.14 SR 3.8.1.15 SR 3.8.1.19 For AC sources required to be ()PERABLE, the In accordance with following SRs of Specification 3.8.1 are applicable: applicable SRs SR 3.8.1.1 SR 3.8.1.2 SR 3.8.1.3 (see Note)

SR 3.8.1.4 SR 3.8.1.5 SR 3.8.1.6 SR 3.8.1.7 SR 3.8.1.8 (see Note)

SR 3.8.1.9 (see Note)

SR 3.8.1.1 a (except 3.8.1.1 a.c2)

(see Note)

SR 3.8.1.13 (see Note)

SR 3.8.1.14 (see Note)

SR 3.8.1.15 (see Note)

SR 3.8.1.19 (see Note)

Vogtle Units 1 and 2 3.8.2-3 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Diesel Fuel Oil, Lube Oil, Starting Air, and Ventilation 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, Starting Air, and Ventilation LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits and ventilation supply fans OPERABLE for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

NOTE-----------------------------------------------------------

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with A.1 Restore fuel oil level to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months fuel level < 68,000 gal within limits.

and> 52,000 gal in storage tank.

B. One or more DGs with B.1 Restore lube oil inventory 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months lube oil inventory to within limits.

< 336 gal and> 288 gal.

C. One or more DGs with C.1 Restore fuel oil total 7 days stored fuel oil total particulates within limit.

particulates not within limit.

(continued)

Vogtle Units 1 and 2 3.8.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Diesel Fuel Oil, Lube Oil, Starting Air, and Ventilation 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One or more DGs with D.1 Restore stored fuel oil 30 days new fuel oil properties properties to within limits.

not within limits.

E. One or more DGs with E.1 Restore one starting air 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months both starting air receiver receiver pressure per DG pressures < 210 psig to ~ 210 psig.

and ~ 175 psig.

F. One or more DGs with F.1 Restore ventilation supply 14 days one ventilation supply fan to OPERABLE status.

fan inoperable per DG.

G. Required Action and G.1 Declare associated DG Immediately associated Completion inoperable.

Time not met.

OR One or more DGs diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C, D, or E.

OR One or more DGs with two ventilation supply fans inoperable per DG.

Vogtle Units 1 and 2 3.8.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Diesel Fuel Oil, Lube Oil, Starting Air, and Ventilation 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains 31 days

~ 68,000 gal of fuel.

SR 3.8.3.2 Verify lube oil inventory is ~ 336 gal. 31 days SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil In accordance with are tested in accordance with, and maintained the Diesel Fuel Oil within the limits of, the Diesel Fuel Oil Testing Testing Program Program.

SR 3.8.3.4 Verify each DG has one air start receiver with a 31 days pressure ~ 210 psig.

SR 3.8.3.5 Check for and remove accumulated water from 31 days each fuel oil storage tank.

SR 3.8.3.6 Verify each DG ventilation supply fan starts and 18 months the necessary dampers actuate on a simulated or actual actuation signal.

SR 3.8.3.7 ----------------------------NC>TE------------------------------

Not required to be performed when DG is required C>PERABLE in accordance with Specification 3.8.2.

For each fuel oil storage tank: 10 years

a. Drain the fuel oil;

b. Remove the sediment; and

c. Clean the tank.

Vogtle Units 1 and 2 3.8.3-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 Four class 1E 125 V DC electrical power sources shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One DC electrical power ----- ------------- NOTE----------------

source inoperable due to Enter applicable Conditions and inoperable battery A or B. Required Actions of LCO 3.8.1, "AC Sources - Operating," for emergency diesel generator made inoperable by inoperable battery A or B.

A.1 Restore DC electrical 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months power source to OPERABLE status.

B. One DC electrical power B.1 Verify SAT available 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months source inoperable due to inoperable battery C or D. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.2 Restore DC electrical 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months power source to OPERABLE status.

(continued)

Vogtle Units 1 and 2 3.8.4-1 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

DC Sources - Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One DC electrical power C.1 Restore DC electrical 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months source inoperable for power source to reasons other than OPERABLE status.

Condition A or B.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or 7 days equal to the minimum established float voltage.

SR 3.8.4.2 Verify the battery charger supplies: 18 months

~ 400 amps for System A and B

~ 300 amps for System C, and

~ 200 amps for System D at greater than or equal to the minimum established float voltage for ~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months for Systems A and B and ~ 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months for Systems C and D.

Verify each battery charger can recharge the battery to the fully charged state within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

(continued)

Vogtle Units 1 and 2 3.8.4-2 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.3 ----------------------------NOTES----------------------------

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of the service test in SR 3.8.4.3.

2. This Surveillance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SR.

Verify battery capacity is adequate to supply, and 18 months maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

Vogtle Units 1 and 2 3.8.4-3 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

DC Sources - Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources - Shutdown LCO 3.8.5 DC electrical power sources shall be OPERABLE to support the DC electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown."

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME Vogtle Units 1 and 2 3.8.5-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

DC Sources - Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 ------------------------------NOTE----------------------------

The following SRs are applicable but not required to be performed:

SR 3.8.4.2 SR 3.8.4.3 For the DC electrical power sources required to be In accordance with OPERABLE, the following SRs of Specification applicable SRs 3.8.4 are applicable:

SR 3.8.4.1 SR 3.8.4.2 (see Note)

SR 3.8.4.3 (see l\Iote)

Vogtle Units 1 and 2 3.8.5-2 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 Battery parameters for the required Class 1E 125 V batteries shall be within limits.

APPLICABILITY: When associated DC electrical power sources are required to be OPERABLE.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One battery with one or A.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months more battery cells float voltage < 2.07 V. AND A.2 Perform SR 3.8.6.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.3 Restore affected cell 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months voltage ~ 2.07 V.

B. Battery A or B with float B.1 Perform SR 3.8.4.1. 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months current> 2 amps.

AND OR B.2 Restore battery float 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Battery C or D with float current to within limit.

current> 1 amp.

(continued)

Vogtle Units 1 and 2 3.8.6-1 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

NOTE-------------- --------------------NOTE------- -------------

Required Action C.2 shall be Required Actions C.1 and C.2 are completed if electrolyte level only applicable if electrolyte level was below the top of plates. was below the top of plates.

C. One battery with one or C.1 Restore electrolyte level to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months more cells electrolyte above top of plates.

level less than minimum established design limits. AND C.2 Verify no evidence of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months leakage.

AND C.3 Restore electrolyte level to 31 days greater than or equal to minimum established design limits.

D. One battery with pilot cell D.1 Restore battery pilot cell 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months electrolyte temperature temperature to greater less than minimum than or equal to minimum established design limits. established design limits.

E. Two or more batteries E.1 Restore battery 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months with battery parameters parameters for at least not within limits. three batteries to within limits.

F. Required Action and F.1 Declare associated battery Immediately associated Completion inoperable.

Time of Condition A, B, C, D, or E not met.

OR (continued)

Vogtle Units 1 and 2 3.8.6-2 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

Battery Parameters 3.8.6 ACTIONS SURVEILLANCE FREQUENCY F. (continued)

One battery with one or more battery cells float voltage < 2.07 V and float current> 2 amps for systems A or B batteries, or > 1 amp for system Cor D.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6. 1 ---------------------------------N OTE----------------------------

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1.

Verify each system A and B battery float current is 7 days

~ 2 amps. Verify each system C and D battery float current is ~ 1 amp.

SR 3.8.6.2 Verify each battery pilot cell voltage is ~ 2.07 V. 31 days SR 3.8.6.3 Verify each battery connected cell electrolyte level is 31 days greater than or equal to minimum established design limits.

SR 3.8.6.4 Verify each battery pilot cell temperature is greater 31 days than or equal to minimum established design limits.

(continued)

Vogtle Units 1 and 2 3.8.6-3 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.5 Verify each battery connected cell voltage is ~ 2.07 V. 92 days SR 3.8.6.6 ----------- -------------------1\1aTE-------------------------------

This Survelliance shall not be performed in MODE 1, 2, 3, or 4. However, credit may be taken for unplanned events that satisfy this SA.

Verify battery capacity is ~ 80% of the manufacturer's 60 months rating when subjected to a performance discharge test or a modified performance discharge test. AND 12 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating 24 months when battery has reached 85% of the expected life with capacity

~ 100% of manufacturer's rating Vogtle Units 1 and 2 3.8.6-4 Amendment No. 133 (Unit 1)

Amendment No. 112 (Unit 2)

Inverters - Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters - Operating LCO 3.8.7 The required Class 1E 120 V inverters shall be OPERABLE.

~OTE----------------------------------------------

Two inverters may be disconnected from their associated DC bus for

~ 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to perform an equalizing charge on their associated common battery, provided:

a. The associated AC vital bus(es) are energized from their Class 1E regulating transformers; and

b. All other AC vital buses are energized from their associated OPERABLE inverters.

APPLICABILITY: IVIODES 1, 2, 3, and 4.

ACTIO~S CO~DITIO~ REQUIRED ACTIO~ COMPLETIO~ TIME A. One required inverter ------------------ ~ 0 TE-------------------

inoperable. Enter applicable conditions and required actions of LCO 3.8.9 "Distribution Systems - Operating" with any vital bus deenergized.

A.1 Restore inverter to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. A~D B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Vogtle Units 1 and 2 3.8.7-1 Amendment ~o. 96 (Unit 1)

Amendment ~o. 74 (Unit 2)

Inverters - Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage and alignment to 7 days required AC vital buses.

Vogtle Units 1 and 2 3.8.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters - Shutdown LCO 3.8.8 Inverters shall be OPERABLE to support the onsite Class 1E AC vital bus electrical power distribution subsystem(s) required by LCO 3.8.10, "Distribution Systems - Shutdown."

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected required Immediately inverters inoperable. feature(s) inoperable.

OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

A.2.3 Initiate action to suspend Immediately operations involving positive reactivity additions.

A.2.4 Initiate action to restore Immediately required inverters to OPERABLE status.

Vogtle Units 1 and 2 3.8.8-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Inverters - Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and alignments to 7 days required AC vital buses.

Vogtle Units 1 and 2 3.8.8-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Distribution Systems - Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.8.9 The required AC, DC, and AC vital bus electrical power distribution sUbsystems shall be OPERABLE.

1\10TE--------------------------------------------

The redundant emergency buses of 4160 V switchgear 1/2AA02 and 1/2BA03 may be manually connected within the unit by tie breakers in order to allow transfer of preferred offsite power sources provided SR 3.8.1.1 is successfully performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months prior to the interconnection. The interconnection shall be implemented without adversely impacting the ability to simultaneously sequence both trains of LOCA loads.

APPLICABILITY: MODES 1,2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more AC A.1 Restore AC electrical 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months electrical power power distribution distribution subsystems subsystems to AND inoperable. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO B. One or more AC vital bus B.1 Restore AC vital bus 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power electrical power distribution subsystems distribution subsystems to AND inoperable. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO (conti nued)

Vogtle Units 1 and 2 3.8.9-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more DC C.1 Restore DC electrical 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months electrical power power distribution distribution subsystems subsystems to AND inoperable. OPERABLE status.

16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO D. Required Action and 0.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND 0.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Two or more electrical E.1 Enter LCO 3.0.3. Immediately power distribution subsystems inoperable that result in a loss of function.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to 7 days required AC, DC, and AC vital bus electrical power distribution subsystems.

Vogtle Units 1 and 2 3.8.9-2 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

Distribution Systems - Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems - Shutdown LCO 3.8.10 The necessary portion of AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE to support equipment required to be OPERABLE.

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare associated Immediately AC, DC, or AC vital bus supported required electrical power feature(s) inoperable.

distribution subsystems inoperable. OR A.2.1 Suspend CORE Immediately ALTERATIONS.

AND A.2.2 Suspend movement of Immediately irradiated fuel assemblies.

AND A.2.3 Initiate action to suspend Immediately operations involving positive reactivity additions.

(continued)

Vogtle Units 1 and 2 3.8.10-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Distribution Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore Immediately required AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

A.2.5 Declare associated Immediately required residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to 7 days required AC, DC, and AC vital bus electrical power distribution subsystems.

Vogtle Units 1 and 2 3.8.10-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System, the refueling canal, and the refueling cavity shall be maintained within the limit specified in the COLR.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Boron concentration not A.1 Suspend CORE Immediately within limit. ALTERATIONS.

AND A.2 Suspend positive Immediately reactivity additions.

AND A.3 Initiate action to restore Immediately boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months specified in the COLR.

Vogtle Units 1 and 2 3.9.1-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the closed position.

NOTE--------------------------------------------

Valves in the flowpath from the RMWST, through the chemical mixing tank, to the suction of the charging pumps may be opened under administrative control provided the reactor coolant system is in compliance with Specification 3.9.1 and the high flux at shutdown alarm is OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS

NOTE---------------------------------------------------------------

Separate Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------------NOTE------------- A.1 Suspend CORE Immediately Required Action A.3 must ALTERATIONS.

be completed whenever Condition A is entered. AND A.2 Initiate actions to secure Immediately One or more valves not valve in closed position.

secured in closed position.

AND A.3 Perform SR 3.9.1.1 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (verify boron concentration).

Vogtle Units 1 and 2 3.9.2-1 Amendment No. 96 (Unit 1)

Amendment NO.74 (Unit 2)

Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water 31 days sources is secured in the closed position.

Vogtle Units 1 and 2 3.9.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One source range neutron A. 1 Suspend CORE Immediately flux monitor inoperable. ALTERATIONS.

AND A.2 Suspend positive Immediately reactivity additions.

B. --------------NOTE------------ B.1 Initiate action to restore Immediately Condition A entry is one source range required when Condition B neutron flux monitor to is entered. OPERABLE status.

