ML25120A068

Virgil C Summer Nuclear Station, Unit 1 - Subsequent Renewed License

ML25120A068
Person / Time
Site:	Summer
Issue date:	06/30/2025
From:	Gregory Bowman NRC/NRR/DNRL/NLRP
To:
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ML25120A066	List: ML25120A067 ML25120A068 ML25120A069 ML25120A070
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Download: ML25120A068 (17)

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UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, DC 20555 DOMINION ENERGY SOUTH CAROLINA, INC.

SOUTH CAROLINA PUBLIC SERVICE AUTHORITY DOCKET NO. 50-395 VIRGIL C. SUMMER NUCLEAR STATION, UNIT 1 SUBSEQUENT RENEWED FACILITY OPERATING LICENSE NO. NPF-12

1. The U.S. Nuclear Regulatory Commission (the Commission or the NRC) having previously made the findings set forth in Renewed License No. NPF-12 issued April 23, 2004, has now found that:

A. The application to subsequently renew License No. NPF-12 filed by Dominion Energy South Carolina Electric, Inc.1 (DESC) acting for itself and South Carolina Public Service Authority (the licensees) 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. Actions have been identified and have been or will be taken with respect to (1) managing the effects of aging during the subsequent 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 this subsequent renewed license will continue to be conducted in accordance with the current licensing basis, as defined in 10 CFR 54.3, for Virgil C.

Summer Nuclear Station (V.C. Summer), Unit 1, and that any changes made to the plant's current licensing basis in order to comply with 10 CFR 54.29(a) are in accord with the Act and the Commission's regulations; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the rules and regulations of the Commission; D. There is reasonable assurance: (i) that the activities authorized by this subsequent renewed 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 rules and regulations of the Commission; E. Dominion Energy South Carolina, lnc.2 is technically qualified to engage in the activities authorized by this subsequent renewed operating license in accordance with the rules and regulations of the Commission; 1 On April 29, 2019, "South Carolina Electric & Gas Company" (SCE&G) changed its name to "Dominion Energy South Carolina, Inc."

2 Dominion Energy South Carolina, Inc. is authorized to act as agent for the South Carolina Public Service Authority and has exclusive responsibility and control over the physical construction, operation and maintenance of the facility.

2 F. The licensees have satisfied the applicable provisions of 10 CFR Part 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G. The issuance of this subsequent renewed license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the Commission concludes that the issuance of Subsequent Renewed Facility Operating License NPF-12, subject to the conditions for protection of the environment set forth herein, is in accordance with 10 CFR Part 51, of the Commission's regulations and all applicable requirements have been satisfied; and I.

The receipt, possession, and use of source, byproduct and special nuclear material as authorized by this subsequent renewed license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70.

2. On the basis of the foregoing findings regarding this facility, Facility Operating License No.

NPF-12, issued April 23, 2004, is superseded by Subsequent Renewed Facility Operating License No. NPF-12, which is hereby issued to Dominion Energy South Carolina, Inc. and the South Carolina Public Service Authority (the licensees) to read as follows:

A. This subsequent renewed license applies to the Virgil C. Summer Nuclear Station, Unit 1, a pressurized water reactor and associated equipment (the facility), owned by Dominion Energy South Carolina, Inc. and South Carolina Public Service Authority. The facility is located in Fairfield County, South Carolina, and is described in the Final Safety Analysis Report, as supplemented and amended and the Environmental Report as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1)

Dominion Energy South Carolina, Inc. pursuant to Section 103 of the Act and 10 CFR Part 50, to possess, use, and operate the facility at the designated location in Fairfield County, South Carolina, in accordance with the procedures and limitations set forth in this subsequent renewed license; (2)

South Carolina Public Service Authority to possess the facility at the designated location in Fairfield County, South Carolina, in accordance with the procedures and limitations set forth in this subsequent renewed license; (3)

DESC, 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 amounts required for reactor operation, as described in the Final Safety Analysis Report, as supplemented and amended; (4)

DESC, pursuant to the Act and 10 CFR Part 30, 40 and 70 to receive, possess and use at any time byproduct, source and special nuclear material as sealed neutron sources for reactor startup, sealed neutron sources for reactor instrumentation and radiation monitoring equipment calibration, and as fission detectors in amounts as required;

3 (5)

DESC, 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 of components; and (6)

DESC, 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.

