Text

Issuance of Amendments Regarding the Adoption of Technical Specifications Task Force Traveler TSTF-541, Rev. 2
	ML22256A253
Person / Time
Site:	Oconee, Mcguire, Catawba, Harris, Brunswick, Robinson, McGuire
Issue date:	11/14/2022
From:	Luke Haeg; Plant Licensing Branch II
To:	Gibby S; Duke Energy Corp
	Haeg, L.
References
	EPID L-2022-LLA-0011
	Download: ML22256A253 (89)
	v • d • e

November 14, 2022 Mr. Shawn Gibby Vice President Nuclear Engineering Duke Energy 526 South Church Street, EC-07H Charlotte, NC 28202

SUBJECT:

BRUNSWICK STEAM ELECTRIC PLANT, UNIT NOS. 1 AND 2; CATAWBA NUCLEAR STATION, UNIT NOS. 1 AND 2; SHEARON HARRIS NUCLEAR POWER PLANT, UNIT NO. 1; MCGUIRE NUCLEAR STATION, UNIT NOS. 1 AND 2; OCONEE NUCLEAR STATION, UNIT NOS. 1, 2, AND 3; AND H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 - ISSUANCE OF AMENDMENTS REGARDING THE ADOPTION OF TECHNICAL SPECIFICATIONS TASK FORCE TRAVELER TSTF-541, REVISION 2 (EPID L-2022-LLA-0011)

Dear Mr. Gibby:

The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the following enclosed Amendment Nos. 310 and 338 to Renewed Facility Operating License Nos. DPR-71 and DPR-62 for the Brunswick Steam Electric Plant, Unit Nos. 1 and 2, respectively; Amendment Nos. 315 and 311 to Renewed Facility Operating License Nos. NPF-35 and NPF-52 for the Catawba Nuclear Station, Unit Nos. 1 and 2, respectively; Amendment No. 196 to Renewed Facility Operating License No. NPF-63 for the Shearon Harris Nuclear Power Plant, Unit No. 1; Amendment Nos. 325 and 304 to Renewed Facility Operating License Nos. NPF-9 and NPF-17 for the McGuire Nuclear Station, Unit Nos. 1 and 2, respectively; Amendment Nos. 425, 427, and 426 to Renewed Facility Operating License Nos. DPR-38, DPR-47, and DPR-55 for the Oconee Nuclear Station, Unit Nos. 1, 2, and 3, respectively; and Amendment No. 272 to Renewed Facility Operating License No. DPR-23 for the H. B. Robinson Steam Electric Plant, Unit No. 2.

The license amendments consist of changes to the technical specifications (TSs) in response to your application dated January 18, 2022 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML22018A236).

The amendments modified certain TS surveillance requirements (SRs) by adding exceptions to consider the SR met when automatic valves or dampers are locked, sealed, or otherwise secured in the actuated position, in order to consider the SR met based on TS Task Force (TSTF) Traveler TSTF-541, Revision 2, Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position (ML19240A315), and the associated NRC safety evaluation for TSTF-541, Revision 2 (ML19323E926).

A copy of the NRC staffs safety evaluation is also enclosed. The Notice of Issuance will be included in the Commissions monthly Federal Register notice.

Following issuance of the Oconee Nuclear Station, Unit No. 3, Amendment No. 425 (ML22096A187), the NRC identified that the NRC staff included erroneous subsection letters on Page 3 of Renewed License No. DPR-55. The NRC concludes that these corrections are entirely editorial in nature and do not change the staffs previous conclusion in the safety evaluation for the issuance of Amendment No. 425, nor do they affect the no significant hazards considerations, as published in the Federal Register on November 2, 2021 (86 FR 60481). The corrections are included in Enclosure 10.

If you have any questions, please contact me at (301) 415-0272 or by e-mail at Lucas.Haeg@nrc.gov.

Sincerely,

/RA/

Lucas E. Haeg, Project Manager Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos.: 50-325, 50-324, 50-413, 50-414, 50-400, 50-369, 50-370, 50-269, 50-270, 50-287, and 50-261

Enclosures:

1. Amendment No. 310 to DPR-71

2. Amendment No. 338 to DPR-62

3. Amendment No. 315 to NPF-35

4. Amendment No. 311 to NPF-52

5. Amendment No. 196 to DPR-63

6. Amendment No. 325 to NPF-9

7. Amendment No. 304 to NPF-17

8. Amendment No. 425 to DPR-38

9. Amendment No. 427 to DPR-47

10. Amendment No. 426 to DPR-55

11. Amendment No. 272 to DPR-23

12. Safety Evaluation

cc:

Mr. John A. Krakuszeski Site Vice President Duke Energy Progress, LLC Brunswick Steam Electric Plant 8470 River Rd., SE (M/C BNP001)

Southport, NC 28461 Mr. Robert T. Simril Site Vice President Duke Energy Carolinas, LLC Catawba Nuclear Station 4800 Concord Road York, SC 29745 Mr. Thomas Haaf Site Vice President Duke Energy Progress, LLC Shearon Harris Nuclear Power Plant 5413 Shearon Harris Rd, M/C HNP01 New Hill, NC 27562-9300 Mr. Edward Pigott Site Vice President Duke Energy Carolinas, LLC McGuire Nuclear Station 12700 Hagers Ferry Road Huntersville, NC 28078-8985 Mr. Steven M. Snyder Site Vice President Duke Energy Carolinas, LLC Oconee Nuclear Station 7800 Rochester Highway Seneca, SC 29672-0752 Ms. Nicole L. Flippin Site Vice President Duke Energy Progress, LLC H. B. Robinson Steam Electric Plant 3581 West Entrance Road, RNPA11 Hartsville, SC 29550 Additional Distribution via Listserv

DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-325 BRUNSWICK STEAM ELECTRIC PLANT, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 310 Renewed License No. DPR-71

1.

The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment filed by Duke Energy Progress, LLC (the licensee), dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-71 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 310, are hereby incorporated in the license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 13:54:18 -05'00'

ATTACHMENT TO DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-325 BRUNSWICK STEAM ELECTRIC PLANT, UNIT 1 AMENDMENT NO. 310 RENEWED FACILITY OPERATING LICENSE NO. DPR-71 Replace the following pages of the Renewed Facility Operating Licenses with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert DPR-71, Page 6 DPR-71, Page 6 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.5-7 3.5-7 3.5-12 3.5-12 3.5-15 3.5-15 3.6-35 3.6-35 3.7-10 3.7-10 3.7-14 3.7-14 Renewed License No. DPR-71 Amendment No. 310 (c)

Transition License Conditions 1.

Before achieving full compliance with 10 CFR 50.48(c), as specified by 2. below, risk-informed changes to the licensees 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 2. above.

2.

The licensee shall implement the modifications to its facility, as described in Table S-1, Plant Modifications Committed, of Duke letter BSEP 14-0122, dated November 20, 2014, to complete the transition to full compliance with 10 CFR 50.48(c) by the startup of the second refueling outage for each unit after issuance of the safety evaluation. The licensee shall maintain appropriate compensatory measures in place until completion of these modifications.