AND Two source rallge neutron flux monitors inoperable. B.2 Perform SR 3.9.1.1 Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (verify boron concentration).

Vogtle Units 1 and 2 3.9.3-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.9.3.2 -----------------------------N()TE--------------------------

Neutron detectors are excluded from CHANNEL CALIBRATI()N.

Perform CHANNEL CALIBRATI()N. 18 months Vogtle Units 1 and 2 3.9.3-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Containment Penetrations 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Penetrations LCO 3.9.4 The containment penetrations shall be in the following status:

a. The equipment hatch is capable of being closed and held in place by four bolts;

b. The emergency and personnel air locks are isolated by at least one air lock door, or if open, the emergency and personnel air locks are isolable by at least one air lock door with a designated individual available to close the open air lock door(s); and

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. capable of being closed by at least two OPERABLE Containment Ventilation Isolation valves APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment A.1 Suspend CORE Immediately penetrations not in ALTERATIONS.

required status.

A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.

Vogtle Units 1 and 2 3.9.4-1 Amendment No. 115 (Unit 1)

Amendment No. 93 (Unit 2)

Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is 7 days in the required status.

SR 3.9.4.2 --------------------------NOTE--------------------------

Only required for unisolated penetrations.

Verify at least two containment ventilation valves 18 months in each open containment ventilation penetration providing direct access from the containment atmosphere to the outside atmosphere are capable of being closed from the control room.

SR 3.9.4.3 --------------------------NOTE---------------------------

Only required for an open equipment hatch.

Verify the capability to install the equipment 7 days hatch.

Vogtle Units 1 and 2 3.9.4-2 Amendment No. 115 (Unit 1)

Amendment No. 93 (Unit 2)

RHR and Coolant Circulation - High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation.

NOTE------------------------------------------

The required RHR loop may be removed from operation for::;; 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period, provided no operations are permitted that would cause a reduction of the Reactor Coolant System boron concentration.

APPLICABILITY: MODE 6 with the water level ~ 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements A.1 Suspend operations Immediately not met. involving a reduction in reactor coolant boron concentration.

AND A.2 Suspend loading Immediately irradiated fuel assemblies in the core.

AND A.3 Initiate action to satisfy Immediately RHR loop requirements.

AND (continued)

Vogtle Units 1 and 2 3.9.5-1 Amendment No. 96 (Unit 1)

Amendment No.74 (Unit 2)

RHR and Coolant Circulation - High Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) AA Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of ~ 3000 gpm.

Vogtle Units 1 and 2 3.9.5-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

RHR and Coolant Circulation - Low Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level LCO 3.9.6 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

APPLICABILITY: MODE 6 with the water level < 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A. 1 Initiate action to restore Immediately number of RHR loops required RHR loops to OPERABLE. OPERABLE status.

OR A.2 Initiate action to Immediately establish ~ 23 ft of water above the top of reactor vessel flange.

B. No RHR loop in operation. B.1 Suspend operations Immediately involving a reduction in reactor coolant boron concentration.

AND (continued)

Vogtle Units 1 and 2 3.9.6-1 Amendment No. 137 (Unit 1)

Amendment No. 116 (Unit 2)

RHR and Coolant Circulation - Low Water Level 3.9.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Initiate action to restore Immediately one RHR loop to operation.

AND B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months reactor coolant at a flow rate of ~ 3000 gpm.

Vogtle Units 1 and 2 3.9.6-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained ~ 23 ft above the top of reactor vessel flange.

APPLICABILITY: During CORE ALTERATIONS, except during latching and unlatching of control rod drive shafts, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend CORE Immediately not within limit. ALTERATIONS.

AND A.2 Suspend movement of Immediately irradiated fuel assemblies within containment.

Vogtle Units 1 and 2 3.9.7-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Refueling Cavity Water Level 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is ~ 23 ft above 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the top of reactor vessel flange.

Vogtle Units 1 and 2 3.9.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site 4.1.1 Site and Exclusion Area Boundaries (EAB)

The VEGP site and EAB consist of approximately 3,169 acres in eastern Georgia on the west side of the Savannah River about 26 miles southeast of Augusta, Georgia, and 15 miles east-northeast of Waynesboro, Georgia, in Burke County, Georgia. The nearest point to the EAB from the VEGP Reactors is the near bank of the Savannah River. Reactor 1 is approximately 3600 feet from the EAB and Reactor 2 is approximately 3900 feet from the EAB.

4.1.2 Low Population Zone (LPZ)

The LPZ is that area falling within a 2-mile radius from the midpoint between the containment buildings.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy or ZIRLO' clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U0 2 ) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing may be placed in non limiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control material shall be silver-indium-cadmium, or hafnium metal as approved by the NRC.

(continued)

Vogtle Units 1 and 2 4.0-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality (Unit 1) 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. Kef! < 1.0 when fully flooded with unborated water which includes an allowance for uncertainties as described in Section 4.3 of the FSAR.

c. Kef! ~ 0.95 when fully flooded with water borated to 511 ppm, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

d. New or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figures 3.7.18-1 or satisfying a minimum Integral Fuel Burnable Absorber (IFBA) requirement as shown in Figure 4.3.1-7 may be allowed unrestricted storage in the Unit 1 fuel storage pool.

e. New or partially spent fuel assemblies with a maximum initial enrichment of 5.0 weight percent U-235 may be stored in the Unit 1 fuel storage pool in a 3-out-of-4 checkerboard storage configuration as shown in Figure 4.3.1-1.

Interfaces between storage configurations in the Unit 1 fuel storage pool shall be in compliance with Figure 4.3.1-3. "A" assemblies are new or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figure 3.7.18-1, or which satisfy a minimum IFBA requirement as shown in Figure 4.3.1-7. "B" assemblies are assemblies with initial enrichments up to a maximum of 5.0 weight percent U-235.

(continued)

Vogtle Units 1 and 2 4.0-2 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued)

f. A nominal 10.25 inch center to center pitch in the Unit 1 high density fuel storage racks.

(Unit 2) 4.3.1.2 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. Keff < 1.0 when fully flooded with unborated water which includes an allowance for uncertainties as described in Section 4.3 of the FSAR.

c. Keff ~ 0.95 when fully flooded with water borated to 394 ppm, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

d. New or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figure 3.7.18-2 may be allowed unrestricted storage in the Unit 2 fuel storage pool.

e. New or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figure 4.3.1-8 may be stored in the Unit 2 fuel storage pool in a 3-out-of-4 checkerboard storage configuration as shown in Figure 4.3.1-1.

New or partially spent fuel assemblies with a maximum initial enrichment of 5.0 weight percent U-235 may be stored in the Unit 2 fuel storage pool in a 2-out-of-4 checkerboard storage configuration as shown in Figure 4.3.1-1.

New or partially spent fuel assemblies with a combination of burnup, decay time, and initial nominal enrichment in the "acceptable burnup domain" of Figure 4.3.1-10 may be stored (continued)

Vogtle Units 1 and 2 4.0-3 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) in the Unit 2 fuel storage pool as "low enrichment" fuel assemblies in the 3x3 checkerboard storage configuration as shown in Figure 4.3.1-2. New or partially spent fuel assemblies with initial nominal enrichments less than or equal to 3.20 weight percent U-235 or which satisfy a minimum IFBA requirement as shown in Figure 4.3.1-9 for higher initial enrichments may be stored in the Unit 2 fuel storage pool as "high enrichment" fuel assemblies in the 3x3 checkerboard storage configuration as shown in Figure 4.3.1-2.

Interfaces between storage configurations in the Unit 2 fuel storage pool shall be in compliance with Figures 4.3.1-3,4.3.1-4, 4.3.1-5, and 4.3.1-6. "A" assemblies are new or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figure 3.7.18

2. "B" assemblies are new or partially spent fuel assemblies with a combination of burnup and initial nominal enrichment in the "acceptable burnup domain" of Figure 4.3.1-8. "e" assemblies are assemblies with initial enrichments up to a maximum of 5.0 weight percent U-235. "L" assemblies are new or partially spent fuel assemblies with a combination of burnup, decay time, and initial nominal enrichment in the "acceptable burnup domain" of Figure 4.3.1-10. "H" assemblies are new or partially spent fuel assemblies with initial nominal enrichments less than or equal to 3.20 weight percent U-235 or which satisfy a minimum IFBA requirement as shown in Figure 4.3.1-9 for higher initial enrichments.

f. A nominal 10.58-inch center to center pitch in the north-south direction and a nominal 1OA-inch center to center pitch in the east-west direction in the Unit 2 high density fuel storage racks.

(continued)

Vogtle Units 1 and 2 4.0-4 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.1.3 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.05 weight percent;

b. kelt :s; 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

c. keff :s; 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR; and

d. A nominal 21-inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 Drainage The spent fuel storage pool is designed and shall be maintained to prevent inadvertent draining of the pool below elevation 194 foot-1 1/2 inch.

4.3.3 Capacity The spent fuel storage pool is designed and shall be maintained with a storage capacity limited to no more than 1476 fuel assemblies in the Unit 1 storage pool and no more than 2098 fuel assemblies in the Unit 2 storage pool.

Vogtle Units 1 and 2 4.0-5 Amendment No. 102 (Unit 1)

Amendment No. 80 (Unit 2)

Design Features 4.0 3-out-of-4 Checkerboard Storage (Units 1 and 2) 2-out-of-4 Checkerboard Storage (Unit 2)

D Empty Storage Cell 11><11 Fuel Assembly in Storage CeO Figure 4.3.1-1 Vogtle Units 1 and 2 Empty Cell Checkerboard Storage Configurations Vogtle Units 1 and 2 4.0-6 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 3x3 Checkerboard Storage I_I Low Enrichment Fnel Assembly in Storage Cell I;l High Enrichment Fnel LJ Assembly in Storage Cell Figure 4.3.1-2 Vogtle Unit 2 3x3 Checkerboard Storage Configuration Vogtle Units 1 and 2 4.0-7 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 A A A A A A A A A A A A Note:

Interface A = All Cell A A A A A A

~-

Enrichment B = 3-0ut-Of-4 Empty B Empty A A A Enrichment Empty = Empty Cell B B B A A A Empty B Empty A A A Boundary Between All Cell Storage and 3-out-of-4 Storage (Units 1 and 2)

A A A A A A Note:

A A A A A A A = AnCell Enrichment Interface A A A A A A B = 3-0ut-Of-4

~ Enrichment C = 2-0ut-Of-4 Empty B Empty A A A Enrichment Empty = Empty Cell C Empty B A A A Empty C Empty A A A Boundary Between All Cell Storage and 2-out-of-4 Storage (Unit 2)

Note:

1. A row of empty cells can be used at the interface to separate the configurations.

2. It is acceptable to replace an assembly with an empty cell.

Figure 4.3.1-3 Vogtle Units 1 and 2 Interface Requirements (All Cell to Checkerboard Storage)

Vogtle Units 1 and 2 4.0-8 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 B Empty B Empty B Empty Note:

B B B B B B B = 3-0ut-Of-4 Enrichment Interface B Empty B Empty B Empty C = 2-0ut-Of-4

.......... Enrichment Empty = Empty CeU Empty C Empty B B B C Empty C Empty B Empty Empty C Empty B B B I

Boundary Between 2-out-of-4 Storage and 3-out-of-4 Storage Empty B Empty B B B Note:

B B B B Empty B B = 3-0ut-Of-4 Enrichment Interface Empty B Empty B B B C = 2-0ut-Of-4

.........

Enrichment Empty = Empty CeU C Empty C Empty B Empty Empty C Empty B B B C Empty C Empty B Empty I

Boundary Between 2-out-of-4 Storage and 3-out-of-4 Storage Note:

1. A row of empty cells can be used at the interface to separate the configurations.

2. It is acceptable to replace an assembly with an empty cell.

Figure 4.3.1-4 Vogtle Unit 2 Interface Requirements (Checkerboard Storage Interface)

Vogtle Units 1 and 2 4.0-9 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 A A A A A A Note:

A A A A A A A = All CeU Enrichment L = Low Enrichment of 3x3 Checkerboard Interface L L L L A A H = High Enrichment of

" L L L L A A 3x3 Checkerboard L H L L A A L L L L A A I

Note:

1. A row of empty cells can be used at the interface to separate the configurations.

2. It is acceptable to replace an assembly with an empty cell.

Figure 4.3.1-5 Vogtle Unit 2 Interface Requirements (3x3 Checkerboard to All Cell Storage)

Vogtle Units 1 and 2 4.0-10 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 B B B B B B*

Note:

Empty B Empty B Empty B B = 3-0ut-or-4 Enrichment Interface L L L L B B L = Low Enrichment

......... of 3x3 Storage H = High Enrichment of L L L L Empty B 3x3 Storage Empty = Empty CeO L H L L B B L L L L Empty B I

Boundary Between 3x3 Storage and 3-out-of-4 Storage C Empty C Empty C Empty Note:

B = 3-out-Of-4 Empty B Empty B Empty C Enrichment L = Low Enrichment Interface of 3x3 Storage L L** L L** B Empty

........

H = High Enrichment of 3x3 Storage L Empty C C = 2-out-or-4 L L L Enrichment Empty = Empty Cell L H L L** B Empty L L L L Empty C I

Boundary Between 3x3 Storage and 2-out-of-4 Storage Note:

1. A row of empty cells can be used at the interface to separate the configurations.

2. It is acceptable to replace an assembly with an empty cell.

3. For the 3-out-of-4 configuration, the row beyond the Low enrichment can swap empty and and B assemblies, however the next outer row must change the indicated assembly ("') to an empty cell.

4. For the 2-out-of-4 configuration, the row beyond the Low enrichment can swap empty and B assemblies, however the next outer row of empty and C assemblies must also swap locations.