C. This subsequent renewed license shall be deemed to contain, and is subject to, the conditions specified in the Commissions 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 DESC is authorized to operate the facility at reactor core power levels not in excess of 2900 megawatts thermal in accordance with the conditions specified herein and in to this subsequent renewed license.

The preoperational tests, startup tests and other items identified in Attachment 1 to this subsequent renewed license shall be completed as specified. Attachment 1 is hereby incorporated into this subsequent renewed license.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 227, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the subsequent renewed license. Dominion Energy South Carolina, Inc.

shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3)

Conduct of Work Activities During Fuel Load and Initial Startup DESC shall review by committee all facility construction, preoperational testing, and system demonstration activities performed concurrently with facility initial fuel loading or with the facility startup test program to assure that the activity will not affect the safe performance of the facility fuel loading or the portion of the facility startup program being performed. The review shall address, as a minimum, system interaction, span of control, staffing, security, and health physics, with respect to the performance of the activity concurrently with the facility fuel loading or the portion of the facility startup program being performed. The committee for the review shall be composed of at least three members, knowledgeable in the above areas, and who meet the qualifications for professional-technical personnel specified by Section 4.4 of ANSI N18.7-1971. At least one of these three shall be a senior member of the Plant Manager's staff.

4 (4)

Initial Test Program DESC shall conduct the post-fuel-loading initial test program set forth in Chapter 14 of the Final Safety Analysis Report, as amended through No. 33, without making any major modifications to this program unless such modifications have been identified and have received prior NRC staff approval. Major modifications are defined as:

a. Elimination of any test other than those identified as non-essential in Chapter 14 of the Final Safety Analysis Report, as amended through Amendment No. 33,

b. Modifications of test objectives, methods or acceptance criteria for any test other than those identified as non-essential in Chapter 14 of the Final Safety Analysis Report, as amended through Amendment No. 33,

c. Performance of any test at a power level different from the power level indicated in the described program; and

d. Failure to complete any tests included in the described program (planned or scheduled for power levels up to the authorized power level).

For the performance of startup testing as described in Table 14.1-75 of the Final Safety Analysis Report, as amended through Amendment No. 33, compliance with items 3 and 4 of Table 3.3-1 of the Technical Specifications is not required.

(5)

Stability of the West Embankment and its Effects on the Intake Structure (Section 2.5.4, SSER 3)

DESC shall conduct the monitoring program discussed in Section 2.5.4.10.6.2 of the Final Safety Analysis Report, as amended through Amendment No. 33, to specifically include the following:

a. At the vicinity of the pumphouse and intake structure, four settlement points capable of monitoring both horizontal and vertical movements shall be established to monitor the embankment movements.

b. The submerged slope profile of the west embankment over the intake structure shall be established and monitored to detect any unusual movements that may affect the intake structure.

c. The schedule and the reporting requirements of the above inspection shall be in accordance with the recommendations stated in Regulatory Guide 1.127.

d. The condition of the intake structure shall be monitored to detect new cracks and changes to the old grouted or ungrouted cracks. Observed changes (length or width) in existing cracks and any new cracks shall be reported by DESC to the NRC staff. The maximum inspection interval for this monitoring of the intake structure is five (5) years.

e. The condition of the intake structure shall also be monitored as specified in (d.)

above following any earthquake during which the plant seismic instrumentation indicates that the operating basis earthquake has been exceeded.

5 (6)

Design Verification Program (Section 3.7.4, SSER #5)

Prior to December 31, 1982, DESC shall provide a final report to the NRC staff delineating the final resolution of the actions taken to satisfy the recommendations of the independent design verification conducted by Stone & Webster Engineering Corporation.

(7)

Thermal Sleeves (Section 3.9.3, SSER #5)

Prior to startup after the first refueling outage, DESC shall provide, for NRC staff review and approval, justification for continued operation with the thermal sleeves removed from selected nozzles in the reactor coolant system.