3.

The licensee shall complete all implementation items, except item 9, listed in LAR Attachment S, Table S-2, Implementation Items, of Duke letter BSEP 14-0122, dated November 20, 2014, within 180 days after NRC approval unless the 180th day falls within an outage window; then, in that case, completion of the implementation items, except item 9, shall occur no later than 60 days after startup from that particular outage. The licensee shall complete implementation of LAR Attachment S, Table S-2, Item 9, within 180 days after the startup of the second refueling outage for each unit after issuance of the safety evaluation.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; and is subject to all applicable provisions hereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1)

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2923 megawatts thermal.

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 310, are hereby incorporated in the license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications.

For Surveillance Requirements (SRs) that are new in Amendment 203 to Renewed Facility Operating License DPR-71, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 203. For SRs that existed prior to Amendment 203, including SRs with modified acceptance criteria and SRs whose frequency of

ECCSOperating 3.5.1 Brunswick Unit 1 3.5-7 Amendment No. 310 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9

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

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.10

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

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated automatic initiation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.11

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure is adequate to perform the test.

Verify each required ADS valve is capable of being opened.

In accordance with the INSERVICE TESTING PROGRAM SR 3.5.1.12

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

Instrumentation response time may be assumed to be the design instrumentation response time.

Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within the limit.

In accordance with the Surveillance Frequency Control Program

RPV Water Inventory Control 3.5.2 Brunswick Unit 1 3.5-12 Amendment No. 310 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.7

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

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem can be manually operated.

In accordance with the Surveillance Frequency Control Program

RCIC System 3.5.3 Brunswick Unit 1 3.5-15 Amendment No. 310 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.4

NOTES------------------------------

1.

Use of auxiliary steam for the performance of the SR is not allowed with reactor pressure 150 psig.

2.

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reactor steam pressure is adequate to perform the test.

Verify, with turbine inlet pressure 135 psig and 165 psig, the RCIC pump can develop a flow rate 400 gpm against a system head corresponding to an equivalent reactor pressure.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.5

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

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

SGT System 3.6.4.3 Brunswick Unit 1 3.6-35 Amendment No. 310 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Two SGT subsystems inoperable during movement of recently irradiated fuel assemblies in the secondary containment.

E.1

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

LCO 3.0.3 is not applicable.

Suspend movement of recently irradiated fuel assemblies in secondary containment.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 15 continuous minutes with heaters operating.

In accordance with the Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual or simulated initiation signal, except for dampers that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

SW System and UHS 3.7.2 Brunswick Unit 1 3.7-10 Amendment No. 310 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.2.5

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

Isolation of flow to individual components does not render SW System inoperable.

Verify each required SW System automatic component actuates on an actual or simulated initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

CREV System 3.7.3 Brunswick Unit 1 3.7-14 Amendment No. 310 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.3.3 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitability Program SR 3.7.3.4 Verify each CREV subsystem actuates on an actual or simulated initiation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-324 BRUNSWICK STEAM ELECTRIC PLANT, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 338 Renewed License No. DPR-62

1.

The U.S. Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment filed by Duke Energy Progress, LLC (the licensee), dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 2.C.(2) of Renewed Facility Operating License No. DPR-62 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 338, are hereby incorporated in the license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 13:54:51 -05'00'

ATTACHMENT TO DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-324 BRUNSWICK STEAM ELECTRIC PLANT, UNIT 2 AMENDMENT NO. 338 RENEWED FACILITY OPERATING LICENSE NO. DPR-62 Replace the following pages of the Renewed Facility Operating Licenses with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert DPR-62, Page 6 DPR-62, Page 6 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.5-7 3.5-7 3.5-12 3.5-12 3.5-15 3.5-15 3.6-35 3.6-35 3.7-10 3.7-10 3.7-14 3.7-14

6 Renewed License No.

DPR-62 Amendment No. 338 (c)

Transition License Conditions 1.

Before achieving full compliance with 10 CFR 50.48(c), as specified by 2. below, risk-informed changes to the licensees 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 2. above.

2.

The licensee shall implement the modifications to its facility, as described in Table S-1, Plant Modifications Committed, of Duke letter BSEP 14-0122, dated November 20, 2014, to complete the transition to full compliance with 10 CFR 50.48(c) by the startup of the second refueling outage for each unit after issuance of the safety evaluation. The licensee shall maintain appropriate compensatory measures in place until completion of these modifications.

3.

The licensee shall complete all implementation items, except Item 9, listed in LAR Attachment S, Table S-2, Implementation Items, of Duke letter BSEP 14-0122, dated November 20, 2014, within 180 days after NRC approval unless the 180th day falls within an outage window; then, in that case, completion of the implementation items, except item 9, shall occur no later than 60 days after startup from that particular outage. The licensee shall complete implementation of LAR Attachment S, Table S-2, Item 9, within 180 days after the startup of the second refueling outage for each unit after issuance of the safety evaluation.

C. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Section 30.34 of Part 30, Section 40.41 of Part 40, Sections 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; 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 The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2923 megawatts (thermal).

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 338, are hereby incorporated in the license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications.

For Surveillance Requirements (SRs) that are new in Amendment 233 to Renewed Facility Operating License DPR-62, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 233. For SRs that existed prior to Amendment 233,

ECCSOperating 3.5.1 Brunswick Unit 2 3.5-7 Amendment No. 338 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.9

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

Vessel injection/spray may be excluded.

Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.10

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

Valve actuation may be excluded.

Verify the ADS actuates on an actual or simulated automatic initiation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.11

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam pressure is adequate to perform the test.

Verify each required ADS valve is capable of being opened.

In accordance with the INSERVICE TESTING PROGRAM SR 3.5.1.12

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

Instrumentation response time may be assumed to be the design instrumentation response time.

Verify the ECCS RESPONSE TIME for each ECCS injection/spray subsystem is within the limit.

In accordance with the Surveillance Frequency Control Program

RPV Water Inventory Control 3.5.2 Brunswick Unit 2 3.5-12 Amendment No. 338 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.7

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

Vessel injection/spray may be excluded.

Verify the required ECCS injection/spray subsystem can be manually operated.

In accordance with the Surveillance Frequency Control Program

RCIC System 3.5.3 Brunswick Unit 2 3.5-15 Amendment No. 338 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.4

NOTES----------------------------

1.

Use of auxiliary steam for the performance of the SR is not allowed with reactor pressure 150 psig.

2.

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after reactor steam pressure is adequate to perform the test.

Verify, with turbine inlet pressure 135 psig and 165 psig, the RCIC pump can develop a flow rate 400 gpm against a system head corresponding to an equivalent reactor pressure.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.5

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

Vessel injection may be excluded.

Verify the RCIC System actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

SGT System 3.6.4.3 Brunswick Unit 2 3.6-35 Amendment No. 338 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Two SGT subsystems inoperable during movement of recently irradiated fuel assemblies in the secondary containment.

E.1

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

LCO 3.0.3 is not applicable.