S. If empty cells are in indicated locations ("'), then the face adjacent B assemblies can be C assemblies.

Figure 4.3.1-6 Vogtle Unit 2 Interface Requirements (3x3 to Empty Cell Checkerboard Storage)

Vogtle Units 1 and 2 4.0-11 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 140

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Figure 4.3.1-7 Vogtle Unit 1 IFBA Credit Requirements for All Cell Storage Vogtle Units 1 and 2 4.0-12 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 25,000

--- _ L- - - - --- -.. - -~

_ . _ - ~

V 20,000 V

V

/ f-I IACCEPTABLEI V 15,000

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2.0 2.5 3.0 3.5 4.0 4.5 5.0 235 Initial U Enrichment (nominal w/o)

Figure 4.3.1-8 Vogtle Unit 2 Burnup Credit Requirements for 3-out-of-4 Storage Vogtle Units 1 and 2 4.0-13 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 100 90 80

/

II 70

>. l'

c I E J 1II 1---

til ACCEPTABLE /

~ 60

...1II ---- _. -~---

------ f---C-- - - - ------ - - -- - -

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IFBA Q. /

til I -1.0X "C

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Figure 4.3.1-9 Vogtle Unit 2 IFBA Credit Requirements for Center Assembly for 3x3 Storage Vogtle Units 1 and 2 4.0-14 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Design Features 4.0 55,000 50,000 Decay I Time I

./ - 0 years 1/

45,000 /I - 5 years

,I i - 1 0 years V - 1 5 years

~'

V ://. - 2 0 years 40,000 1/ ~.

. f . - ..+ . - /

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IUNACCEPTABLE ft

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Figure 4.3.1-10 Vogtle Unit 2 Burnup Credit Requirements for Peripheral Assemblies for 3x3 Storage Vogtle Units 1 and 2 4.0-15 Amendment No. 139 (Unit 1)

Amendment No. 118 (Unit 2)

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Plant Manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during his absence.

The Vice President - Vogtle or his designee shall approve, prior to implementation, each proposed test, experiment, or modification to systems or equipment that affect nuclear safety.

5.1.2 A Senior Reactor Operator (SRO) shall be responsible for the control room command function while either unit is in MODES 1, 2, 3, or 4, or it is acceptable to designate an SRO as responsible for the control room command function for each unit. While both units are in MODE 5, 6, or defueled, an SRO or Reactor Operator (RO) shall be designated to assume the control room command function.

Vogtle Units 1 and 2 5.1-1 Amendment No. 148 (Unit 1)

Amendment No. 128 (Unit 2)

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting the safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements shall be documented in the FSAR;

b. The Plant Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. The Vice President - Vogtle shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor and an additional non-licensed operator shall be assigned for the control room when a reactor is operating in MODES 1, (continued)

Vogtle Units 1 and 2 5.2-1 Amendment No. 148 (Unit 1)

Amendment No. 128 (Unit 2)

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) 2, 3, or 4. With both units in MODES 5 or 6 or defueled, a total of three non-licensed operators are required for the two units.

b. At least one licensed RO shall be present in the control room when fuel is in the reactor.

NOTE-----------------------------------------------

A single SRO licensed on both units may fulfill this function for both units.

In addition, while the unit is in MODE 1, 2, 3, or 4, at least one licensed SRO shall be present in the control room.

c. The shift crew composition may be less than the minimum requirement of 10 CFR 50.54 (m)(2)(i) and 5.2.2.a and g for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

d. ----------------------------------------NOTE-----------------------------------------------

A single Health Physics Technician may fulfill this position for both units.

A Health Physics Technician shall be on site when fuel is in the reactor.

The position may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required position.

e. Administrative procedures shall be developed and implemented to limit the working hours of unit staff who perform safety-related functions (e.g., licensed SROs, licensed ROs, key health physics technicians, key non-licensed operators, and key maintenance personnel).

Adequate shift coverage shall be maintained without routine heavy use of overtime. The objective shall be to have operating personnel work an 8 or 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months day, nominal 40 hour4.62963e-4 days 0.0111 hours 6.613757e-5 weeks 1.522e-5 months week while the unit is operating. However, in the (continued)

Vogtle Units 1 and 2 5.2-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) event that unforeseen problems require substantial amounts of overtime to be used, or during extended periods of shutdown for refueling, major maintenance, or major plant modification, on a temporary basis the following guidelines shall be followed:

1. An individual should not be permitted to work more than 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months straight, excluding shift turnover time;

2. An individual should not be permitted to work more than 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months in any 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months period, nor more than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months in any 48 hour5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months period, nor more than 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months in any 7 day period, all excluding shift turnover time;

3. A break of at least 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months should be allowed between work periods, including shift turnover time;

4. Except during extended shutdown periods, the use of overtime should be considered on an individual basis and not for the entire staff on a shift.

Any deviation from the above guidelines shall be authorized by the applicable department manager or higher levels of management, in accordance with established procedures and with documentation of the basis for granting the deviation.

Controls shall be included in the procedures such that individual excess overtime shall be reviewed monthly by the Plant Manager or his designee to assure that excessive hours were authorized and that they do not become routine.

f. The Operations Manager or at least one Operations Superintendent shall hold an SRO license.

g. An individual shall be assigned who provides technical support in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This individual shall be available for duty when the plant is in modes 1-4. At other times, this individual is not required. In addition, this individual shall meet the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift.

This position may also be filled by the Shift Superintendent or (continued)

Vogtle Units 1 and 2 5.2-3 Amendment No. 153 (Unit 1)

Amendment No. 134 (Unit 2)

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued) the individual with an SRO license provided that person meets the qualifications specified by the Commission Policy Statement on Engineering Expertise on Shift.

Vogtle Units 1 and 2 5.2-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff, including Vice President - Vogtle and Plant Manager, shall meet or exceed the minimum qualifications of Regulatory Guide 1.8, Revision 2,1987, and, for licensed staff, 10 CFR 55.59. Priorto meeting the recommendations of Regulatory Guide 1.8, Revision 2, personnel may be trained to perform specific tasks and will be qualified to perform those tasks independently. Personnel who complete an accredited program which has been endorsed by the NRC shall meet the requirements of the accredited program in lieu of the above. The Operations Manager shall meet or exceed the above requirements except that Technical Specification 5.2.2.f shall specify the requirements regarding the holding of an SRO license.

Vogtle Units 1 and 2 5.3-1 Amendment No. 153 (Unit 1)

Amendment No. 134 (Unit 2)

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for eft'luent and environmental monitoring;

d. Fire Protection Program implementation; and

e. All programs specified in Specification 5.5.

Vogtle Units 1 and 2 5.4-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the Radioactive Effluent Controls and Radiological Environmental Monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating and Radioactive Effluent Release Reports required by Specification 5.6.2 and Specification 5.6.3.

Licensee initiated changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained.

This documentation shall contain:

1. sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s),

2. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

b. Shall become effective after the approval of the Vice President - Vogtle; and

c. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page (continued)

Vogtle Units 1 and 2 5.5-1 Amendment No. 148 (Unit 1)

Amendment No. 128 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued) that was changed, and shall indicate the date (Le., month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include:

1) Residual Heat Removal System;

2) Containment Spray System;

3) Safety Injection (excluding Boron Injection and Accumulators);

4) Chemical and Volume Control System (Letdown and Charging Systems);

5) Post Accident Processing System (until such time as a modification eliminates the Post Accident Processing System as a potential leakage path);

6) Gaseous Waste Processing System; and

7) Nuclear Sampling System (Pressurizer steam and liquid sampling lines, Reactor Coolant sample lines, RHR sample lines, CVCS Demineralizer and Letdown Heat Exchanger sample lines only).

The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Leak test requirements for each system at least once per 18 months. The provisions of SR 3.0.2 are applicable 5.5.3 Not Used.

(continued)

Vogtle Units 1 and 2 5.5-2 Amendment No. 123 (Unit 1)

Amendment No. 101 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the aDCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the aDCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to ten times the concentrations stated in 10 CFR 20, Appendix B (to paragraphs 20.1001-20.2401),

Table 2, Column 2;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the aDCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the aDCM at least every 31 days;

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that (continued)

Vogtle Units 1 and 2 5.5-3 Amendment No. 123 (Unit 1)

Amendment No. 101 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued) appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents to areas at and beyond the site boundary as follows:

1. For noble gases: dose rates of S 500 mrem/yr to the whole body and 3000 mrem/yr to the skin, and

2. For iodine-131, iodine-133, tritium, and for all radionuclides in particulate form with half-lives> 8 days: a dose rate of S 1500 mrem/yr to any organ;

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I;

i. Limitations on the annual and quarterly doses to a member of the public from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives> 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and

j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the cyclic and transient occurrences to ensure that components are maintained within the design limits. The component cyclic or transient limits are provided in FSAR, Section 3.9.

(contin ued)

Vogtle Units 1 and 2 5.5-4 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.6 Prestressed Concrete Containment Tendon Surveillance Program This program provides controls for monitoring any tendon degradation in prestressed concrete containments, including effectiveness of its corrosion protection medium, to ensure containment structural integrity. The program shall include baseline measurements prior to initial operations. The Tendon Surveillance Program, inspection frequencies, and acceptance criteria shall be in accordance with ASME Boiler and Pressure Vessel Code Section XI, Subsection IWL and applicable addenda as required by 10 CFR 50.55a except where an exemption, relief, or alternative has been authorized by the NRC.

The provisions of SR 3.0.3 are applicable to the Tendon Surveillance Program inspection frequencies.

5.5.7 Reactor Coolant Pump Flywheel Inspection Program This program shall provide for the inspection of each reactor coolant pump flywheel at least once per 10 years by conducting either:

a. An in-place ultrasonic examination over the volume from the inner bore of the flywheel to the circle of one-half the outer radius; or

b. A surface examination (magnetic particle and/or liquid penetrant) of exposed surfaces of the disassembled flywheel.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Reactor Coolant Pump Flywheel Inspection Program.

(continued)

Vogtle Units 1 and 2 5.5-5 Amendment No. 147 (Unit 1)

Amendment No. 127 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a. Testing frequencies specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as follows:

ASME Boiler and Pressure Vessel Code and applicable Required Frequencies for Addenda terminology for performing inservice inservice testing activities testing activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every At least once per 184 days 6 months Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies for performing inservice testing activities;

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME Boiler and Pressure Vessel Code shall be construed to supersede the requirements of any TS.

(continued)

Vogtle Units 1 and 2 5.5-6 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tUbe structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

(continued)

Vogtle Units 1 and 2 5.5-7 Amendment No. 144 (Unit 1)

Amendment No. 124 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued)

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 1 gpm per SG.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

The following alternate tUbe repair criteria shall be applied as an alternative to the 40% depth based criteria:

1. For Unit 2 during Refueling Outage 11 and the subsequent operating cycle, degradation found in the portion of the tube below 17 inches from the top of the hot leg tubesheet does not require plugging.

For Unit 2 during Refueling Outage 11 and the subsequent operating cycle, degradation identified in the portion of the tube from the top of the hot leg tubesheet to 17 inches below the top of the tubesheet shall be plugged upon detection.

2. For Unit 1 during Refueling Outage 13 and the subsequent operating cycle, and for Unit 2 during Refueling Outage 12 and the subsequent operating cycle, degradation identified in the portion of the tube below 17 inches from the top of the hot leg tubesheet does not require plugging.

For Unit 1 during Refueling Outage 13 and the subsequent operating cycle, and for Unit 2 during Refueling Outage 12 and the subsequent operating cycle, degradation identified in the portion of the tube from the top of the hot leg tubesheet to 17 inches below the top of the hot leg tubesheet shall be plugged upon detection.

3. For Unit 1 during Refueling Outage 14 and the subsequent operating cycle and for Unit 2 during Refueling Outage 13 and the subsequent operating cycle, tubes with flaws having a circumferential component less than or equal to 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the (continued)

Vogtle Units 1 and 2 5.5-8 Amendment No. 152 (Unit 1)

Amendment No. 133 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) bottom of the tubesheet do not require plugging. Tubes with flaws having a circumferential component greater than 203 degrees found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet shall be removed from service.

Tubes with service-induced flaws located within the region from the top of the tubesheet to 17 inches below the top of the tubesheet shall be removed from service. Tubes with service-induced axial cracks found in the portion of the tube below 17 inches from the top of the tubesheet do not require plugging.

When more than one flaw with circumferential components is found in the portion of the tube below 17 inches from the top of the tubesheet and above 1 inch from the bottom of the tubesheet with the total of the circumferential components greater than 203 degrees and an axial separation distance of less than 1 inch, then the tUbe shall be removed from service. When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

When one or more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet, and the total of the circumferential components found in the tUbe exceeds 94 degrees, then the tube shall be removed from service.

When one or more flaws with circumferential components are found in the portion of the tube within 1 inch from the bottom of the tubesheet, and within 1 inch axial separation distance of a flaw above 1 inch from the bottom of the tubesheet, and the total of the circumferential components found in the tube exceeds 94 degrees, then the tube shall be removed from service. When the circumferential components of each of the flaws are added, it is acceptable to count the overlapped portions only once in the total of circumferential components.

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tUbes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. For Unit 2 during Refueling Outage 11 and the subsequent operating cycle, the portion of the tube (continued)

Vogtle Units 1 and 2 5.5-9 Amendment No. 152 (Unit 1) I Amendment No. 133 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Program (continued) below 17 inches from the top of the hot leg tubesheet is excluded. For Unit 1 during Refueling Outage 13 and the sUbsequent operating cycle, and for Unit 2 during Refueling Outage 12 and the subsequent operating cycle, the portion of the tube below 17 inches from the top of the hot leg tubesheet is excluded. The tube-to-tubesheet weld is not part of the tube.

In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2. Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected.