(8)

Environmental Qualification of Mechanical and Electrical Equipment (Section 3.11, SSER 4)

a. DESC shall complete all actions related to environmental qualification of equipment on a schedule specified in Section 3.11 of Supplement 4 to the Safety Evaluation Report.

b. Complete and audible records shall be available and maintained at a central location by DESC. Such records shall describe the environmental qualification methods used for all safety-related electrical equipment in sufficient detail to document the degree of compliance with NUREG-0588, "Interim Staff Position on Environmental Qualification of Safety-Related Electrical Equipment," Revision 1, dated July 1981. Such records shall be updated and maintained current as equipment is replaced, further tested, or otherwise further qualified to document compliance with NUREG-0588.

c. Prior to startup after the first major shutdown or refueling outage after June 1983, DESC shall be in compliance with the provisions of NUREG-0588 for safety-related electrical equipment exposed to a harsh environment.

(9)

Mechanical Performance (Section 4.2.3, SER)

Prior to startup after the first refueling outage, DESC shall examine fuel rods for baffle-jetting failure as specified in Section 4.2.3 of the Safety Evaluation Report.

Should damage be observed at that time, a corrective action plan shall be submitted to the NRC staff for review and approval.

(10) Overpressurization Protection (Section 5.2.2, SSER 4)

Prior to startup after the first refueling outage, DESC shall install an NRC staff-approved low-temperature overpressurization protection system. The preliminary design shall be provided for NRC staff review not later than June 30, 1983.

(11) lnservice Inspection and Testing (Section 5.2.4. SSER 3)

DESC shall perform the following actions in conjunction with the first inservice examination:

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a. Demonstrate the ability of the ultrasonic examination procedure to detect actual flaws and/or artificial reflectors in the volume subject to examination to the acceptance standards of Paragraph IWB-3500 in weldments representative of the design and materials of construction.

b. In the event that one-third thickness semi-circular reference flaws cannot be detected and discriminated from inherent anomalies, the entire volume of the weld shall be examined during the inservice inspection.

c. The reporting of the inservice inspection examination results shall be documented in a manner to define qualitatively whether, the weldment and the heat affected zone and adjacent base metal on both sides of the weld were examined by ultrasonic angle beam techniques.

(12) Design Description - Control (Section 4.3.2, SER)

DESC is prohibited from using part-length rods during power operation.

(13) Deleted (14) Deleted (15) Deleted (16) Cable Tray Separation (Section 8.3.3, SSER 4)

Prior to startup after the first refueling outage, DESC shall implement the modifications to the cable trays discussed in Section 8.3.3 of Supplement No. 4 to the Safety Evaluation Report or demonstrate to the NRC staff that faults induced in non-class 1E cable trays will not result in failure of cable in the adjacent Class 1E cable trays.

(17) Alternate Shutdown System (Section 9.5.1, SSER 4)

Prior to startup after the first refueling outage, DESC shall install a source range neutron flux monitor independent of the control complex as part of the alternate shutdown system.

(18) Fire Protection Program Dominion Energy South Carolina, Inc. shall implement and maintain in effect all provisions of the approved fire protection program that comply with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the license amendment request dated 11/15/11 (and supplements dated 1/26/12, 10/10/12, 2/1/13, 4/1/13, 10/14/13, 11/26/13, 1/9/14, 2/25/14, 5/2/14, 5/11/14, 8/14/14, 10/9/14, 12/11/14), and license amendment request dated 8/29/18 (and supplements dated 4/29/19, 5/22/19, 8/12/19, and 10/9/19) and as approved in safety evaluations dated 2/11/15 and 3/6/2020.

Except where NRC approval for changes or deviations is required by 10 CFR 50.48(c), and provided no other regulation, technical specification, license condition or requirement would require prior NRC approval, the licensee may make changes to the fire protection program without prior approval of the Commission if those changes satisfy the provisions set forth in 10 CFR 50.48(a) and 10 CFR 50.48(c),

7 the change does not require a change to a technical specification or a license condition, and the criteria listed below are satisfied.

a. Risk-Informed Changes that May Be Made Without Prior NRC Approval A risk assessment of the change must demonstrate that the acceptance criteria below are met. The risk assessment approach, methods, and data shall be acceptable to the NRC and shall be appropriate for the nature and scope of the change being evaluated; be based on the as-built, as-operated, and maintained plant; and reflect the operating experience at the plant. Acceptable methods to assess the risk of the change may include methods that have been used in the peer-reviewed fire PRA model, methods that have been approved by NRC through a plant-specific license amendment or NRC approval of generic methods specifically for use in NFPA 805 risk assessments, or methods that have been demonstrated to bound the risk impact.

1. Prior NRC review and approval is not required for changes that clearly result in a decrease in risk. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins. The change may be implemented following completion of the plant change evaluation.