Suspend movement of recently irradiated fuel assemblies in secondary containment.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.3.1 Operate each SGT subsystem for 15 continuous minutes with heaters operating.

In accordance with the Surveillance Frequency Control Program SR 3.6.4.3.2 Perform required SGT filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual or simulated initiation signal, except for dampers that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

SW System and UHS 3.7.2 Brunswick Unit 2 3.7-10 Amendment No. 338 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.2.5

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

Isolation of flow to individual components does not render SW System inoperable.

Verify each required SW System automatic component actuates on an actual or simulated initiation signal, except for valves that are locked sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

CREV System 3.7.3 Brunswick Unit 2 3.7-14 Amendment No. 338 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.3.3 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitability Program SR 3.7.3.4 Verify each CREV subsystem actuates on an actual or simulated initiation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-413 CATAWBA NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 315 Renewed License No. NPF-35

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment filed by Duke Energy Carolinas, LLC (the licensee), dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-35 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 315, which are attached hereto, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 13:55:28 -05'00'

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-414 CATAWBA NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 311 Renewed License No. NPF-52

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment filed by the Duke Energy Carolinas, LLC (the licensee), dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-52 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 311, which are attached hereto, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC, shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 13:56:13 -05'00'

ATTACHMENT TO DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-413 CATAWBA NUCLEAR STATION, UNIT 1 AMENDMENT NO. 315 RENEWED FACILITY OPERATING LICENSE NO NPF-35 AND DOCKET NO. 50-414 CATAWBA NUCLEAR STATION, UNIT 2 AMENDMENT NO. 311 RENEWED FACILITY OPERATING LICENSE NO. NPF-52 Replace the following pages of the Renewed Facility Operating Licenses with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert NPF-35, Page 4 NPF-35, Page 4 NPF-52, Page 4 NPF-52, Page 4 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.6.10-2 3.6.10-2 3.6.17-1 3.6.17-1 3.7.10-3 3.7.10-3 3.7.12-2 3.7.12-2 Renewed License No. NPF-35 Amendment No. 315 (2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 315 which are attached hereto, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC shall operate the facility in accordance with the Technical Specifications.

(3)

Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation. Duke shall complete these activities no later than December 6, 2024, 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 on December 16, 2002, described above, 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 renewed operating license. Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

(4)

Antitrust Conditions Duke Energy Carolinas, LLC shall comply with the antitrust conditions delineated in Appendix C to this renewed operating license.

(5)

Fire Protection Program Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program that complies with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the licensee amendment request dated September 25, 2013; as supplemented by letters dated January 13, 2015; January 28, 2015; February 27, 2015; March 30, 2015; April 28, 2015; July 15, 2015; August 14, 2015; September 3, 2015; December 11, 2015; January 7, 2016; March 23, 2016; June 15, 2016; August 2, 2016; September 7, 2016; and, January 26, 2017, as approved in the SE dated February 8, 2017. 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),

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

Renewed License No. NPF-52 Amendment No. 311 (2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 311 which are attached hereto, are hereby incorporated into this renewed operating license. Duke Energy Carolinas, LLC shall operate the facility in accordance with the Technical Specifications.

(3)

Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation. Duke shall complete these activities no later than December 6, 2024, 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 on December 16, 2002, described above, 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 renewed operating license. Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

(4)

Antitrust Conditions Duke Energy Carolinas, LLC shall comply with the antitrust conditions delineated in Appendix C to this renewed operating license.

(5)

Fire Protection Program Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program that complies with 10 CFR 50.48(a) and 10 CFR 50.48(c), as specified in the licensee amendment request dated September 25, 2013; as supplemented by letters dated January 13, 2015; January 28, 2015; February 27, 2015; March 30, 2015; April 28, 2015; July 15, 2015; August 14, 2015; September 3, 2015; December 11, 2015; January 7, 2016; March 23, 2016; June 15, 2016; August 2, 2016; September 7, 2016; and, January 26, 2017, as approved in the SE dated February 8, 2017. 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),

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

AVS 3.6.10 Catawba Units 1 and 2 3.6.10-2 Amendment Nos. 315/311 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Operate each AVS train for > 15 continuous minutes.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.2 Perform required AVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be opened, except for valves that are locked, sealed, or otherwise secured in the open position.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.5 Verify each AVS train flow rate is > 8100 cfm and < 9900 cfm.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.6 Verify each AVS train produces a pressure equal to or more negative than -0.88 inch water gauge when corrected to elevation 564 feet.

In accordance with the Surveillance Frequency Control Program

CVIWS 3.6.17 Catawba Units 1 and 2 3.6.17-1 Amendment Nos. 315/311 3.6 CONTAINMENT SYSTEMS 3.6.17 Containment Valve Injection Water System (CVIWS)

LCO 3.6.17 Two CVIWS trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One CVIWS train inoperable.

A.1 Restore CVIWS train to OPERABLE status.

7 days B.

Required Action and associated Completion Time not met.

B.1 Be in MODE 3.

AND B.2 Be in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.17.1 Verify system surge tanks pressure is > 36.4 psig.

31 days SR 3.6.17.2 Verify valve injection flow rate is < 1.29 gpm (Unit 1)

< 1.21 gpm (Unit 2) for Train A and < 1.16 gpm for Train B with a surge tank pressure > 36.4 psig.

18 months SR 3.6.17.3 Verify each automatic valve actuates to its correct position on an actual or simulated actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

18 months

CRAVS 3.7.10 Catawba Units 1 and 2 3.7.10-3 Amendment Nos. 315/311 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CRAVS train for > 15 continuous minutes.

In accordance with the Surveillance Frequency Control Program SR 3.7.10.2 Perform required CRAVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with VFTP SR 3.7.10.3 Verify each CRAVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.10.4 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitability Program

ABFVES 3.7.12 Catawba Units 1 and 2 3.7.12-2 Amendment Nos. 315/311 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ABFVES train for > 15 continuous minutes.

In accordance with the Surveillance Frequency Control Program SR 3.7.12.2 Perform required ABFVES filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.12.3 Verify each ABFVES train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.12.4 Verify one ABFVES train can maintain the ECCS pump rooms at negative pressure relative to adjacent areas.

In accordance with the Surveillance Frequency Control Program

DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-400 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 196 Renewed License No. NPF-63

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Progress, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment 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; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-63 is hereby amended to read as follows:

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, as revised through Amendment No. 196, are hereby incorporated into this license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 13:57:05 -05'00'

ATTACHMENT TO DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-400 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT 1 AMENDMENT NO. 196 RENEWED FACILITY OPERATING LICENSE NO. NPF-63 Replace the following page of the Renewed Facility Operating License with the revised page.

The revised page is identified by amendment number and contains a marginal line indicating the area of change.