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic nondestructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

5.5.10 Secondarv Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation. The program shall include:

(continued)

Vogtle Units 1 and 2 5.5-10 Amendment No. 152 (Unit 1)

Amendment No. 133 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.10 Secondary Water Chemistry Program (continued)

a. Identification of a sampling schedule for the critical variables and control points for these variables;

b. Identification of the procedures used to measure the values of the critical variables;

c. Identification of process sampling points;

d. Procedures for the recording and management of data;

e. Procedures defining corrective actions for all off control point chemistry conditions; and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.

5.5.11 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in accordance with Regulatory Guide 1.52, Revision 2, and ASME N510-1980:

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass ~ 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N51 0-1980 at the system flow rate specified below

+/- 10%.

ESF Ventilation System Flow Rate Control Room Emergency Filtration System (CREFS) 19,000 CFM Piping Penetration Area Filtration and Exhaust (PPAFES) 15,500 CFM

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass ~ 0.05% when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N51 0-1980 at the system flow rate specified below +/- 10%.

(continued)

Vogtle Units 1 and 2 5.5-11 Amendment No. 152 (Unit 1)

Amendment No. 133 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testing Program (VFTP) (continued)

ESF Ventilation System Flow Rate CREFS 19,000 CFM PPAFES 15,500 CFM

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than or equal to the value specified below when tested in accordance with ASTM 03803-1989 at a temperature of 30°C and greater than or equal to the relative humidity specified below.

ESF Ventilation System Penetration RH CREFS .2% 70%

PPAFES 10% 95%

d. Demonstrate for each of the ESF systems that the pressure drop across the combined HEPA filters, the charcoal adsorbers, and CREFS cooling coils is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ASME N51 0-1989 at the system flow rate specified below +/- 10%.

ESF Ventilation System Delta P Flow Rate CREFS 7.1 in. 19,000 CFM water gauge PPAFES 6 in. 15,500 CFM water gauge

e. Demonstrate that the heaters for the CREFS dissipate ~ 95 kW when corrected to 460 V when tested in accordance with ASME N510-1989.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Gaseous Waste Processing System, the quantity of radioactivity contained in each Gas Decay Tank, and the quantity of radioactivity contained in (conti nued)

Vogtle Units 1 and 2 5.5-12 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program (continued) unprotected outdoor liquid storage tanks. The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure." The liquid radwaste quantities shall be limited to 10 curies per outdoor tank in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures."

The program shall include:

a. The limits for concentrations of hydrogen and oxygen in the Gaseous Waste Processing System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (I.e., whether or not the system is designed to withstand a hydrogen explosion);

b. A surveillance program to ensure that the quantity of radioactivity contained in each gas decay tank is less than the amount that would result in a whole body exposure of ~ 0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and

c. A surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is limited to S 10 curies per tank, excluding tritium and dissolved or entrained noble gases. This surveillance program provides assurance that in the event of an uncontrolled release of the tank's contents, the resulting concentrations would be less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2, at the nearest potable water supply and the nearest surface water supply in an unrestricted area.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

5.5.13 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

(continued)

Vogtle Units 1 and 2 5.5-13 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Diesel Fuel Oil Testing Program (continued)

1. an API gravity or an absolute specific gravity within limits, or an API gravity or specific gravity within limits when compared to the supplier's certificate;

2. a flash point within limits for ASTM 2D fuel oil, and, if gravity was not determined by comparison with supplier's certification, a kinematic viscosity within limits for ASTM 2D fuel oil; and

3. a clear and bright appearance with proper color.

b. Other properties for.ASTM 2D fuel oil are within limits within 30 days following sampling and addition to storage tanks; and

c. Total particulate concentration of the fuel oil is S 10 mgtl when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program surveillance frequencies.

5.5.14 Technical Specifications nS) Bases Control Program This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either of the following:

1. a change in the TS incorporated in the license; or

2. a change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

d. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

e. Proposed changes that meet the criteria of (b) above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71 (e).

(continued)

Vogtle Units 1 and 2 5.5-14 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.15 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

a. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

b. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

c. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

d. Other appropriate limitations and remedial or compensatory actions.

A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

a. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or

b. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or

c. A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

(continued)

Vogtle Units 1 and 2 5.5-15 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.16 MS and FW Piping Inspection Program This program shall provide for the inspection of the four Main Steam and Feedwater lines from the containment penetration flued head outboard welds, up to the first five-way restraint. The extent of the inservice examinations completed during each inspection interval (ASME Code Section XI) shall provide 100%

volumetric examination of circumferential and longitudinal welds to the extent practical. This augmented inservice inspection is consistent with the requirements of NRC Branch Technical Position MEB 3-1, "Postulated Break and Leakage Locations in Fluid System Piping Outside Containment," November 1975 and Section 6.6 of the FSAR.

5.5.17 Containment Leakage Rate Testing Program A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(0) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Testing Program," dated September 1995, as modified by the following exceptions:

1. Leakage rate testing for containment purge valves with resilient seals is performed once per 18 months in accordance with LCO 3.6.3, SR 3.6.3.6 and SR 3.0.2.

2. Containment personnel air lock door seals will be tested prior to reestablishing containment integrity when the air lock has been used for containment entry. When containment integrity is required and the air lock has been used for containment entry, door seals will be tested at least once per 30 days during the period that containment entry(ies) is (are) being made.

3. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by ASME Section XI Code, Subsection IWL, except where relief or alternative has been authorized by the NRC. At the discretion of the licensee, the containment concrete visual examinations may be performed during either power operation, e.g., performed concurrently with other containment inspection-related activities such as tendon testing, or during a maintenance/refueling outage.

(continued)

Vogtle Units 1 and 2 5.5-16 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.17 Containment Leakage Rate Testing Program (continued)

4. A one time exception to NEI 94-01, Rev. 0, "Industry Guidelines for Implementing Performance-Based Option of 10 CFR 50, Appendix J":

Section 9.2.3: The next Type A test, after the March 2002 test for Unit 1 and the March 1995 test for Unit 2, shall be performed within 15 years.

The peak calculated primary containment internal pressure for the design basis loss of coolant accident, Pal is 37 psig.

The maximum allowable containment leakage rate, La, at Pa, is 0.2% of primary containment air weight per day.

Leakage rate acceptance criteria are:

a. Containment overall leakage rate acceptance criteria are ~ 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are' ~ 0.60 La for the combined Type B and Type C tests, and ~ 0.75 La for Type A tests;

b. Air lock testing acceptance criteria are:

1) Overall air lock leakage rate is ~ 0.05 La when tested at;?: Pa,

2) For each door, the leakage rate is ~ 0.01 La when pressurized to

~ Pa .

The provisions of SR 3.0.2 do not apply to the test frequencies specified in the Containment Leakage Rate Testing Program.

The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

5.5.18 Configuration Risk Management Program The Configuration Risk Management Program (CRMP) provides a proceduralized risk-informed assessment to manage the risk associated with equipment inoperability. The program applies to technical specification structures, systems, or components for which a risk-informed allowed outage time has been granted. The program shall include the following elements:

(continued)

Vogtle Units 1 and 2 5.5-17 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.18 Configuration Risk Management Program (continued)

a. Provisions for the control and implementation of a Level 1 at power internal events PRA-informed methodology. The assessment shall be capable of evaluating the applicable plant configuration.

b. Provisions for performing an assessment prior to entering the LCO Condition for preplan ned activities.

c. Provisions for performing an assessment after entering the LCO Condition for unplanned entry into the LCO Condition.

d. Provisions for assessing the need for additional actions after the discovery of additional equipment out of service conditions while in the LCO Condition.

e. Provisions for considering other applicable risk significant contributors such as Level 2 issues and external events, qualitatively or quantitatively.

5.5.19 Battery Monitoring and Maintenance Program This program provides for restoration and maintenance, based on the recommendations of IEEE Standard 450-1995, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," of the following:

a. Actions to restore battery cells with float voltage < 2.13 V, and b Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates.

Vogtle Units 1 and 2 5.5-18 Amendment No. 150 (Unit 1)

Amendment No. 130 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.20 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Filtration System (CREFS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem whole body or its equivalent to any part of the body for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and the CRE boundary.

b. Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors," Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision O.

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation by one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS. The results shall be trended and used as part of the 18 month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

(continued)

Vogtle Units 1 and 2 5.5-19 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.20 Control Room Envelope Habitability Program (continued)

f. The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability, determining CRE unfiltered inleakage, and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

Vogtle Units 1 and 2 5.5-20 Amendment No. 154 (Unit 1)

Amendment No. 135 (Unit 2)

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Deleted.

5.6.2 Annual Radiological Environmental Operating Report

NOTE-----------------------------------------------

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 15 of each year. The report shall include summaries, interpretations, and analyses of trends of the results of the Radiological Environmental Monitoring Program for the reporting period. The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM),

and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

(continued)

Vogtle Units 1 and 2 5.6-1 Amendment No. 135 (Unit 1)

Amendment No. 114 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.2 Annual Radiological Environmental Operating Report (continued)

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in a format similar to the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.3 Radioactive Effluent Release Report

NOTE-------------------------------------------------

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station; however, the submittal shall specify the releases of gaseous and liquid radioactive material from each unit and of solid radioactivity from the site.

The Radioactive Effluent Release Report covering the operation of the unit shall be submitted in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR 50, Appendix I, Section IV.B.1.

5.6.4 Deleted.

(continued)

Vogtle Units 1 and 2 5.6-2 Amendment No. 135 (Unit 1)

Amendment No. 114 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

LCO 3.1.1 "SHUTDOWN MARGIN" LCO 3.1.3 "Moderator Temperature Coefficient" LCO 3.1.5 "Shutdown Bank Insertion Limits" LCO 3.1.6 "Control Bank Insertion Limits" LCO 3.2.1 "Heat Flux Hot Channel Factor" LCO 3.2.2 "Nuclear Enthalpy Rise Hot Channel Factor" LCO 3.2.3 "Axial Flux Difference" LCO 3.9.1 "Boron Concentration"

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 0!::!.... Proprietary). (Methodology for Moderator Temperature Coefficient, Shutdown Bank Insertion Limit, Control Bank Insertion Limits, and Nuclear Enthalpy Rise Hot Channel Factor.)

WCAP-10216-P-A, Revision 1A, "RELAXATION OF CONSTANT AXIAL OFFSET CONTROL FQ SURVEILLANCE TECHNICAL SPECIFICATION," February, 1994 (W Proprietary). (Methodology for Axial Flux Difference (Relaxed Axial Offset Control) and Heat Flux Hot Channel Factor (W(Z) surveillance requirements for Fa Methodology).)

WCAP-10266-P-A, Revision 2, "The 1981 Version of the Westinghouse ECCS Evaluation Model Using the BASH Code," March 1987.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

(contin ued)

Vogtle Units 1 and 2 5.6-3 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR) (continued)

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a. RCS pressure and temperature limits for heatup, cooldown, operation, criticality, and hydrostatic testing as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

LCO 3.4.3 "RCS Pressure and Temperature (PIT) Limits"

b. The power operated relief valve lift settings required to support the Cold Overpressure Protection Systems (COPS) and the COPS arming temperature shall be established and documented in the PTLR for the following:

LCO 3.4.12 "Cold Overpressure Protection Systems"

c. The analytical methods used to determine the RCS pressure and temperature limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

1. WCAP-14040-A, Rev. 4, "Methodology Used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves."

2. WCAP-16142-P, Rev. 1, "Reactor Vessel Closure Head/Vessel Flange Requirements Evaluation for Vogtle Units 1 and 2."

3. The PTLR will contain the complete identification for each of the TS reference Topical Reports used to prepare the PTLR (i.e.,

report number, title, revision, date, and any supplements).

(continued)

Vogtle Units 1 and 2 5.6-4 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) (continued)

d. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

5.6.7 EDG Failure Report If an individual emergency diesel generator (EDG) experiences four or more valid failures in the last 25 demands, these failures and any nonvalid failures experienced by that EDG in that time period shall be reported within 30 days.

Reports on EDG failures shall include the information recommended in Regulatory Guide 1.9, Revision 3, Regulatory Position CA, or existing Regulatory Guide 1.108 reporting requirement.

5.6.8 PAM Report When a Report is required by Condition G or J of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

(continued)

Vogtle Units 1 and 2 5.6-5 Amendment No. 136 (Unit 1)

Amendment No. 115 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.9 Deleted.

5.6.10 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,

b. Active degradation mechanisms found,

c. Nondestructive examination techniques utilized for each degradation mechanism,

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e. Number of tubes plugged during the inspection outage for each active degradation mechanism,

f. Total number and percentage of tubes plugged to date,

g. The results of condition monitoring, including the results of tube pulls and in-situ testing,

h. Following completion of a Unit 1 inspection performed in Refueling Outage 14 (and any inspections performed in the subsequent operating cycle) and following completion of a Unit 2 inspection performed in Refueling Outage 13 (and any inspections performed in the subsequent operating cycle), the number of indications and location, size, orientation, whether initiated on primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the circumferential components and any circumferential overlap below 17 inches from the top of the tubesheet as determined in accordance with TS 5.5.9.c.3;

i. Following completion of a Unit 1 inspection performed in Refueling Outage 14 (and any inspections performed in the subsequent operating cycle) and following completion of a Unit 2 inspection performed in Refueling Outage 13 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each SG (if it is not practical to assign leakage to an individual SG, the entire primary to secondary LEAKAGE should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report; and

j. Following completion of a Unit 1 inspection performed in Refueling Outage 14 (and any inspections performed in the subsequent operating cycle) and following completion of a (continued)

Vogtle Units 1 and 2 5.6-6 Amendment No. 152 (Unit 1)

Amendment No. 133 (Unit 2)

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.10 Steam Generator Tube Inspection Report (continued)

Unit 2 inspection performed in Refueling Outage 13 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube below 17 inches from the top of the tubesheet for the most limiting accident in the most limiting SG.