2. Prior NRC review and approval is not required for individual changes that result in a risk increase less than 1x10-7/year (yr) for CDF and less than 1x10-8/yr for LERF. The proposed change must also be consistent with the defense-in-depth philosophy and must maintain sufficient safety margins.

The change may be implemented following completion of the plant change evaluation.

b. Other Changes that May Be Made Without Prior NRC Approval

1. Changes to NFPA 805, Chapter 3, Fundamental Fire Protection Program Prior NRC review and approval are not required for changes to the NFPA 805, Chapter 3, fundamental fire protection program elements and design requirements for which an engineering evaluation demonstrates that the alternative to the Chapter 3 element is functionally equivalent or adequate for the hazard. The licensee may use an engineering evaluation to demonstrate that a change to NFPA 805, Chapter 3, element is functionally equivalent to the corresponding technical requirement.

A qualified fire protection engineer shall approve the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard.

The licensee may use an engineering evaluation to demonstrate that changes to certain NFPA 805, Chapter 3, elements are acceptable because the alternative is "adequate for the hazard." Prior NRC review and approval would not be required for alternatives to four specific sections of NFPA 805, Chapter 3, for which an engineering evaluation demonstrates that the alternative to the

8 Chapter 3 element is adequate for the hazard. A qualified fire protection engineer shall approve the engineering evaluation and conclude that the change has not affected the functionality of the component, system, procedure, or physical arrangement, using a relevant technical requirement or standard.

The four specific sections of NFPA 805, Chapter 3, are as follows:

Fire Alarm and Detection Systems (Section 3.8);

Automatic and Manual Water-Based Fire Suppression Systems (Section 3.9);

Gaseous Fire Suppression Systems (Section 3.10); and, Passive Fire Protection Features (Section 3.11).

This License Condition does not apply to any demonstration of equivalency under Section 1.7 of NFPA 805.

2. Fire Protection Program Changes that Have No More than Minimal Risk Impact Prior NRC review and approval are not required for changes to the licensee's fire protection program that have been demonstrated to have no more than a minimal risk impact. The licensee may use its screening process as approved in the NRC safety evaluation dated February 11, 2015. The licensee shall ensure that fire protection defense-in-depth and safety margins are maintained when changes are made to the fire protection program.

c. Transition License Conditions

1. Before achieving full compliance with 10 CFR 50.48(c), as specified by c.2 and c.3 below, risk-informed changes to the licensee's fire protection program may not be made without prior NRC review and approval unless the change has been demonstrated to have no more than a minimal risk impact, as described in b.2 above.

2. The licensee shall implement the modifications to its facility, as described in Attachment S, Table S-1, "Plant Modifications Committed," of DESC letter RC-14-0196, dated December 11, 2014, as modified by Enclosure 1, Attachments 2 and 3, of the DESC letter RC-18-0091, dated August 29, 2018. The licensee shall maintain appropriate compensatory measures in place until issuance of the safety evaluation.

3. The licensee shall implement items listed in Attachment S, Table S-2, "Implementation Items," of DESC letter RC-14-0196, dated December 11, 2014, to complete the transition to full compliance with 10 CFR 50.48(c) by March 31, 2016, as follows:

a. Items 3, 6, 7, 8, 10, 13, 14, 17, 19, and 21 within 180 days of NRC approval.

b. Items 1, 2, 4, 11, and 12 by December 31, 2015.

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c. Items 5, 15, 16, 18, 20, 22, and 23 by March 31, 2016.

(19) Instrument and Control Vibration Tests for Emergency Diesel Engine Auxiliary Support Systems (Section 9.5.4, SER)

Prior to startup after the first refueling outage, DESC shall either provide test results and results of analyses to the NRC staff for review and approval which validate that the skid-mounted control panels and mounted equipment have been developed, tested, and qualified for operation under severe vibrational stresses encountered during diesel engine operation, or DESC shall floor mount the control panels presently furnished with the diesel generators separate from the skid on a vibration-free floor area.

(20) Solid Radioactive Waste Treatment System (Section 11.2.3, SSER 4)

DESC shall not ship "wet" solid wastes from the facility until the NRC staff has reviewed and approved the process control program for the cement solidification system.