Remove Insert Page 4 Page 4 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3/4 6-11 3/4 6-11 3/4 6-12 3/4 6-12 3/4 7-11 3/4 7-11 3/4 7-12 3/4 7-12 3/4 7-16 3/4 7-16 3/4 7-30 3/4 7-30 Renewed License No. NPF-63 Amendment No. 196 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 Duke Energy Progress, LLC, is authorized to operate the facility at reactor Core power levels not in excess of 2948 megawatts thermal (100 percent rated core power) in accordance with the conditions specified herein.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A and the Environmental Protection Plan contained in Appendix B, both of which are attached hereto, as revised through Amendment No. 196, are hereby incorporated into this license. Duke Energy Progress, LLC shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3)

Antitrust Conditions Duke Energy Progress, LLC. shall comply with the antitrust conditions delineated in Appendix C to this license.

(4)

Initial Startup Test Program (Section 14)1 Any changes to the Initial Test Program described in Section 14 of the FSAR made in accordance with the provisions of 10 CFR 50.59 shall be reported in accordance with 50.59(b) within one month of such change.

(5)

Steam Generator Tube Rupture (Section 15.6.3)

Prior to startup following the first refueling outage, Carolina Power & Light Company* shall submit for NRC review and receive approval if a steam generator tube rupture analysis, including the assumed operator actions, which demonstrates that the consequences of the design basis steam generator tube rupture event for the Shearon Harris Nuclear Power Plant are less than the acceptance criteria specified in the Standard Review Plan, NUREG-0800, at 15.6.3 Subparts II (1) and (2) for calculated doses from radiological releases. In preparing their analysis Carolina Power &

Light Company* will not assume that operators will complete corrective actions within the first thirty minutes after a steam generator tube rupture.

1The parenthetical notation following the title of many license conditions denotes the section of the Safety Evaluation Report and/or its supplements wherein the license condition is discussed.

On April 29, 2013, the name of Carolina Power & Light Company (CP&L) was changed to Duke Energy Progress, Inc. On August 1, 2015, the name Duke Energy Progress, Inc. was changed to Duke Energy Progress, LLC.

Not required to be met for system vent flow paths opened under administrative control.

SHEARON HARRIS - UNIT 1 3/4 6-11 Amendment No. 196 CONTAINMENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS CONTAINMENT SPRAY SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.1 Two independent Containment Spray Systems shall be OPERABLE with each Spray System capable of taking suction from the RWST and transferring suction to the containment sump.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With one Containment Spray System inoperable, restore the inoperable Spray System to OPERABLE status within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s** or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Spray System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Refer also to Specification 3.6.2.3 Action.

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

- One Containment Spray System train is allowed to be inoperable for a total of 7 days to allow for maintenance on the Essential Services Chilled Water System and air handlers supported by the Essential Services Chilled Water System. Prior to exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the compensatory measures described in HNP LAR correspondence letter RA-19-0007 shall be implemented.

SURVEILLANCE REQUIREMENTS 4.6.2.1 Each Containment Spray System shall be demonstrated OPERABLE:

a.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position*;

b.

By verifying that, on an indicated recirculation flow of at least 1832 gpm, each pump develops a differential pressure of greater than or equal to 186 psi when tested pursuant to the INSERVICE TESTING PROGRAM; c.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying that each automatic valve in the flow path actuates to its correct position on a containment spray actuation test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and 2.

Verifying that each spray pump starts automatically on a containment spray actuation test signal.

3.

Verifying that, coincident with an indication of containment spray pump running, each automatic valve from the sump and RWST actuates to its appropriate position following an RWST Lo-Lo test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

d.

At the frequency specified in the Surveillance Frequency Control Program by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

e.

At the frequency specified in the Surveillance Frequency Control Program by verifying that containment spray locations susceptible to gas accumulation are sufficiently filled with water.

SHEARON HARRIS - UNIT 1 3/4 6-12 Amendment No. 196 CONTAINMENT SYSTEMS SPRAY ADDITIVE SYSTEM LIMITING CONDITION FOR OPERATION 3.6.2.2 The Spray Additive System shall be OPERABLE with:

a.

A Spray Additive Tank containing a volume of between 3268 and 3768 gallons of between 27 and 29 weight % of NaOH solution, and b.

Two spray additive eductors each capable of adding NaOH solution from the chemical additive tank to a Containment Spray System pump flow.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With the Spray Additive System inoperable, restore the system to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the Spray Additive System to OPERABLE status within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.6.2.2 The Spray Additive System shall be demonstrated OPERABLE:

a.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each valve (manual, power-operated, or automatic) in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position; b.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying the contained solution volume in the tank, and 2.

Verifying the concentration of the NaOH solution by chemical analysis.

c.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each automatic valve in the flow path actuates to its correct position on a containment spray or containment isolation phase A test signal as applicable; except for valves that are locked, sealed, or otherwise secured in the actuated position, and d.

At the frequency specified in the Surveillance Frequency Control Program by verifying each eductor flow rate is between 17.2 and 22.2 gpm, using the RWST as the test source containing at least 436,000 gallons of water.

The breaker for CCW pump 1C-SAB shall not be racked into either power source (SA or SB) unless the breaker from the applicable CCW pump (1A-SA or 1B-SB) is racked out.

SHEARON HARRIS - UNIT 1 3/4 7-11 Amendment No. 196 PLANT SYSTEMS 3/4.7.3 COMPONENT COOLING WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.3 At least two component cooling water (CCW) pumps*, heat exchangers and essential flow paths shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With only one component cooling water flow path OPERABLE, restore at least two flow paths to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or in accordance with the Risk-Informed Completion Time Program or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.3 At least two component cooling water flow paths shall be demonstrated OPERABLE:

a.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each valve (manual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its correct position; and b.

At the frequency specified in the Surveillance Frequency Control Program by verifying that:

1.

Each automatic valve servicing safety-related equipment or isolating non-safety-related components actuates to its correct position on a Safety Injection test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and 2.

Each Component Cooling Water System pump required to be OPERABLE starts automatically on a Safety Injection test signal.

3.

Each automatic valve serving the gross failed fuel detector and sample system heat exchangers actuates to its correct position on a Low Surge Tank Level test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SHEARON HARRIS - UNIT 1 3/4 7-12 Amendment No. 196 PLANT SYSTEMS 3/4.7.4 EMERGENCY SERVICE WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.4 At least two independent emergency service water loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With only one emergency service water loop OPERABLE, restore at least two loops to OPERABLE status within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s* or in accordance with the Risk-Informed Completion Time Program or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

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

The B Train emergency service water loop is allowed to be inoperable for a total of 7 days to allow for maintenance on the Essential Services Chilled Water System and air handlers supported by the Essential Services Chilled Water System. Prior to exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the compensatory measures described in HNP LAR correspondence letter RA-19-0007 shall be implemented.

SURVEILLANCE REQUIREMENTS 4.7.4 At least two emergency service water loops shall be demonstrated OPERABLE:

a.

At the frequency specified in the Surveillance Frequency Control Program by verifying that each valve (manual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its correct position; and b.

At the frequency specified in the Surveillance Frequency Control Program by verifying that:

1.

Each automatic valve servicing safety-related equipment or isolating non-safety portions of the system actuates to its correct position on a Safety Injection test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and 2.