Vogtle Units 1 and 2 5.6-7 Amendment No. 152 (Unit 1)

Amendment No. 133 (Unit 2)

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area 5.7.1 Pursuant to 10 CFR 20, paragraph 20.1601(c), in lieu of the requirements of 10 CFR 20.1601, each high radiation area, as defined in 10 CFR 20, in which the intensity of radiation is > 100 mrem/hr but < 1000 mrem/hr, shall be barricaded and conspicuously posted as a high radiation area, and entrance thereto shall be controlled by requiring issuance of a Radiation Work Permit (RWP). Individuals qualified in radiation protection procedures (e.g., Health Physics Technicians) or personnel continuously escorted by such individuals may be exempt from the RWP issuance requirement during the performance of their assigned duties in high radiation areas with exposure rates s 1000 mrem/hr, provided they are otherwise following plant radiation protection procedures for entry into such high radiation areas.

Any individual or group of individuals permitted to enter such areas shall be provided with or accompanied by one or more of the following:

a. A radiation monitoring device that continuously indicates the radiation dose rate in the area.

b. A radiation monitoring device that continuously integrates the radiation dose rate in the area and alarms when a preset integrated dose is received. Entry into such areas with this monitoring device may be made after the dose rate levels in the area have been established and personnel are aware of them.

c. An individual qualified in radiation protection procedures with a radiation dose rate monitoring device, who is responsible for providing positive control over the activities within the area and shall perform periodic radiation surveillance at the frequency specified by Health Physics supervision in the RWP.

5.7.2 In addition to the requirements of Specification 5.7.1, areas with radiation levels ~ 1000 mrem/hr shall be provided with locked or continuously guarded doors to prevent unauthorized entry, and the keys shall be maintained under the administrative control of Operations or health physics supervision. Doors shall remain locked except during periods of access by personnel under an approved RWP that shall specify the dose rate levels in the immediate work areas and the maximum allowable stay times for (continued)

Vogtle Units 1 and 2 5.7-1 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 (continued) individuals in those areas. In lieu of the stay time specification of the RWP, direct or remote (such as closed circuit TV cameras) continuous surveillance may be made by personnel qualified in radiation protection procedures to provide positive exposure control over the activities being performed within the area.

5.7.3 For individual high radiation areas within radiation levels of> 1000 mrem/hr, accessible to personnel, that are located within large areas such as reactor containment, where no enclosure exists for purposes of locking, or that cannot be continuously guarded, and where no enclosure can be reasonably constructed around the individual area, that individual area shall be barricaded and conspicuously posted, and a flashing light shall be activated as a warning device.

Vogtle Units 1 and 2 5.7-2 Amendment No. 96 (Unit 1)

Amendment No. 74 (Unit 2)

APPENDIX B ENVIRONMENTAL PROTECTION PLAN

APPENDIX B TO FACILITY OPERATING LICENSE NO. NPF-68 AND FACILITY OPERATING LICENSE NO. NPF-81 VOGTLE ELECTRIC GENERATING PLANT UNITS 1 AND 2 SOUTHERN NUCLEAR DOCKET NOS. 50-424 AND 50-425 ENVIRONMENTAL PROTECTION PLAN (NON RADIOLOGICAL)

Amendment No. 97 Amendment No. 75

1.0 Objectives of the Environmental Protection Plan The Environmental Protection Plan (EPP) is to provide for protection of nonradiological environmental values during operation of the nuclear facility.

The principal objectives of the EPP are as follows:

(I) Verify that the facility is operated in an environmentally acceptable manner, as established by the Final Environmental Statement - Operating License Stage (FES-OL) and other NRC environmental impact assessments.

(2) Coordinate NRC requirements and maintain consistency with other Federal, State and local requirements for environmental protection.

(3) Keep NRC informed of the environmental effects of facility construction and operation and of actions taken to control those effects.

Environmental concerns identified in the FES-OL which relate to water quality matters are regulated by way of the licensee's* NJPOES permit.

The term licensee, when used in the Vogtle Environmental Protection Plan, refers to Southern Nuclear Operating Company, Inc. (Southern Nuclear).

1-1 Amendment No. 97 Amendment No. 75

2.~ Enyiron~nta' Protection Issues In the FES (NlI~£G-I087), dated March, 1'85. the staff considered th, e~yiponment.l impacts .ssociated with the oPtratie~ nf the two unit V~9tlt Electric ~ne~atin; Plant (VEGP'. Certai~ env1~nment~' issues

~r, identified which required stuey, Dr license conditions to resolve

oneerns and Issure adequate protection of the environment.

2.1 AQuatic'lssues No specific aquatic issues wert identified in the YES.OL.

Ne specific terrestrial issues were ide"t1fied in the FES.OL.

2.3 Issues Related to Maintenance of Transmission Line Corriders Rout1"~ maintenance ~Qu1~nts for the .xt.nt of use of he~bicides, tr1~.~~

of the trees, Ind for preservltion o~ Nationl' Natura' Landmarks Ind H1sto~ic Places Ire d4lcuss.d in S.ctiDn 4.2.3.

2-]

2.4 Neise Issues Nrise 1.v~ls It residenc.s Ilong the trlnsmiss1~n lines could be s1ightly Ibev. ambient levels. ~onit~rinq requirements for ~oise assoc1lted with t~l"sm;ssion flcilities Ire specified in Section 4.2.4.

2*2

3.r Consistency _equire~ents 3.1 Pllnt Design .nd ~Pfrltion The lirensee ~IY ~ke chlnges in pl.nt design Dr nperltion Dr p.. rfo~

tests Dr experiMents .ffecting the envirnnment provided such .ctivities de not involve .n unrlviewtd environment.l question .nd de nnt involve.

ch.nge in th, EPP*. Ch.nges in pl.nt design or oper.tion Dr p,rfn~.nce of tests or experiments which do nnt .ffpct the tnvironment .re not subiett .

to the reQui~nts of this EPP. _ctivities gove~ed by Section 3.3 .~e not subject to the requirements of this S,ction.

B!~Clr, eng.gi n§l in addi tior.e 1 rO'lstruet i on or oper.tion.l .e t1vi ties W~I; c:~

~v significantly .ffect th, environment. the lic,n", sh.ll pr'Darr. and

~ecord .n env1ronment.l ev.lu.tion of such activity. Activities.re exclud,d from this requirement if .11 ...sur.ble nonr.diologic.l envir""

~nt.l 'ffects I~ confined to the on-sitt lre.s previously disturbed durinp Jite prep.ration and pl.nt construction. When the eVI1UItion 1ndic.tes th.t such Ictivi~ involves In unrevitw.d environment.l Question, the lic.ns.e sh.ll provid. I written ev.luation of such .ctivity .nd obtlin prior NRC approv.l. When such .ctivity involves I ch.nge in the [PP, such Ictivity and ch.nge to the EPP ~y bt implementtd ~nly in Iccord.nce with In IPpropri.t. licens. I..ndme~t .s set forth ir Section 5.3 of this EPP.

i This provision does not ~li,ve the lic,nsee of the ,.qu1rements o~

10 en 50.59.

3-1

A proposed change. test or experiment shall be deemed to 1ny~lve an unrevi~wed environmental question if it concerns: (1) a -.tter which may result in a significant increase in any .dyerse eny;ronmenta' 1~pact pr'Yiously ,Yaluated in the FES-OL. enYironme~ta' impact appraisals. or in an) dec;sions of the Atomic Safety and Licensing Boardi or (2) a significant change in effluents or power leYel; or (3) a matter, not prtviously reviewed a~d evaluated in the documents specified in (1) of t~1s ,Subsection. which

~y haye a significant adYerse env1ronmenta' impact.

The licensee sha'l ..1ntlin records of changes in plant design or operation and of tests and experiments carried out pursuant to this Sub section. These records shall include written evaluations which provide b~sp.s for the determination that the c~ange. test. or experiment does not involve In unreYiewed environmental question or constitute a decrease in the effect1Yeness of this EPP to ..et the objectives specified in Section 1.0.

The licensee shall include IS part of the Annual Environmental Operating Report (per Subsection 5.4.1) bri.f descriptions, Inalys.s, interpretlti~n$.

and ,va'uat1ons of such chlnges, tests and experiments.

3.2 Reporting Related to the "PDES PerMit and Stlte Certification Changes to, or renewals of, the "PDES Pe~it or the State certification shall be reportld to the NRC within 30 days followtnl th. date the change or renewa' is approved. If I permit or certification. in part or in its entirety, is appealed and stayed. the NRC sha'l be notified within 30 days following the date the stay is granted.

3-2

The licensee shill notify the NRC of chlnges to the e1f~ctive NPCtS Penr.it proposed by the licensee by providing NRC with I copy of the proposed c~lnge It the sime time it is submitted to the permitting Igeney. The liten~ee sha'l provide the NRC I copy of the application for renewal of the NPOtS Perw,it It the slme time the .pplic.tion is submitted to the permitting Igency.

3.3 Ch.nges Required for Compliance with Other Environmental Re;u"tions Changes in pllnt design or oper.tion Ind performince of tests or Ixp.rimtnts which Ire required to achieve compliance with other Feder.l. State, .nd locil environment.l regul,tions Irt not subject to the requirements of Section 3.1.

3-3

4.0 Enyi~n~~t.l Cond1t1nns 4.1 Unusual or Importlnt Enyironme~ta' [vents Any occurrence of an unusual Dr impnrtant event that indicates or could result in significant environmental impact causally related to plant operation shell be recorded and repnrted to the NRC within 1. hours followed by a written report per Subslction 5.4.2. The following are

.xamples: Ixcessiye bird impaction events; onsite plant or Inimal dise.se outbreaks; -ertality or unusual occurrence of Iny species protectld by the

[ndangere~ Species Act of 1973; fish kills ~r impingement events On the intl~e sc~ens; increase in nuisance organisms or c"nditions; unlnticipefed or emerveney dischl~e of wast. water or chemiCll substlnces; and dlmage to vegetltion resulting from cooling towwr operations.

No ~utine monitorfng programs Ire requirP.d to implement this condition.

4.' EnYironmental Monitoring

- 2.] 'quatic Monitoring The certifications Ind permits required under thl Cllan Water Act provide

..chanisms for protlcting water Qu~lfty and. indirectly **quatic biot**

The NRC wi" rely on the decisions ..de by the Stlte of &torgil under the .uthority of the Cllan Wlter Act for Iny requi~nts for Iquatic

~nitoring.

4.2.2 Terrestrial Monitoring Terrestrial monitoring is not required.

4.2.3 Maintenance of Transmission Line Corridors The use of herbicides within the Vogtle Electric Generating Plant transmission line corridors (VEGP-Thalmann, VEGP-Scherer, Georgia side of VEGP-South Carolina Electric and Gas, and VEGP-Goshen) shall conform to the approved use of selected herbicides as registered by the Environmental Protection Agency and approved by the State of Georgia authorities and applied as directed on the herbicide label.

Records shall be maintained in accordance with EPA or State of Georgia requirements by the Georgia Power Company's Transmission Operating and Maintenance Department concerning herbicide use. Such records shall be made readily available to the NRC upon request. There shall be no routine reporting requirement associated with the condition.

4.2.3.1 Ebenezer Creek Any routine maintenance involving trimming of the trees within the National Natural Landmark area necessary to maintain conductor clearance shall be done by hand (Section 5.2.2, FES-OL).

4-2 Amendment No. 97 Amendment No. 75

4.2.3.2 Francis Plantation Routine maintenance involving trimming of the trees within the National Register of Historic Places property necessary to maintain conductor clearance shall be done by hand (Memorandum of Agreement between Advisory Council on Historic Preservation (ACHP), u.s. Nuclear Regulatory Commission (NRC), State Historic Preservation Officer (SHPO) for Georgia Power Company).

4.2.3.3 Cultural Properties Along Transmission Line Corridors Routine maintenance activities in these area will be in accordance with the Final Cultural Resource Management Plan.

4.2.4 Noise Monitoring Complaints received by Georgia Power Company or Southern Nuclear regarding noise along the high voltage transmission lines (VEGP-Goshen, VEGP-Scherer, VEGP-Thalman, and Georgia side of VEGP-SCEG) and a report of the actions taken in response to any complaints shall be submitted to the NRC in the annual report (FES-OL Section 5.12.2).

4-3 Amendment No. 97 Amendment No. 75

5.0 Administrative Procedur~s' 5.1 Review .nd Audit The licer-s.e shall provide for review .nd .udit of complf.nce with the EPP.

The audits sha" be conducted independently of the individual or groups resp~"sihle ~or performinp the specific activity.

description of the org.nization structure utflized to achieve the i"~tPlndlnt revlew and au~~t function and results of the audit Ictivities shill be ~intained and ~d" Ivailable for inspection.

5.2 Rlcords Retention Records and logs relitivi to the environmental ISPlcts of station op?ration shal' be ~de Ind retlined in I ~nner conv.rient for review and inspectioM.

These records and logs sha'l be ~dl Ivailable to Np.e on requlst.

Rlcords of ~d1ffc.tfons to station structures, systeMS and component*.

determined to potenti.lly affect the continued protection of the environ ment sh.ll bt retafntd for the 1ifl Of the stltion. All other records, deta Ind '~gs rellting to thfs fPP sh,'l be retlined for ffve Ylars or, whlre IPpltcab1 __ , in Iccordanct ~th the requtrP.Mtnts of other agenct,s.

5-1

5.3 Changes in Environmental Protection Pl.n R'Qu,sts ror ch.nges in th, EPP shall include In IsseSSMent Dr the erY.ronme~ta' 1mp.~t nf the Propos,d ching, Ind a supporting justification.