(21) Process and Effluent Radiological Monitoring and Sampling Systems (Section 11.3, SSER 4)

Prior to startup after the first refueling outage, DESC shall install and calibrate the condensate demineralizer backwash effluent monitor RM-L11.

(22) Core Reactivity Insertion Events (Section 15.2.4, SSER 4)

For operations above 90% of full power, DESC shall control the reactor manually or the rods shall be out greater than 215 steps until written approval is received from the NRC staff authorizing removal of this restriction.

(23) NUREG-0737 Conditions (Section 22)

DESC shall complete the following conditions to the satisfaction of the NRC staff. Each item references the related subpart of Section 22 of the SER and/or its supplements.

a. Procedures for Transients and Accidents (I.C.1. SSER 4)

Prior to startup after the first refueling outage, DESC shall implement emergency operating procedures based on guidelines approved by the NRC staff.

b. Special Low Power Testing and Training (I.G.1. SSER 4)

Within twelve months following completion of the startup test program, DESC shall provide a report describing the results of a comparison of actual plant data taken during the natural circulation test program to the simulator responses described in the DESC letter, T. C. Nichols, Jr. to H. R. Denton dated March 31, 1982.

c. Direct Indication of Safety Valve Position (II.D.3, SSER 4)

10 Prior to exceeding 5 percent of full power, the safety valve position indication system shall be seismically qualified by DESC consistent with the component or system to which it is attached, and documentation of this shall be provided to the NRC staff for review and approval.

d. Inadequate Core Cooling Instruments (II.F.2, SSER 4)

Prior to startup after the first major shutdown or refueling outage after June 30, 1983, DESC shall complete upgrading of the incore thermocouple wiring and qualification of isolators, reference junction boxes and connectors.

e. Plant-Specific Calculations for Compliance with 10 CFR Section 50.46 (II.K.3.31, SSER 1)

Within one year after model revisions are approved by the NRC staff, DESC shall provide a supplemental plant-specific analysis to verify compliance with 10 CFR 50.46, using the revised models developed under item II.K.3.30 of NUREG-0737.

f. Upgrade Emergency Support Facilities (III.A.1.2. SSER 4)

DESC shall complete its emergency response facilities as follows:

(i) Safety parameter display system - April 1, 1983 (ii) Emergency operations facility - April 1, 1983 (iii) Technical support center - April 1, 1983 (24) Deleted (25) Confirmatory Seismic Analysis (ASLB Partial Initial Decision, July 20, 1982, Section Vl.2)

During the first year of operation, DESC shall successfully complete the confirmatory program on plant equipment and components within the guidelines established in the findings contained in the ASLB Partial Initial Decision dated July 20, 1982, to demonstrate to the NRC staffs satisfaction that explicit safety margins exist for each component necessary for shutdown and continued heat removal in the event of the maximum potential shallow earthquake.

(26) Plume Exposure Emergency Planning Zone (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.3)

During the first year of operation, DESC shall assure that the plume exposure emergency planning zone has been expanded to include the Kelly Miller, Greenbriar Headstart and Chapin Elementary schools and the emergency evacuation plans have been adjusted accordingly.

(27) Transportation Planning (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.4)

11 During the first year of operation, DESC shall assure that the defects in transportation planning discussed in Finding 24 of the ASLB Supplemental Partial Initial Decision dated August 4, 1982, have been remedied.

(28) Food Pathway Contamination (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.6)

During the first year of operation, DESC shall assure that plans to implement remedial and preventive measures for consumer protection against food pathway contamination have been formulated and communicated to the agricultural community.

(29) Siren Alerting System (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.7)

Prior to exceeding 5% of full power, DESC shall complete installation and satisfactory testing of its siren alerting system.

(30) Emergency Facilities and Staffing (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.8)

DESC shall complete the following three items related to emergency preparedness to the satisfaction of the NRC staff, consistent with the Supplement No. 2 to the Safety Evaluation Report, page A-13:

(i) Minimum shift manning requirements (ii) Emergency response facilities (iii) Meteorological and dose assessment capability (31) Final NRC Approval of Emergency Preparedness (ASLB Supplemental Partial Initial Decision, August 4, 1982, Section Vlll.9)

Prior to exceeding 5% of full power, final NRC staff approval of the state of emergency preparedness for the Virgil C. Summer Nuclear Station site shall be required.