Each emergency service water pump and each emergency service water booster pump starts automatically on a Safety Injection test signal.

SHEARON HARRIS - UNIT 1 3/4 7-16 Amendment No. 196 PLANT SYSTEMS CONTROL ROOM EMERGENCY FILTRATION SYSTEM SURVEILLANCE REQUIREMENTS (CONTINUED) 2.

Verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, has a methyl iodide penetration of 0.5% when tested at a temperature of 30°C and at a relative humidity of 95% in accordance with ASTM D3803 -1989.

c.

After every 720 hours0.00833 days 0.2 hours 0.00119 weeks 2.7396e-4 months of charcoal adsorber operation, by verifying, within 31 days after removal, that a laboratory analysis of a representative carbon sample obtained in accordance with Regulatory Position C.6.b of Regulatory Guide 1.52, Revision 2, March 1978, has a methyl iodide penetration of 0.5% when tested at a temperature of 30°C and at a relative humidity of 95% in accordance with ASTM D3803-1989.

d.

At the frequency specified in the Surveillance Frequency Control Program by:

1.

Verifying that the pressure drop across the combined HEPA filters and charcoal adsorber banks is less than 5.1 inches water gauge while operating the system at a flow rate of 4000 cfm +/- 10%;

2.

Verifying that, on either a Safety Injection or a High Radiation test signal, the system automatically switches into an isolation with recirculation mode of operation with flow through the HEPA filters and charcoal adsorber banks, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position; 3.

Deleted.

4.

Deleted.

5.

Deleted.

e.

After each complete or partial replacement of a HEPA filter bank, by verifying that the unit satisfies the in-place penetration and bypass leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a DOP test aerosol while operating the system at a flow rate of 4000 cfm +/- 10%; and f.

After each complete or partial replacement of a charcoal adsorber bank, by verifying that the cleanup system satisfies the in-place penetration leakage testing acceptance criteria of less than 0.05% in accordance with ANSI N510-1980 for a halogenated hydrocarbon refrigerant test gas while operating the system at a flow rate of 4000 cfm +/- 10%.

g.

Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

Prior to exceeding 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , the compensatory measures described in HNP LAR correspondence letter RA-19-0007 shall be implemented.

SHEARON HARRIS - UNIT 1 3/4 7-30 Amendment No. 196 PLANT SYSTEMS 3/4.7.13 ESSENTIAL SERVICES CHILLED WATER SYSTEM LIMITING CONDITION FOR OPERATION 3.7.13 At least two independent Essential Services Chilled Water System loops shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

With only one Essential Services Chilled Water System loop OPERABLE, restore at least two loops to OPERABLE status within 7 days* or in accordance with the Risk-Informed Completion Time Program or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE REQUIREMENTS 4.7.13 The Essential Services Chilled Water System shall be demonstrated OPERABLE by:

a.

Performance of surveillances as required by the INSERVICE TESTING PROGRAM, and b.

At the frequency specified in the Surveillance Frequency Control Program by demonstrating that:

1.

Non-essential portions of the system are automatically isolated upon receipt of a Safety Injection actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and 2.

The system starts automatically on a Safety Injection actuation signal.

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 325 Renewed License No. NPF-9

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Carolinas, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment 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; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-9 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 325, are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:26:20 -05'00'

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-370 MCGUIRE NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 304 Renewed License No. NPF-17

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by the Duke Energy Carolinas, LLC (the licensee), dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Renewed Facility Operating License No. NPF-17 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 304 are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:27:11 -05'00'

ATTACHMENT TO DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 1 AMENDMENT NO. 325 RENEWED FACILITY OPERATING LICENSE NO. NPF-9 AND DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 2 AMENDMENT NO. 304 RENEWED FACILITY OPERATING LICENSE NO. NPF-17 Replace the following pages of the Renewed Facility Operating Licenses with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert NPF-9, Page 3 NPF-9, Page 3 NPF-17, Page 3 NPF-17, Page 3 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.6.10-2 3.6.10-2 3.7.9-4 3.7.9-4 3.7.11-2 3.7.11-2

Renewed License No. NPF-9 Amendment No. 325 (4)

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; (5)

Pursuant to the Act and 10 CFR Parts 30, 40 and 70, to possess, but not separate, such byproducts and special nuclear materials as may be produced by the operation of McGuire Nuclear Station, Units 1 and 2, and; (6)

Pursuant to the Act and 10 CFR Parts 30 and 40, to receive, possess and process for release or transfer such byproduct material as may be produced by the Duke Training and Technology Center.

C.

This renewed operating 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 The licensee is authorized to operate the facility at a reactor core full steady state power level of 3469 megawatts thermal (100%).

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 325, are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.

(3)

Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation. Duke shall complete these activities no later than June 12, 2021, 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 on December 16, 2002, described above, 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 renewed operating license Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59 and otherwise complies with the requirements in that section.

Renewed License No. NPF-17 Amendment No. 304 (4)

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; (5)

Pursuant to the Act and 10 CFR Parts, 30, 40 and 70, to possess, but not separate, such byproducts and special nuclear materials as my be produced by the operation of McGuire Nuclear Station, Units 1 and 2; and, (6)

Pursuant to the Act and 10 CFR Parts 30 and 40, to receive, possess and process for release or transfer such by product material as may be produced by the Duke Training and Technology Center.

C.

This renewed operating 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 thereafter in effect; and is subject to the additional conditions specified or incorporated below:

(1)

Maximum Power Level The licensee is authorized to operate the facility at a reactor core full steady state power level of 3469 megawatts thermal (100%).

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 304 are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Technical Specifications.

(3)

Updated Final Safety Analysis Report The Updated Final Safety Analysis Report supplement submitted pursuant to 10 CFR 54.21(d), as revised on December 16, 2002, describes certain future activities to be completed before the period of extended operation.

Duke shall complete these activities no later than March 3, 2023, 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 on December 16, 2002, described above, 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 renewed operating license.

Until that update is complete, Duke may make changes to the programs described in such supplement without prior Commission approval, provided that Duke evaluates each such change pursuant to the criteria set forth in 10 CFR 50.59, and otherwise complies with the requirements in that section.

AVS 3.6.10 McGuire Units 1 and 2 3.6.10-2 Amendment Nos. 325/304 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.10.1 Operate each AVS train for 15 continuous minutes.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.2 Perform required AVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be opened, except for valves that are locked, sealed, or otherwise secured in the open position.

In accordance with the Surveillance Frequency Control Program SR 3.6.10.5 Verify each AVS train flow rate is 7200 cfm and 8800 cfm.

In accordance with the Surveillance Frequency Control Program

CRAVS 3.7.9 McGuire Units 1 and 2 3.7.9-4 Amendment No. 325/304 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CRAVS train for 15 continuous minutes.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Perform required CRAVS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.9.3 Verify each CRAVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.4 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitability Program

NSWS B 3.7.7 McGuire Units 1 and 2 3.7.11-2 Amendment No. 325/304 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Operate each ABFVES for 15 minutes.