]~pleme"tltion of such chlnges in the EPP shall not commtnce prior to N~C Ipprova' Dr the proposed chlnges in the f~rM of I lfcense lmen~ent incorporating the Ippropr1~te ~vision to the EPP.

5.4 Pllnt Reporting Requirements 5.4.1 Rout1n, Reports An Annual Environmental Operlting ~e~ort describing 1mp'eme~tat1on of this EPP for the previous yelr shl" be submitted to the NRC prior to May 1 o~

.Ich yelr. The period Dr the first report shl" begin with the dlte Of 1ssuanc. of the Operlting License for Unit 1, and the initfll report sha" be submitted prior to Mly 1 of the yair fo"ow1ng issulnce of the Operating License for Unit 1.

The ~port shl" includl summaries and Inllvses of the results of the

.nvironment.l prot.ction activities required by SubSlct10n 4.? (if Iny) of this EPP for the ~port period. including I comparison with rellted preop,ra tion.' studies *. operltionll controls CIS appropriate), and previous no~r.diologicl' .nv1ro~ntll -anitor1n9 reports, Ind. In aSseSsMe~t of the observed implcts of the ,lint operation on the tnvironment. If hlrmful 5*2

e~fects or evidence of trends toward irreversible damage to the environm!n~

Ire observed, the licensee shl" provide I detli'ed Inl'ys1s of the data and I proposed course of ~itigating Iction.

The Annua' [~yironmental Operating Report shall Ilso include:

(1' A list of EPP nDncomplilnces Ind the cnrrectiye Ictions taken to

..""edy them.

(2) A list of 11' chlnges in stltion design or operltion, tests, .nd elperiments ..de in Iccord,nce with Subsection 3.1 which invDlved I potentillly significlnt unreYiewed enYironmental question.

(3) A list of nonrcutin, ~~orts submitt,d 1n Iccordlnce with Subsectior 5.'.2.

In the eyent th.t lame results Ire not IY.11lble by the report due date, the

~eport shill be submitted noting Ind expllining the m1ssing results. The missing results shl" be submitted IS loon IS poss1ble 1n I suppl~,nt.ry report.

5.'.? Nonrout1ne Reports A written ~.port shl" be submitted to the Np.r within 30 dlYs of occurr,nce of I nonroutine eYent. The report shill: CI) describe, Inllyze, Ind evalu~te 5*3

the event, includinS extent Ind magnitude of the impact, Ind plant o~er.t1ng characteristics; (b) deser1b. the ~roblbl. CIUS. nf the tvent; (c) indicate the Iction tlken to correct the reported tvent; Cd) 1nd1clte the corrective

.ction taken to preclude repetition of the event Ind to prevent si~ilar occurrences involving si~illr components or systems; Ind fe' indicate the

.gencies notified .nd their preliminary responses.

Events reportable under this subsection which Ilso require rl~orts to other Federll, State or 'O~I' 'genc1es shill be repnrted in .ccordlnce with those reporting requirements in lieu o~ the requirements of this subsection. The NRC shall be provided with. copy of such report It the sime ti~ it is su~itted t~ the other Iveney.

APPENDIX C ANTITRUST CONDITIONS

Appendix C Antitrust Conditions The following antitrust conditions are hereby incorporated in Facility Operating license NPF-68:

(1) As used herein:

(a) *Entity* means any financially responsible person, private or public corporation, municipality, county, cooperative, association, joint stock association or business trust, owning, operating or proposing to own or operate equipment or facilities within the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) for the generation, transmission or distribution of electricity, provided that, except for municipalities, counties, or rural electric cooperatives, "entity* is restricted to those which are or will be public utilities under the laws of the State of Georgia or under the laws of the United States, and are or will be providing retail electric service under a contract or rate schedule on file with and subject to the regulation of the Public Service Co..ission of the State of Georgia or any regulatory agency of the United States, and provided further, that as to municipalities, counties or rural electric cooperatives, *entity" is restricted to those which provide electricity to the pUblic at retail within the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) or to responsible and legally qualified organizations of such municipalities, counties and/or cooperatives in the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) to the extent they may bind their members.

(b) *Power Company* means Georgia Power Company, any successor, assignee of this license, or assignee of all or substantially all of Georgia Power Company's assets, and any affiliate or subsidiary of Georgia Power Company to the extent it engages in the ownership of any bulk power supply generation or transmission resource in the State of Georgia (but specifically not including (1) flood rights and other land rights acquired in the State of Georgia incidental to hydro electric generation facilities located in another state and (2) facilities located west of the thread of the stream on that part of the Chattahoochee River serving as the boundary between the States of Georgia and Alabama).

(2) Power Company recognizes that it is often in the public interest for those engaging in bulk power supply and purchases to interconnect, coordinate for reliability and economy, and engage in bulk power supply transactions in order to increase interconnected system reliability and reduce the costs of electric power. Such arrangements must provide for Power Company's costs (including a reasonable return) in connection therewith and allow other participating entities full access to the benefits available from interconnected bulk power supply operations and must provide net benefits to Power Company. In entering into such arrangements neither Power Company nor any other participant should be Amendm~nt No. 97

- 2 required to violate the principles of sound engineering practice or forego a reasonably contemporaneous alternative arrangement with another, developed in good faith in arms length negotiations (but not including arrangements between Power Company and its affiliates or subsidiaries which impair such arrangements made in good faith between Power Company and a non-affiliate or non-subsidiary) which affords it greater benefits. Any such arrangement must provide for adequate notice and joint planning procedures consistent with sound engineering practice, and must relieve Power Company from obligations undertaken by it in the event such procedures are not followed by any participating entity.

Power Company recognizes that each entity may acquire some or all of its bulk power supply from sources other than applicant.

In the implementation of the obligations stated in the succeeding paragraphs, Power Company and entities shall act in accordance with the foregoing principles, and these principles are conditions to each of Power Company's obligations herein undertaken.

(3) Power Company shall interconnect with any entity which provides, or which has undertaken firm contractual obligations to provide, some or all of its bulk power supply from sources other than Power Company on tenls to be included in an interconnection agreement which shall provide for appropriate allocation of the costs of interconnection facilities; provided, however, that if an entity undertakes to negotiate such a firm contractual obligation, the Power Company shall, in good faith, negotiate with such entity concerning any proposed interconnection.

Such interconnection agreement shall provide, without undue preference or discrimination, for the following, among other things, insofar as consistent with the operating necessities of Power Company's and any participating entity's systems:

(a) maintenance and coordination of reserves, including, where appropriate, the purchase and sale thereof, (b) emergency support, (c) maintenance support, (d) economy energy exchanges, (e) purchase and sale of firm and non-firm capacity and energy, (f) economic dispatch of power resources within the State of Georgia, provided, however, that in no event shall such arrangements impose a higher percentage of reserve requirements on the participating entity than that maintained by Power Company for similar resources.

(4) Power Company shall sell full requirements power to any entity. Power Company shall sell partial requirements power to any entity. Such sales

- 3 shall be made pursuant to rates on file with the Federal Power Commission, or any successor regulatory agency, and subject to reasonable terms and conditions.

(5) (a) Power Company shall transmit ("transmission service") bulk power over its system to any entity or entities with which it is interconnected, pursuant to rate schedules on file with the Federal Power Commission which will fully compensate Power Company for the use of its system, to the extent that such arrangements can be acc~dated from a functional engineering standpoint and to the extent that Power Company has surplus line capacity or reasonably available funds to finance new construction for this purpose. To the extent the entity or entities are able, they shall reciprocally provide transmission service to Power Company. Transmission service will be provided under this subparagraph for the delivery of power to an entity for its or its member's consumption and retail distribution or for casual resale to another entity for (1) its consu.ption or (2) its retail distribution. Nothing contained herein shall require the Power Company to transmit bulk power so as to have the effect of making the Tennessee Valley Authority ("TVA")

or its distributors, directly or indirectly, a source of power supply outside the are determined by the TVA Board of Directors by resolution of Hay 16, 1966 to be the area for which the TVA or its distributors were the primary source of power supply on July 1, 1957, the date specified in the Revenue Bond Act of 1959, 16 USC 831 n-4.

(b) Power Company shall transmit over its system from any entity or entities with which it is interconnected, pursuant to rate schedules on file with the Federal Power Commission which will fully compensate Power Company for the use of its system, bulk power which results from any such entity having excess capacity available from self-owned generating resources in the State of Georgia, to the extent such excess necessarily results from economic unit sizing or from failure to forecast load accurately or from such generating resources becoming operational earlier than the planned in-service date, to the extent that such arrangements can be accommodated from a functional engineering standpoint, and to the extent Power Company has surplus line capacity available.

(6) Upon request, Power Company shall prOVide service to any entity purchasing partial requirements service, full requirements service or transmission service from Power Company at a delivery voltage appropriate for loads served by such entity, commensurate with Power Company's available transmission facilities. Sales of such service shall be made pursuant to rates on file with the Federal Power Commission or any successor regulatory agency, and subject to reasonable terms and conditions.

(7) Upon reasonable notice Power Company shall grant any entity the opportunity to purchase an appropriate share in the ownership of, or, at the option of the entity, to purchase an appropriate share of unit power Amendment No. 97

- 4 from, each of the following nuclear generating units at Power Company's costs, to the extent the same are constructed and operated: Hatch Z, Yogtle 1, Yogtle Z, and any other nuclear generating unit constructed by Power Company in the State of Georgia which, in the application filed with the USAEC or its successor agency, is scheduled for commercial operation prior to January 1, 1989.

An entity's request for a share must have regard for the economic size of such nuclear unit(s), for the entity's load size, growth and characteristics, and for demands upon Power Company's system from other entities and Power Company's retail customers, all in accordance with sound engineering practice. Executory agreements to accomplish the foregoing shall contain provisions reasonably specified by Power Company requiring the entity to consummate and pay for such purchase by an early date or dates certain. For purposes of this provision, "unit power" shall mean capacity and associated energy from a specified generating unit.

(8) Southern Nuclear shall not market or broker power or energy from Vogtle Electric Generating Plant, Unit 1. Georgia Power Company shall continue to be responsible for compliance with the obligations imposed on it by the antitrust conditions contained in this Appendix C of the license.

Georgia Power Ca-pany is responsible and accountable for the actions of Southern Nuclear, to the extent that Southern Nuclear's actions may, in any way, contravene the antitrust conditions of this Appendix C.

(9) To effect the foregoing conditions, the following steps shall be taken:

(a) Power Company shall file with the appropriate regulatory authorities and thereafter maintain in force as needed an appropriate transmission tariff available to any entity; (b) Power Company shall file with the appropriate regulatory authorities and thereafter maintain in force as needed an appropriate partial requirements tariff available to any entity; Power Company shall have its liability limited to the partial requirements service actually contracted for and the entity shall be made responsible for the security of the bulk power supply resources acquired by the entity from sources other than the Power Company; (c) Power Company shall amend the general terms and conditions of its current Federal Power Commission tariff and thereafter maintain in force as needed provisions to enable any entity to receive bulk power at transmission voltage at appropriate rates; (d) Power Company shall not have the unilateral right to defeat the intended access by each entity to alternative sources of bulk power supply provided by the conditions to this license; but Power Company shall retain the right to seek regulatory approval of changes in its tariffs to the end that it be adequately compensated for services it provides, specifically including, but not limited to, the provisions of Section ZOS of the Federal Power Act; Amendment ~o. 97

- 5 (e) Power Company shall use its best efforts to amend any outstanding contract to which it is a party that contains provisions which are inconsistent with the conditions of this license; (f) Power Company affirms that no consents are or will become necessary fro. Power Company's parent, affiliates or subsidiaries to enable Power Company to carry out its obligations hereunder or to enable the entities to enjoy their rights hereunder; (g) All provisions of these conditions shall be subject to and implemented in accordance with the laws of the United States and of the State of Georgia, as applicable, and with rules, regulations and orders of agencies of both, as applicable.

Amerdment No. 37

APPENDIX D ADDITIQNAL CONDITIONS FACILITY QPERATING LICENSE NO. NPF-68 Amendment Implementation Nymber Additional Condition Date 100 The licensee shall implement a procedure that Prior to will prohibit entry into an extended Emergency Diesel implementation of Generator Allowed Outage Time (14 days), for Amendment scheduled maintenance purposes, if severe weather No. 100 conditions are expected, as described in the licensee's application dated January 22, 1998, as supplemented by letter dated March 18, 1998, and evaluated in the staffs Safety Evaluation dated May 20, 1998.

102 The spent fuel pool heat loads will be managed by Before administrative controls. These controls will be transferring irradiated placed in applicable procedures as described in fuel into the Unit 1 the licensee's letters dated September 4, 1997, spent fuel pool May 19 and June 12, 1998, and evaluated in the staffs Safety Evaluation dated June 29, 1998.

102 The UFSAR will be updated to include the heat To be included in load that will ensure the temperature limit of 170°F will the next appropriate not be exceeded, as well as the requirement to perform UFSAR update a heat load evaluation before transferring irradiated fuel following the to either pool. as described in the licensee's letters dated installation of the September 4. 1997, May 19 and June 12, 1998, and Unit 1 spent fuel evaluated in the staff's Safety Evaluation dated racks June 29. 1998.

102 A temporary gantry crane, with a hoist rated for 20 tons, Before commencing will be erected on the existing fuel handling bridge rails reracking operations to move the racks within the spent fuel pool area, as described in the licensee's letters dated September 4, 1997, May 19 and June 12. 1998, and evaluated in the staffs Safety Evaluation dated June 29, 1998.

Amendment No. 102

Amendment Additional Condition Implementation Number Date 102 The licensee will implement all applicable crane, load path and Before and height, rigging and load testing guidelines of NUREG-0612 and during reracking ANSI Standard B30.2, as described in the licensee's letters dated operations, as September 4,1997, May 19 and June 12,1998, and evaluated in appropriate.

the staff's Safety Evaluation dated June 29, 1998.