(32) Deleted (33) Emergency Preparedness Exercise (Section 13.3, SSER #5)

Prior to March 31, 1983, DESC shall conduct an emergency exercise similar to that conducted on May 5, 1982, but which includes full participation of the local governments and partial State participation.

(34) Mitigation Strategy License Condition DESC 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:

12

i.

Pre-defined coordinated fire response strategy and guidance ii. Assessment of mutual aid fire fighting assets iii. Designated staging areas for equipment and materials iv. Command and control

v. Training of response personnel

b. Operations to mitigate fuel damage considering the following:

i.

Protection and use of personnel assets ii. Communications iii. Minimizing fire spread iv. Procedures for implementing integrated fire response strategy

v. Identification of readily-available pre-staged equipment vi. Training on integrated fire response strategy vii. Spent fuel pool mitigation measures

c. Actions to minimize release to include consideration of:

i.

Water spray scrubbing ii. Dose to onsite responders D. An exemption to the requirements of Paragraph 111.B.4 of Appendix G to 10 CFR Part 50 is described in Section 5.3.1 of Supplement No. 1 to the Office of Nuclear Reactor Regulation's Safety Evaluation Report. A limited exemption to the requirements of Section IV.F.1(b) of Appendix E to 10 CFR Part 50 is described in a letter from B. J. Youngblood, NRC to O. W. Dixon, Jr., dated November 2, 1982. These exemptions are authorized by law and will not endanger life or property or the common defense and security and are otherwise in the public interest. 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. DESC 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 combined set of plans, which contain Safeguards Information protected under 10 CFR 73.21, is entitled: "Virgil C. Summer Nuclear Station Security Plan," as updated through May 15, 2006. This document includes the Security Training and Qualification Plan as Appendix B and the Safeguards Contingency Plan as Appendix C.

DESC shall fully implement and maintain in effect all provisions of the Commission-approved cyber security plan (CSP), including changes made pursuant to the authority of 10 CFR 50.90 and 10 CFR 50.54(p). The CSP was approved by License Amendment No. 184, as supplemented by changes approved by License Amendment Nos. 198 and 208.

F. This subsequent renewed license is subject to the following additional condition for the protection of the environment:

Before engaging in activities that may result in a significant adverse environmental

13 impact that was not evaluated or that is significantly greater than that evaluated In the Final Environmental Statement, DESC shall provide a written notification of such activities to the NRC Office of Nuclear Reactor Regulation and receive written approval from that office before proceeding with such activities.

G. Reporting to the Commission:

(1)

DELETED (2)

DESC shall notify the Commission as soon as possible but not later than one hour, of any accident at this facility which could result in an unplanned release of quantities of fission products in excess of allowable limits for normal operation established by the Commission.

H. The licensees 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.

I.

In accordance with the Commission's direction in its Statement of Policy, Licensing and Regulatory Policy and Procedures for Environmental Protection: Uranium Fuel Cycle Impacts, October 29, 1982, this license is subject to the final resolution of the pending litigation involving Table S-3. See, Natural Resources Defense Council vs. NRC, No.

74-1586 (April 27, 1982).

J. Additional License Conditions The Additional Conditions contained in Appendix C, as revised through Amendment No.

216, are hereby incorporated into this subsequent renewed license. Dominion Energy South Carolina, Inc. shall operate the facility in accordance with the Additional Conditions.

K. Updated Final Safety Analysis Report The Updated Final Safely Analysis Report Supplement, submitted pursuant to 10 CFR 54.21(d), describes certain future activities to be completed prior to the period of extended operation. Dominion Energy South Carolina, Inc. shall complete these activities no later than August 6, 2022, and shall notify the NRC in writing when implementation of these activities is complete and can be verified by NRC inspection.

The Updated Final Safety Analysis Report Supplement, as revised, shall be included in the next scheduled update to the Updated Final Safety Analysis Report required by 10 CFR 50.71(e)(4) following issuance of this subsequent renewed license. Until that update is complete, Dominion Energy South Carolina, Inc. may make changes to the programs and activities described in the supplement without prior Commission approval, provided that Dominion Energy South Carolina, Inc. evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

L. All capsules in the reactor vessel that are removed and tested must meet the test procedures and reporting requirements of 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

14 implementation. All capsules placed in storage must be maintained for future insertion.

Any changes to storage requirements must be approved by the NRC.