In accordance with the Surveillance Frequency Control Program SR 3.7.11.2 Perform required ABFVES filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.11.3 Verify each ABFVES actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.11.4 Verify one ABFVES can maintain a pressure

-0.125 inches water gauge in the ECCS pump room area relative to atmospheric pressure during the post accident mode of operation.

In accordance with the Surveillance Frequency Control Program

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-269 OCONEE NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 425 Renewed License No. DPR-38

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Carolinas, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 3.B of Renewed Facility Operating License No. DPR-38 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 425 are hereby incorporated into the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:27:50 -05'00'

DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-270 OCONEE NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 427 Renewed License No. DPR-47

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Carolinas, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment 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; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 3.B of Renewed Facility Operating License No. DPR-47 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 427 are hereby incorporated into the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:28:27 -05'00'

0 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-287 OCONEE NUCLEAR STATION, UNIT 3 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 426 Renewed License No. DPR-55

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Carolinas, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's rules and regulations as set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commissions regulations set forth in 10 CFR Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is hereby amended by page changes to the Technical Specifications as indicated in the attachment to this license amendment, and paragraph 3.B of Renewed Facility Operating License No. DPR-55 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 426 are hereby incorporated into the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating Licenses and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:29:02 -05'00'

ATTACHMENT TO DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-269 OCONEE NUCLEAR STATION, UNIT 1 AMENDMENT NO. 425 RENEWED FACILITY OPERATING LICENSE NO. DPR-38 AND DOCKET NO. 50-270 OCONEE NUCLEAR STATION, UNIT 2 AMENDMENT NO. 427 RENEWED FACILITY OPERATING LICENSE NO. DPR-47 AND DOCKET NO. 50-287 OCONEE NUCLEAR STATION, UNIT 3 AMENDMENT NO. 426 RENEWED FACILITY OPERATING LICENSE NO. DPR-55 Replace the following pages of the Renewed Facility Operating Licenses with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert DPR-38, Page 3 DPR-38, Page 3 DPR-47, Page 3 DPR-47, Page 3 DPR-55, Page 3 DPR-55, Page 3 Replace the following page of the Appendix A Technical Specifications with the attached revised page. The revised page is identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.7.9-3 3.7.9-3 Renewed License No. DPR-38 Amendment No. 425 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2610 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 425 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

C.

This license is subject to the following antitrust conditions:

Applicant makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants, such arrangements also serve the best interests of each of the participants. Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.

Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, applicant will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to applicant. There are net benefits in a transaction if applicant recovers the cost of the transaction (as defined in ¶1 (d) hereof) and there is no demonstrable net detriment to applicant arising from that transaction.

1.

As used herein:

(a)

Bulk Power means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.

(b)

Neighboring Entity means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of Renewed License No. DPR-47 Amendment No. 427 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2610 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 427 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

C.

This license is subject to the following antitrust conditions:

Applicant makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants, such arrangements also serve the best interests of each of the participants. Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.

Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, applicant will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to applicant. There are net benefits in a transaction if applicant recovers the cost of the transaction (as defined in ¶1 (d) hereof) and there is no demonstrable net detriment to applicant arising from that transaction.

1.

As used herein:

(a)

Bulk Power means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.

(b)

Neighboring Entity means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of Renewed License No. DPR-55 Amendment No. 426 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2610 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 426 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

C.

This license is subject to the following antitrust conditions:

Applicant makes the commitments contained herein, recognizing that bulk power supply arrangements between neighboring entities normally tend to serve the public interest. In addition, where there are net benefits to all participants, such arrangements also serve the best interests of each of the participants. Among the benefits of such transactions are increased electric system reliability, a reduction in the cost of electric power, and minimization of the environmental effects of the production and sale of electricity.

Any particular bulk power supply transaction may afford greater benefits to one participant than to another. The benefits realized by a small system may be proportionately greater than those realized by a larger system. The relative benefits to be derived by the parties from a proposed transaction, however, should not be controlling upon a decision with respect to the desirability of participating in the transaction. Accordingly, applicant will enter into proposed bulk power transactions of the types hereinafter described which, on balance, provide net benefits to applicant. There are net benefits in a transaction if applicant recovers the cost of the transaction (as defined in ¶1 (d) hereof) and there is no demonstrable net detriment to applicant arising from that transaction.

1.

As used herein:

(a)

"Bulk Power" means electric power and any attendant energy, supplied or made available at transmission or sub-transmission voltage by one electric system to another.

(b)

"Neighboring Entity" means a private or public corporation, a governmental agency or authority, a municipality, a cooperative, or a lawful association of any of the foregoing owning or operating, or proposing to own or operate, facilities for the generation and transmission of electricity which meets each of

CRVS Booster Fans 3.7.9 OCONEE UNITS 1, 2, & 3 3.7.9-3 Amendment Nos. 425, 427, & 426 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F.

Two CRVS Booster Fan trains inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

F.1 Restore one CRVS Booster Fan train to OPERABLE status.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months G.

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

G.1 Enter LCO 3.0.3.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CRVS Booster Fan train for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Perform required CRVS Booster Fan train filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.9.3 Verify the control room isolates on a manual actuation signal, except for dampers that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.4 Perform required CRE unfiltered air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitability Program (continued)

1 DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-261 H. B. ROBINSON STEAM ELECTRIC PLANT UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE NO. DPR-23 Amendment No. 272 Renewed License No. DPR-23

1.

The Nuclear Regulatory Commission (the Commission) has found that:

A.

The application for amendment by Duke Energy Progress, LLC (the licensee),

dated January 18, 2022, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commissions rules and regulations set forth in 10 CFR Chapter I; B.

The facility will operate in conformity with the application, the provisions of the Act, and the rules and regulations of the Commission; C.

There is reasonable assurance (i) that the activities authorized by this amendment 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; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Commissions regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifications, as indicated in the attachment to this license amendment; and paragraph 3.B. of Renewed Facility Operating License No. DPR-23 is hereby amended to read as follows:

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 272 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of the date of its issuance and shall be implemented within 120 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION David J. Wrona, Chief Plant Licensing Branch II-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License and Technical Specifications Date of Issuance: November 14, 2022 David J.

Wrona Digitally signed by David J. Wrona Date: 2022.11.14 15:29:46 -05'00'

ATTACHMENT TO DUKE ENERGY PROGRESS, LLC DOCKET NO. 50-261 H. B. ROBINSON STEAM ELECTRIC PLANT UNIT 2 AMENDMENT NO. 272 RENEWED FACILITY OPERATING LICENSE NO. DPR-23 Replace the following page of the Renewed Facility Operating License with the attached revised page. The revised page is identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert DPR-23, Page 3 DPR-23, Page 3 Replace the following pages of the Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Insert 3.6-21 3.6-21 3.7-24 3.7-24 Renewed Facility Operating License No. DPR-23 Amendment No. 272 D.

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 and equipment calibration or associated with radioactive apparatus or components; E.

Pursuant to the Act and 10 CFR Parts 30 and 70, to possess, but not separate, such byproduct and special nuclear materials as may be produced by operation of the facility.