154 Upon implementation of the Amendment adopting TSTF-448, As stated in the Revision 3, the determination of CRE unfiltered air inleakage as Additional required by SR 3.7.10.5, in accordance with TS 5.5.20.c.(i), and Condition the measurement of CFE pressure as required by Specification 5.5.20.d. shall be considered met. Following implementation:

(a) The first performance of SR 3.7.10.5, in accordance with Specification 5.5.20.c.(i), shall be within the specified frequency of 6 years, plus the 18-month allowance of S R 3.0.2, as measured from March 23, 2004, the date of the most recent successful tracer gas test, as stated in the June 16, 2004 letter response to Generic Letter 2003-01 , or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.

(b) The first performance of the periodic assessment of CRE habitability, specification 5.5.20.c.(ii), shall be within 3 years, plus the 9-month allowance of SR 3.0.2, as measured from March 23, 2004, the date of the most recent successful tracer gas test, as stated in the June 16, 2004 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.

The first performance of the periodic measurement of CRE pressure, specification 5.5.20.d, shall be within 18 months, plus the 138 days allowance of SR 3.0.2, as measured from March 23. 2004, the date of the most recent successful pressure measurement test, or within 138 days if not performed previously.

Vogtle Unit 1 Amendment No. 154

SOUTHERN NUCLEAR OPERATING COMPANY, INC.

GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON, GEORGIA DOCKET NO. 50-425 VOGTLE ELECTRIC GENERATING PLANT, UNIT 2 RENEWED FACILITY OPERATING LICENSE Renewed License No. NPF-81

1. The Nuclear Regulatory Commission (the Commission or the NRC) has found that:

A. The application for renewal of the license filed by the Southern Nuclear Operating Company, Inc. acting for itself, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia (the Owners), complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I; and all required notifications to other agencies or bodies have been duly made; B. Construction of the Vogtle Electric Generating Plant, Unit 2 (the facility) has been substantially completed in conformity with Construction Permit No. CPPR-109 and the application, as amended, the provisions of the of the Act and the regulations of the Commission; C. Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the period of extended operation on the functionality of structures and components that have been identified to require review under 10 CFR 54.21 (a)(1); and (2) time-limited aging analyses that have been identified to require review under 10 CFR 54.21(c), such that there is reasonable assurance that the activities authorized by the renewed operating license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for the facility, and that any changes made to the facility's current licensing basis in order to comply with 10 CFR 54.29(a) are in accordance with the Act and the Commission's regulations; D. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.0 below);

E. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I (except as exempted from compliance in Section 2.0. below);

Renewed Operating License NPF-81

-2 F. Southern Nuclear Operating Company, Inc: (herein called Southern Nuclear) is technically qualified and, together, Southern Nuclear and the Owners are financially qualified to engage in the activities authorized by this license in accordance with the Commission's regulations set forth in 10 CFR Chapter I; G. The Owners have satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; H. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; I. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of this Renewed Facility Operating License No. NPF-81, subject to the conditions for protection of the environment set forth in the Environmental Protection Plan attached as Appendix B, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; J. The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70.

2. Based on the foregoing findings and the Partial Initial Decision and the Concluding Partial Initial Decision issued by the Atomic Safety and Licensing Board on August 27 and December 23, 1986, respectively, regarding this facility and satisfaction of conditions therein imposed, and pursuant to approval by the Nuclear Regulatory Commission at a meeting held on March 30, 1989, Facility Operating License No. NPF-79, issued on February 9, 1989 is superseded by Facility Operating License No. NPF-81, hereby issued to the Southern Nuclear, Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia to read as follows:

A. This license applies to the Vogtle Electric Generating Plant, Unit 2, a pressurized water reactor and associated equipment (the facility) owned by GPC, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, and operated by Southern Nuclear. The facility is located in Burke County, Georgia, on the west bank of the Savannah River approximately 25 miles south of Augusta, Georgia, and is described in the Final Safety Analysis Report, as supplemented and amended, and in the Environmental Report, as supplemented and amended; B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Southern Nuclear, pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, manage, use, maintain, and operate the facility at the designated location in Burke County, Georgia, in accordance with the procedures and limitations set forth in this license;

Southern Nuclear succeeds Georgia Power Company as the operator of Vogtle Electric Generating Plant, Unit 2. Southern Nuclear is authorized by the Owners to exercise exclusive responsibility and control over the physical construction, operation, and maintenance of the facility.

Renewed Operating License NPF-81

-3 (2) Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, pursuant to the Act and 10 CFR Part 50, to possess but not operate the facility at the designated location in Burke County, Georgia, in accordance with the procedures and limitations set forth in this license; (3) Southern Nuclear, pursuant to the Act and 10 CFR Part 70, to receive, possess, and use at any time special nuclear material as reactor fuel, in accordance with the limitations for storage and amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30, 40, and 70 to receive, possess, and use at any time any byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required; (5) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30, 40, and 70, to receive, possess, and use in amounts as required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; (6) Southern Nuclear, pursuant to the Act and 10 CFR Parts 30,40, and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility authorized herein.

C. This license shall be deemed to contain and Is subject to the conditions specified in the Commission's regulations set forth in 10 CFR Chapter I and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect, and is subject to the additional conditions specified or incorporated below.

(1) Maximum Power Level Southern Nuclear is authorized to operate the facility at reactor core power levels not in excess of 3625.6 megawatts thermal (100 percent power) in accordance with the conditions specified herein.

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No.136, and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, are hereby incorporated into this license. Southern Nuclear shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

The Surveillance Requirements (SRs) contained in the Appendix A Technical Specifications and listed below are not required to be performed immediately upon implementation of Amendment No. 74. The SRs listed below shall be Renewed Operating License NPF-81

-4 successfully demonstrated prior to the time and condition specified below for each; a) DELETED b) DELETED c) SR 3.8.1.20 shall be successfully demonstrated at the first regularly scheduled performance after implementation of this license amendment.

(3) Southern Nuclear Operating Company shall be capable of establishing containment hydrogen monitoring within 90 minutes of initiating safety injection following a loss of coolant aCcident.

(4) Mitigation Strategy License Condition The licensee shall develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance

2. Assessment of mutual aid fire fighting assets

3. Designated staging areas for equipment and materials

4. Command and control

5. Training of response personnel (b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (5) Additional Conditions The Additional Conditions contained in Appendix 0, as revised through Amendment No. 135, are hereby incorporated into this license. Southern Nuclear shall operate the facility in accordance with the Additional Conditions.

D. The facility requires exemptions from certain requirements of 10 CFR Part 50 and 10 CFR Part 70. These include (a) an exemption from the requirements of 10 CFR 70.24 for two criticality monitors around the fuel storage area, and (b) an exemption from the requirements of Paragraph III.D.2(b)(ii) of Appendix J of 10 CFR 50, the testing of containment air locks at times when containment integrity is not required. The special circumstances regarding exemption b are identified in Section 6.2.6 of SSER 8.

Renewed Operating License NPF-81

-5 An exemption was previously granted pursuant to 10 CFR 70.24. The exemption was granted with NRC materials license No. SNM-1981, issued July 13, 1988, and relieved GPC from the requirement of having a criticality alarm system. GPC and Southern Nuclear are hereby exempted from the criticality alarm system provision of 10 CFR 70.24 so far as this section applies to the storage of fuel assemblies held under this license.

These exemptions are authorized by law, will not present an undue risk to the public health and safety, and are consistent with the common defense and security.

The exemption in item b above is granted pursuant to 10 CFR 50.12. With these exemptions, the facility will operate, to the extent authorized herein, in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission.

E. Southern Nuclear shall fully implement and maintain in effect all provisions of the Commission-approved physical security, training and qualification, and safeguards contingency plans including amendments made pursuant to provisions of the Miscellaneous Amendments and Search Requirements revisions to 10 CFR 73.55 (51 FR 27817 and 27822) and to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The plan, which contains Safeguards Information protected under 10 CFR 73.21, is entitled: "Southern Nuclear Operating Company Security Plan, Training and Qualification Plan, and Safeguards Contingency Plan," with revisions submitted through May 15, 2006.

F. GPC shall comply with the antitrust conditions delineated in Appendix C to this license.

G. Southern Nuclear shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility, as approved in the SER (NUREG-1137) through Supplement 9 subject to the following provision:

Southern Nuclear may make changes to the approved fire protection program without prior approval of the Commission, only if those changes would not adversely affect the ability to achieve and maintain safe shutdown in the event of a fire.

H. Deleted.

I. The Owners shall have and maintain financial protection of such type and in such amounts as the Commission shall require in accordance with Section 170 of the Atomic Energy Act of 1954, as amended, to cover public liability claims.

J. The Updated Safety Analysis Report supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), shall be included in the next scheduled update to the Updated Safety Analysis Report required by 10 CFR 50.71(e)(4) following the issuance of this renewed operating license. Until that update is complete, Southern Nuclear may make changes to the programs and activities described in the supplement without prior Commission approval, provided that Southern Nuclear evaluates such changes pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

Renewed Operating License NPF-81

-6 K. The Updated Safety Analysis Report supplement, as revised, submitted pursuant to 10 CFR 54.21 (d), describes certain future activities to be completed prior to the period of extended operation. Southern Nuclear shall complete these activities no later than February 9, 2029, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.

L. All capsules in the reactor vessel that are removed and tested must meet the test procedures and reporting requirements of American Society for Testing and Materials (ASTM) E 185-82 to the extent practicable for the configuration of the specimens in the capsule. Any changes to the capsule withdrawal schedule, including spare capsules, must be approved by the NRC prior to implementation.

All capsules placed in storage must be maintained for future insertion. Any changes to storage requirements must be approved by the NRC, as required by 10 CFR Part 50, Appendix H.