M. Subsequent License Renewal License Conditions (1)

The information in the Updated Final Safety Analysis Report Supplement submitted as required by 10 CFR 54.21(d), and revised during the application review process, and the licensees commitments listed in Appendix A of the Final Safety Evaluation to the SLRA of Virgil C. Summer Nuclear Station, Unit 1, Revision 1, dated March 4, 2025, are collectively the Subsequent License Renewal Final Safety Analysis Report Supplement. This supplement is henceforth part of the Updated Final Safety Analysis Report which will be updated in accordance with 10 CFR 50.71(e).

As such, the licensee may make changes to the programs, activities, and commitments described in the Subsequent License Renewal Updated Final Safety Analysis Report Supplement, provided the licensee evaluates such changes pursuant to 10 CFR 50.59, Changes, Tests and Experiments, and otherwise complies with the requirements in that section.

(2)

This Subsequent License Renewal Final Safety Analysis Report Supplement, as defined in subsequent renewed license condition (1) above, describes programs to be implemented and activities to be completed before the subsequent period of extended operation, which is the period following the August 6, 2042, expiration of the initial renewed license.

a. The licensee shall implement those new programs and enhancements to existing programs no later than the date 6 months before the subsequent period of extended operation.

b. The licensee shall complete those activities by the date 6 months prior to the subsequent period of extended operation or by the end of the last refueling outage before the subsequent period of extended operation, whichever occurs later.

c. The licensee shall notify the NRC in writing within 30 days after having accomplished item (2)a above and include the status of those activities that have been or remain to be completed in item (2)b above.

d. The programs and commitments described in the Subsequent License Renewal Final Safety Analysis Report Supplement shall continue in effect during the subsequent period of extended operation, to the extent set forth therein, unless modified in accordance with the process set forth in 10 CFR 50.59.

15 N. This subsequent renewed license is effective as of the date of issuance and shall expire at midnight, August 6, 2062.

FOR THE NUCLEAR REGULATORY COMMISSION

/RA/

Gregory T. Bowman, Acting Director Office of Nuclear Reactor Regulation

Enclosures:

1. Appendix A (Technical Specifications)

2. Appendix B (Environmental Protection Plan)

3. Appendix C (Additional Conditions)

Date of Issuance: June 30, 2025

16 to Subsequent Renewed Operating License No. NPF-12 This attachment identifies certain preoperational tests, system demonstrations and other items which must be completed to the satisfaction of NRC Region II. Dominion Energy South Carolina, Inc. (DESC) shall not proceed without written confirmation from NRC Region II that the following items have been completed in accordance with the conditions and schedules set forth below:

1.

Prior to initial criticality, DESC shall complete to the satisfaction of NRC Region II the following 10 CFR Part 21 identified item:

Correct the diesel generator slow start times attributed to fuel oil header drain down (81-29-01).

2.

Prior to initial criticality, DESC shall complete to the satisfaction of NRC Region II the following open items:

a.

Complete the replacement of all damaged prefilters external to the containment building (82-07-03).

b.

Complete the repair and testing of diesel generator B before entering Mode 4.

3.

Prior to exceeding 5% of full power, DESC shall complete to the satisfaction of NRC Region II the requirements of the following bulletins:

a.

Failure of gate-type valves to close against differential pressure (81-BU-02).

b.

Seismic analysis for as-built safety-related piping systems required to support operations above 5% of full power (79-BU-14).

4.

Prior to exceeding 5% of full power, DESC shall complete to the satisfaction of NRC Region II the following 10 CFR 21 identified items:

a.

Westinghouse 3-inch gate valve closure failure (80-37-10).

b.

Westinghouse 4-inch gate valve closure failure (81-05-09).

5.

Prior to exceeding 5% of full power, DESC shall complete to the satisfaction of NRC Region II the following open items:

a.

Correct the hydrogen recombiner high hydrogen alarm set at 6%

versus proposed Technical Specification limit of 2% (80-06-07).

b.

Satisfactorily complete the capability test for Fe-55 analyses of liquid waste samples.

6.

Prior to full power operation, DESC shall complete to the satisfaction of NRC Region II the requirements of the following bulletin:

Audibility problems encountered during evacuation alarm in high noise area (79-BU-18).

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7.

Prior to full power operation, DESC shall complete to the satisfaction of NRC Region II the following open item:

Resolve the problem of the reactor building temperature being greater than expected during hot functional testing (80-25-09).