3.

This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations: 10 CFR Part 20, Section 30.34 of 10 CFR Part 30, Section 40.41 of 10 CFR Part 40, Section 50.54 and 50.59 of 10 CFR Part 50, and Section 70.32 of 10 CFR Part 70; 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:

A.

Maximum Power Level The licensee is authorized to operate the facility at a steady state reactor core power level not in excess of 2339 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 272 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications.

(1)

For Surveillance Requirements (SRs) that are new in Amendment 176 to Final Operating License DPR-23, the first performance is due at the end of the first surveillance interval that begins at implementation of Amendment 176. For SRs that existed prior to Amendment 176, including SRs with modified acceptance criteria and SRs whose frequency of performance is being extended, the first performance is due at the end of the first surveillance interval that begins on the date the Surveillance was last performed prior to implementation of Amendment 176.

Isolation Valve Seal Water System 3.6.8 HBRSEP Unit No. 2 3.6-21 Amendment No. 272 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.8.3 Verify the opening time of each air operated header injection valve is within limits.

In accordance with the INSERVICE TESTING PROGRAM SR 3.6.8.4 Verify each automatic valve in the IVSW System actuates to the correct position on an actual or simulated actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.6.8.5 Verify the IVSW dedicated nitrogen bottles will pressurize the IVSW tank to 46.2 psig.

In accordance with the Surveillance Frequency Control Program SR 3.6.8.6 Verify total IVSW seal header flow rate is 124 cc/minute In accordance with the Surveillance Frequency Control Program

CREFS 3.7.9 HBRSEP Unit No. 2 3.7-24 Amendment No. 272 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H.

Required Action and associated Completion Time of Condition G not met in MODE 1, 2, 3, or 4.

H.1 Be in MODE 3.

AND H.2 Be in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CREFS train for 15 minutes.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Perform required CREFS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with VFTP SR 3.7.9.3 Verify each CREFS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.4 Perform required CRE maintenance and testing in accordance with the CRE Habitability Program.

In accordance with the CRE Habitability Program

2 November 14, 2022 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO TSTF-541, REVISION 2, ADD EXCEPTIONS TO SURVEILLANCE REQUIREMENTS FOR VALVES AND DAMPERS IN THE ACTUATED POSITION DUKE ENERGY CAROLINAS, LLC AND DUKE ENERGY PROGRESS, LLC BRUNSWICK STEAM ELECTRIC PLANT, UNIT NOS. 1 AND 2 AMENDMENT NOS. 310 AND 338 TO RENEWED FACILITY OPERATING LICENSE NOS. DPR-71 AND DPR-62, DOCKET NOS. 50-325 AND 50-324 CATAWBA NUCLEAR STATION, UNIT NOS. 1 AND 2 AMENDMENT NOS. 315 AND 311 TO RENEWED FACILITY OPERATING LICENSE NOS. NPF-35 AND NPF-52, DOCKET NOS. 50-413 AND 50-414 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT NO. 1 AMENDMENT NO. 196 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-63, DOCKET NO. 50-400 MCGUIRE NUCLEAR STATION, UNIT NOS. 1 AND 2 AMENDMENT NOS. 325 AND 304 TO RENEWED FACILITY OPERATING LICENSE NOS. NPF-9 AND NPF-17, DOCKET NOS. 50-369 AND 50-370 OCONEE NUCLEAR STATION, UNIT NOS. 1, 2, AND 3 AMENDMENT NOS. 425, 427, AND 426 TO RENEWED FACILITY OPERATING LICENSE NOS. DPR-38, DPR-47, AND DPR-55, DOCKET NOS. 50-269, 50-270, AND 50-287 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 AMENDMENT NO. 272 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-23, DOCKET NO. 50-261 Application (i.e., initial and supplements)

Safety Evaluation Date ADAMS Accession No. ML22018A236, January 18, 2022 November 14, 2022 Principal Contributor to Safety Evaluation R. Elliott, NRR

1.0 PROPOSED CHANGE

S Duke Energy Carolinas, LLC, and Duke Energy Progress, LLC (the licensee), requested changes to the technical specifications (TSs) for Brunswick Steam Electric Plant, Unit Nos. 1 and 2 (Brunswick), Catawba Nuclear Station, Unit Nos. 1 and 2 (Catawba), Shearon Harris Nuclear Power Plant, Unit No. 1 (Harris), McGuire Nuclear Station, Unit Nos. 1 and 2 (McGuire),

Oconee Nuclear Station, Unit Nos. 1, 2, and 3 (Oconee), and H. B. Robinson Steam Electric Plant, Unit No. 2 (Robinson) by license amendment request (LAR, application) dated January 18, 2022 (ML22018A236). The proposed amendments were based on Technical Specifications Task Force (TSTF) Traveler TSTF-541, Revision 2, Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position (TSTF-541) (Agencywide Documents Access and Management System (ADAMS) Accession No. ML19240A315), approved under the Consolidated Line Item Improvement Process (CLIIP)

(ML19323E928), and the associated Nuclear Regulatory Commission (NRC) staffs safety evaluation (SE) of TSTF-541 (ML19323E926). Section 1.1 of the NRC staffs SE of TSTF-541 discusses the reason for the proposed changes.

Limiting Conditions for Operation (LCOs) of a TS identify the lowest functional capability or performance level of equipment required for safe operation of the facility. Surveillance requirements (SRs) are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the LCOs will be met. Several existing SRs require the licensee to verify that each train of specified trains actuates on an actual or simulated actuation signal. When the trains actuate, valves and dampers within the trains will, if needed, reposition to their actuated position, which is the position appropriate to respond to the transient or accident that caused the actuation. The proposed amendment would add a phrase to each SR, as described in Section 1.2 of this SE, that would eliminate the need to verify that a damper or valve has repositioned if the damper or valve is secured in its actuated position.

1.1 System Descriptions The following provides the system descriptions for the affected SRs for each plant in the licensees LAR:

Brunswick Steam Electric Plant, Unit Nos. 1 and 2 The control room emergency ventilation (CREV) system provides a protected environment from which occupants can control the unit following an uncontrolled release of radioactivity, hazardous chemicals, or smoke. The purpose of SR 3.7.3.4 is to verify that each train/subsystem starts and operates on an actual or simulated actuation signal. The CREV system is the Brunswick equivalent to the main control room environmental control (MCREC) system LCO 3.7.4 in the approved TSTF-541.

The emergency core cooling system (ECCS) is designed to limit the release of radioactive materials to the environment following a loss-of-coolant accident (LOCA) and consists of the high pressure coolant injection system, the core spray system, the low pressure coolant injection mode of the residual heat removal (RHR) system, and the automatic depressurization system. The purpose of SR 3.5.1.9 is to verify the automatic initiation logic of high pressure coolant injection, core spray, and low pressure coolant injection will cause the systems or subsystems to operate as designed, including actuation of the system throughout its emergency operating sequence, automatic pump startup, and actuation of all automatic valves to their required positions on receipt of an actual or simulated actuation signal. SR 3.5.1.9 is the Brunswick equivalent to SR 3.5.1.10 in the approved TSTF-541.