M. This license is effective as of the date of issuance and shall expire at midnight on February 9, 2049.

FOR THE NUCLEAR REGULATORY COMMISSION

~~~

Office of Nuclear Reactor Regulation

Enclosures:

1. Appendix A - Technical Specifications

2. Appendix B - Environmental Protection Plan

3. Appendix C - Antitrust Conditions

4. Appendix D - Additional Conditions Date of Issuance: June 3, 2009 Renewed Operating License NPF-81

- Deleted Vogtle Unit 2 uses the same Attachment 1 as Vogtle Unit 1. Please refer to Vogtle Unit 1 for (ML090920421)

Appendix A - Technical Specifications Vogtle Unit 2 uses the same Appendix A as Vogtle Unit 1. Please refer to Vogtle Unit 1 for Appendix A (ML090920421)

Appendix B - Environmental Protection Plan Vogtle Unit 2 uses the same Appendix B as Vogtle Unit 1. Please refer to Vogtle Unit 1 for Appendix B (ML090920421)

APPENDIX C ANTITRUST CONDITIONS

Appendix C Antitrust Conditions The following antitrust conditions are hereby incorporated in Facility Operating License NPF-81:

(1) As used herein:

(a) "Entity" means any financially responsible person, private or public corporation, municipality, county, cooperative, association, joint stock association or business trust, owning, operating or proposing to own or operate equipment or facilities within the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) for the generation, transmission or distribution of electricity, provided that, except for municipalities, counties, or rural electric cooperatives, "entity" is restricted to those which are or will be public utilities under the laws of the State of Georgia or under the laws of the United States, and are or will be providing retail electric service under a contract or rate schedule on file with and subject to the regulation of the Public Service Commission of the State of Georgia or any regulatory agency of the United States, and provided further, that as to municipalities, counties or rural electric cooperatives, "entity" is restricted to those which provide electricity to the public at retail within the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) or to responsible and legally qualified organizations of such municipalities, counties and/or cooperatives in the State of Georgia (other than Chatham, Effingham, Fannin, Towns and Union Counties) to the extent they may bind their members.

(b) "Power Company" means Georgia Power Company, any successor, assignee of this license, or assignee of all or substantially all of Georgia Power Company's assets, and any affiliate or subsidiary of Georgia Power Company to the extent it engages in the ownership of any bulk power supply generation or transmission resource in the State of Georgia (but specifically not including (1) flood rights and other land rights acquired in the State of Georgia incidental to hydro electric generation facilities located in another state and (2) facilities located west of the thread of the stream on that part of the Chattahoochee River serving as the boundary between the States of Georgia and Alabama).

(2) Power Company recognizes that it is often in the public interest for those engaging in bulk power supply and purchases to interconnect, coordinate for reliability and economy, and engage in bulk power supply transactions in order to increase interconnected system reliability and reduce the costs of electric power. Such arrangements must provide for Power Company costs (including a reasonable return) in connection therewith and allow other participating entities full access to the benefits available from interconnected bulk power supply operations and must provide net benefits to Power Company. In entering into such arrangements neither Power Company nor any other participant should be Amendment No. 75

- 2 required to violate the principles of sound engineering practice or forego a reasonably contemporaneous alternative arrangement with another, developed in good faith in arms length negotiations (but not including arrangements between Power Company and its affiliates or subsidiaries which impair entities' rights hereunder more than they would be impaired were such arrangements made in good faith between Power Company and a non-affiliate or non-subsidiary) which affords it greater benefits. Any such arrangement must provide for adequate notice and joint planning procedures consistent with sound engineering practice, and must relieve Power Company from obligations undertaken by it in the event such procedures are not followed by any participating entity.

Power Company recognizes that each entity may acquire some or all of its bulk power supply from sources other than applicant.

In the implementation of the obligations stated in the succeeding paragraphs, Power Company and entities shall act in accordance with the foregoing principles, and these principles are conditions to each of Power Company's obligations herein undertaken.

(3) Power Company shall interconnect with any entity which provides, or which has undertaken firm contractual obligations to provide, some or all of its bulk power supply from sources other than Power Company on terms to be included in an interconnection agreement which shall provide for appropriate allocation of the costs of interconnection facilities; provided, however, that if an entity undertakes to negotiate such a firm contractual obligation, the Power Company shall, in good faith, negotiate with such entity concerning any proposed interconnection.

Such interconnection agreement shall provide, without undue preference or discrimination, for the following, among other things, insofar as consistent with the operating necessities of Power Company's and any participating entity's systems:

(a) maintenance and coordination of reserves, including, where appropriate, the purchase and sale thereof, (b) emergency support, (c) maintenance support, (d) economy energy exchanges, (e) purchase and sale of firm and non-firm capacity and energy, (f) economic dispatch of power resources within the State of Georgia, provided, however, that in no event shall such arrangements impose a higher percentage of reserve requirements on the participating entity than that maintained by Power Company for similar resources.

- 3 (4) Power Company shall sell full requirements power to any entity. Power Company shall sell partial requirements power to any entity. Such sales shall be made pursuant to rates on file with the Federal Power Commission, or any successor regulatory agency, and subject to reasonable terms and conditions.

(5) (a) Power Company shall transmit (-transmission service") bulk power over its system to any entity or entities with which it is interconnected, pursuant to rate schedules on file with the Federal Power Commission which will fully compensate Power Company for the use of its system, to the extent that such arrangements can be accommodated from a functional engineering standpoint and to the extent that Power Company has surplus line capacity or reasonably available funds to finance new construction for this purpose. To the extent the entity or entities are able, they shall reciprocally provide transmission service to Power Company. Transmission service will be provided under this subparagraph for the delivery of power to an entity for its or its member's consumption and retail distribution or for casual resale to another entity for (1) its consumption or (2) its retail distribution. Nothing contained herein shall require the Power Company to transmit bulk power so as to have the effect of making the Tennessee Valley Authority ("TVA")

or its distributors, directly or indirectly, a source of power supply outside the are determined by the TVA Board of Directors by resolution of Hay 16, 1966 to be the area for which the TVA or its distributors were the primary source of power supply on July 1, 1957, the date specified in the Revenue Bond Act of 1959, 16 USC 831 n-4.

(b) Power Company shall transmit over its system from any entity or entities with which it is interconnected, pursuant to rate schedules on file with the Federal Power Commission which will fully compensate Power Company for the use of its system, bulk power which results from any such entity having excess capacity available from self-owned generating resources in the State of Georgia, to the extent such excess necessarily results from economic unit sizing or from failure to forecast load accurately or from such generating resources becoming operational earlier than the planned in-service date, to the extent that such arrangements can be accommodated from a functional engineering standpoint, and to the extent Power Company has surplus line capacity available.

(6) Upon request, Power Company shall provide service to any entity purchasing partial requirements service, full requirements service or transmission service from Power Company at a delivery voltage appropriate for loads served by such entity, commensurate with Power Company's available transmission facilities. Sales of such service shall be made pursuant to rates on file with the Federal Power Commission or any successor regulatory agency, and subject to reasonable terms and conditions.

Amendment No. 75

- 4 (7) Upon reasonable notice Power Company shall grant any entity the opportunity to purchase an appropriate share in the ownership of, or, at the option of the entity, to purchase an appropriate share of unit power from, each of the following nuclear generating units at Power Company's costs, to the extent the same are constructed and operated: Hatch 2, Vogtle 1, Vogtle 2, and any other nuclear generating unit constructed by Power Company in the State of Georgia which, in the application filed with the USAEC or its successor agency, is scheduled for commercial operation prior to January 1, 1989.

An entity's request for a share must have regard for the economic size of such nuclear unit(s), for the entity's load size, growth and characteristics, and for demands upon Power Company's system from other entities and Power Company's retail customers, all in accordance with sound engineering practice. Executory agreements to accomplish the foregoing shall contain provisions reasonably specified by Power Company requiring the entity to consummate and pay for such purchase by an early date or dates certain. For purposes of this provision, "unit power" shall mean capacity and associated energy from a specified generating unit.

(8) Southern Nuclear shall not market or broker power or energy from Vogtle Electric Generating Plant, Unit 2. Georgia Power Company shall continue to be responsible for compliance with the obligations imposed on it by the antitrust conditions contained in this Appendix C of the license.

Georgia Power Company is responsible and accountable for the actions of Southern Nuclear, to the extent that Southern Nuclear's actions may, in any way, contravene the antitrust conditions of this Appendix C.

(9) To effect the foregoing conditions, the following steps shall be taken:

(a) Power Company shall file with the appropriate regulatory authorities and thereafter maintain in force as needed an appropriate transmission tariff available to any entity; (b) Power Company shall file with the appropriate regulatory authorities and thereafter maintain in force as needed an appropriate partial requirements tariff available to any entity; Power Company shall have its liability limited to the partial requirements service actually contracted for and the entity shall be made responsible for the security of the bulk power supply resources acquired by the entity from sources other than the Power Company; (c) Power Company shall amend the general terms and conditions of its current Federal Power Commission tariff and thereafter maintain in force as needed provisions to enable any entity to receive bulk power at transmission voltage at appropriate rates; (d) Power Company shall not have the unilateral right to defeat the intended access by each entity to alternative sources of bulk power supply provided by the conditions to this license; but Power Company shall retain the right to seek regulatory approval of changes in its Amendment No. 75

- 5 tariffs to the end that it be adequately compensated for services it provides, specifically including, but not limited to, the provisions of Section 205 of the Federal Power Act; (e) Power Company shall use its best efforts to amend any outstanding contract to which it is a party that contains provisions which are inconsistent with the conditions of this license; (f) Power Company affirms that no consents are or will become necessary from Power Company's parent, affiliates or subsidiaries to enable Power Company to carry out its obligations hereunder or to enable the entities to enjoy their rights hereunder; (g) All provisions of these conditions shall be subject to and implemented in accordance with the laws of the United States and of the State of Georgia, as applicable, and with rules, regulations and orders of agencies of both, as applicable.

Ampnrlmpnt Nn. 7~

APPENDIX D ADDITIONAL CONDITIONS FACILITY OPERATING LICENSE NO. NPF-81 Amendment Additional Condition Implementation Number Date 78 The licensee shall implement a procedure that will prohibit entry Prior to into an extended Emergency Diesel Generator Allowed Outage implementation of time (14 days), for scheduled maintenance purposes, if severe Amendment No. 78.

weather conditions are expected, as described in the licensee's application dated January 22, 1998, as supplemented by letter dated March 18, 1998, and evaluated in the staff's Safety Evaluation dated May 20, 1998.

80 The UFSAR will be updated to include the heat load that will To be included in ensure the temperature limit of 170 F will not be exceeded, as the next appropriate well as the requirement to perform a heat load evaluation before UFSAR update transferring irradiated fuel to either pool, as described in the following the licensee's letters dated September 4, 1997, May 19 and June 12. installation of the 1998. and evaluated in the staff's Safety Evaluation dated June Unit 1 spent fuel 29, 1998. racks.

135 Upon implementation of the Amendment adopting TSTF-448, As stated in the Revision 3, the determination of CRE unfiltered air inleakage as Additional Condition required by SR 3.7.10.5, in accordance with TS 5.5.20.c.(i), and the measurement of CFE pressure as required by Specification 5.5.20.d, shall be considered met. Following implementation:

(a) The first performance of SR 3.7.10.5, in accordance with Specification 5.5.20.c.(i), shall be within the specified frequency of 6 years, plus the 18-month allowance of SR 3.0.2, as measured from March 23, 2004, the date of the most recent successful tracer gas test, as stated in the June 16, 2004 letter response to Generic Letter 2003-01, or within the next 18 months if the time period since the most recent successful tracer gas test is greater than 6 years.

(b) The first performance of the periodic assessment of CRE habitability, specification 5.5.20.c.(ii), shall be within 3 years. plus the 9-month allowance of SR 3.0.2, as measured from March 23, 2004, the date of the most recent successful tracer gas test, as stated in the June 16, 2004 letter response to Generic Letter 2003-01, or within the next 9 months if the time period since the most recent successful tracer gas test is greater than 3 years.

The first performance of the periodic measurement of CRE pressure, specification 5.5.20.d, shall be within 18 months, plus the 138 days allowance of SR 3.0.2, as measured from March 23, 2004, the date of the most recent successful L pressure measurement test. or within 138 days if not performed previously.

Vogtle Unit 2 Amendment No. 135

7590-01-P UNITED STATES NUCLEAR REGULATORY COMMISSION SOUTHERN NUCLEAR OPERATING CO, INC.

GEORGIA POWER COMPANY OGLETHORPE POWER CORPORATION MUNICIPAL ELECTRIC AUTHORITY OF GEORGIA CITY OF DALTON, GEORGIA VOGTLE ELECTRIC GENERATING PLANT, UNITS 1 AND 2 NOTICE OF ISSUANCE OF RENEWED FACILITY OPERATING LICENSE NOS.

NPF-68 AND NPF-81 FOR AN ADDITIONAL 20-YEAR PERIOD RECORD OF DECISION DOCKET NOS. 50-424 AND 50-425 Notice is hereby given that the U.S. Nuclear Regulatory Commission (NRC or the Commission) has issued Renewed Facility Operating License Nos. NPF-68 and NPF-81 to Southern Nuclear Operating Company, Inc. (licensee), Georgia Power Company, Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, co owners of the Vogtle Electric Generating Plant (VEGP), Units 1 and 2. Renewed Facility Operating License Nos. NPF-68 and NPF-81 authorize operation of VEGP by the licensee at reactor core power levels not in excess of 3,625.6 megawatts thermal for each unit, in accordance with the provisions of the VEGP renewed licenses and their technical specifications.

This notice also serves as the record of decision for the renewal of Facility Operating License Nos. NPF-68 and NPF-81 for VEGP, consistent with Title 10 of the Code of Federal Regulations (10 CFR) Section 51.103, "Record of Decision-GeneraL" As discussed in the final supplemental environmental impact statement for VEGP (NUREG-1437, "Generic

-2 Environmental Impact Statement for License Renewal of Nuclear Plants," Supplement 34, "Vogtle Electric Generating Plant, Units 1 and 2," issued December 2008), the Commission considered a range of reasonable alternatives that included power generation from coal, natural gas, oil, wind, solar, hydropower, geothermal, wood waste, municipal solid waste, and other biomass-derived fuels; delayed retirement; utility-sponsored conservation, and a combination of alternatives, including a no-action alternative. The factors considered in the record of decision appear in Supplement 34.

VEGP is a dual-unit pressurized-water reactor designed by Westinghouse Electric Corporation that is located in Wayne County, GA. The site is located approximately 25 miles south of Augusta, GA. The application for the renewed licenses complied with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations. As required by the Act and the Commission's regulations in 10 CFR Chapter I, the Commission has made appropriate findings, which the license sets forth.

Prior public notice of the action involving the proposed issuance of the renewed license and of an opportunity for a hearing regarding the proposed issuance of the renewed license was published in the Federal Register on August 21, 2007 (72 FR 46680). For further details with respect to this action, see (1) the Southern Nuclear Operating Company, Inc., Oglethorpe Power Corporation, Municipal Electric Authority of Georgia, and City of Dalton, Georgia, license renewal application for VEGP, Units 1 and 2, dated June 29, 2007, as supplemented by letters dated through February 16, 2009, (2) the Commission's safety evaluation report (NUREG-1920, "Safety Evaluation Report Related to the License Renewal of the Vogtle Electric Generating Plant, Units 1 and 2," Volumes 1 and 2, issued April 2009), (3) the licensee's updated safety analysis report, and (4) the Commission's final environmental impact statement (NUREG-1437, Supplement 34). These documents are available at the NRC Public Document Room, One White Flint North, 11555 Rockville Pike, Rockville, MD 20852, and can be viewed from the NRC Public Electronic Reading Room at http://www.nrc.gov/readinq-rm/adams.html.

-3 Copies of Renewed Facility Operating License Nos. NPF-68 and NPF-81 may be obtained by writing to the U.S. Nuclear Regulatory Commission, Washington, DC 20555-0001, Attention:

Director, Division of License Renewal. Copies of the safety evaluation report for VEGP Units 1 and 2 (NUREG-1920, Volumes 1 and 2) and the final environmental impact statement (NUREG-1437, Supplement 34) may be purchased from the National Technical Information Service, U.S. Department of Commerce, Springfield, VA 22161-0002 (http://www.ntis.gov), 703-605-6000; or from the Superintendent of Documents, U.S. Government Printing Office, PO Box 371954, Pittsburgh, PA 15250-7954 (http://www.gpoaccess.gov), 202-512-1800. All orders should clearly identify the NRC publication number and the requester's Government Printing Office deposit account number or a VISA or MasterCard number and expiration date.

Dated at Rockville, MD, this 3 rd day of June 2009.

F0tf]E N(J~YCOMMISSION D~ton, Chief Reactor Projects Branch 1 Division of License Renewal Office of Nuclear Reactor Regulation

ML090920437

concurrence via email OFFICE PM:DLRRPB1 Tech Editor* LA:DLR PM:DORL:LPL3-2 BC:DORL:LPL3-2 NAME DAshley KKribbs YEdmonds RMartin MWong DATE 05/01 /09 04/27/09 05/01 /09 05/05/09 05/05/09 OFFICE BC:RPB1 :DLR D:DLR OGG D:NRR PM:DLRRPB1 NAME DPelton BHolian NLO Uttal ELeeds DAshley DATE 05/07/09 05/08/09 OS/21 109 06/02/09 06/03/09

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Contents

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Dear Mr. Tynan:

Enclosures:

Enclosures:

Enclosures:

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