The service water (SW) system and ultimate heat sink (UHS) are designed to provide cooling water for the removal of heat from equipment, such as the diesel generators, RHR pump coolers and heat exchangers, and room coolers for ECCS equipment, required for a safe reactor shutdown following a design-basis accident (DBA) or transient. The SW system and UHS also provide cooling to unit components, as required, during normal operation and shutdown modes. During a DBA, the equipment required only for normal operation is isolated and cooling is directed to only safety-related equipment. The purpose of SR 3.7.2.5 is to verify the systems will automatically switch to the position to provide cooling water exclusively to safety-related equipment during an accident. The SW system and UHS are the Brunswick equivalent to the plant service water (PSW) system and UHS LCO 3.7.2 in the approved TSTF-541.

The function of the reactor core isolation cooling (RCIC) system is to respond to transient events by providing makeup coolant to the reactor. The purpose of SR 3.5.3.5 is to verify the system operates as designed, including actuation of the system throughout its emergency operating sequence; that is, automatic pump startup and actuation of all automatic valves to their required positions on receipt of an actual or simulated actuation signal.

The function of the standby gas treatment (SGT) system is to ensure that radioactive materials that leak from the primary containment into the secondary containment following a DBA are filtered and adsorbed prior to exhausting to the environment. The purpose of SR 3.6.4.3.3 is to verify that each SGT subsystem starts on receipt of an actual or simulated initiation signal.

The licensee also requested to apply TSTF-541 to the reactor pressure vessel (RPV) water inventory control LCO which was not included in the scope of TSTF-541. RPV water level must be controlled in MODES 4 and 5 to ensure that if an unexpected draining event should occur, the reactor coolant water level remains above the top of the active irradiated fuel (TAF) as required by Reactor Core Safety Limit TS 2.1.1.3. The LCO for RPV Water Inventory Control requires the drain time of RPV water inventory to the TAF to be 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A drain time of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months is considered reasonable to identify and initiate action to mitigate unexpected draining of reactor coolant. An event that could cause loss of RPV water inventory and result in the RPV water level reaching the TAF in greater than 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months does not represent a significant challenge to TS 2.1.1.3 and can be managed as part of normal plant operation. The purpose of SR 3.5.2.6 is to verify that each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated RPV water level isolation signal.

Catawba Nuclear Station, Unit Nos. 1 and 2 The annulus ventilation system (AVS) is required to ensure that radioactive materials that leak from the primary containment into the shield building (secondary containment) following a DBA are filtered and adsorbed prior to exhausting to the environment. The containment has a secondary containment called the shield building, which is a concrete structure that surrounds the steel primary containment vessel. Between the containment vessel and the shield building inner wall is an annular space that collects any containment leakage that may occur following a LOCA or rod ejection accident. The AVS establishes a negative pressure in the annulus between the shield building and the steel containment vessel. Filters in the system then control the release of radioactive contaminants to the environment. The AVS consists of two separate and redundant trains. Each train includes a heater, cooling coils, a prefilter, moisture separators, a high-efficiency particulate air (HEPA) filters, an activated charcoal adsorber section for removal of radioiodines, and a fan. Ductwork, valves and/or dampers, and instrumentation also form part of the system. The system initiates and maintains a negative air pressure in the shield building by means of filtered exhaust ventilation of the shield building following receipt of a safety injection signal. The purpose of SR 3.6.10.3 is to verify proper actuation of all train components, including dampers, on an actual or simulated actuation signal. The purpose of SR 3.6.10.4 is to ensure that the system is functioning properly by operating the filter bypass valve. The AVS is the Catawba equivalent to the shield building air cleanup system (SBACS)

LCO 3.6.13 in the approved TSTF-541.

The control room area ventilation system (CRAVS) ensures that the control room envelope (CRE) will remain habitable for occupants during and following all credible accident conditions.

The purpose of SR 3.7.10.3 is to verify that each train/subsystem starts and operates on an actual or simulated actuation signal. The CRAVS is the Catawba equivalent to the control room emergency filtration system (CREFS) LCO 3.7.10 in the approved TSTF-541.

The auxiliary building filtered ventilation exhaust system (ABFVES) limits radioactive release from the ECCS pump rooms to within the Title 10 of the Code of Federal Regulations (10 CFR) 50.67 limits following a LOCA. Ductwork, valves or dampers, and instrumentation also form part of the system, as well as demisters functioning to reduce the relative humidity of the air stream.

During emergency operations, the ABFVES dampers are realigned, and fans are started to begin filtration, normal air discharges from the ECCS pump room are isolated, and the stream of ventilation air is drawn from the ECCS pump rooms, as well as the elevation 522 ft. pipe chase, and elevation 543 ft. and 560 ft. mechanical penetration rooms, and discharged through the system filter trains. The prefilters or demisters remove any large particles in the air, and any entrained water droplets present, to prevent excessive loading of the HEPA filters and charcoal adsorbers. The purpose of SR 3.7.12.3 is to verify that each ABFVES train starts and operates with flow through the HEPA filters and carbon adsorbers on an actual or simulated actuation signal. The ABFVES is the Catawba equivalent to the ECCS penetration room air cleanup LCO 3.7.12 in the approved TSTF-541.

The licensee also requested to apply TSTF-541 to the containment valve injection water system (CVIWS), a plant-specific technical specification that is not included in the approved TSTF-541.

The CVIWS provides a water seal to double disc gate valves during a loss of coolant accident (LOCA) to prevent leakage of containment atmosphere through the valves. The system functions by injecting water at a higher pressure than the LOCA containment peak pressure between the two seating surfaces of double disc gate valves, preventing leakage of the containment atmosphere through the gate valves. The CVIWS does not perform any function during normal power operation. The purpose of SR 3.6.17.3 is to verify each automatic CVIWS valve actuates to its correct position on an actual or simulated actuation signal.

H. B. Robinson Steam Electric Plant, Unit No. 2 The control room emergency filtration system (CREFS) provides a protected environment from which occupants can control the unit following an uncontrolled release of radioactivity, hazardous chemicals, or smoke. The purpose of SR 3.7.9.3 is to verify that each train/subsystem starts and operates on an actual or simulated actuation signal.

The licensee also requested to apply TSTF-541 to the isolation valve seal water (IVSW) system, a plant-specific TS 3.6, that was not included in the approved TSTF-541. As stated in the LAR, the IVSW system assures the effectiveness of certain containment isolation valves during any condition which requires containment isolation, by providing a water seal at the valves. The system provides a reliable means for injecting seal water between the seats and stem packing of the globe and double disc types of isolation valves, and into the piping between other closed isolation valves. The system provides assurance that, should an accident occur, the containment leak rate is no greater than that assumed in the accident analysis. The purpose of SR 3.6.8.4 is to verify that each automatic valve in the IVSW system actuates to the correct position on an actual or simulated actuation signal.

McGuire Nuclear Station, Unit Nos. 1 and 2 The AVS is required to ensure that radioactive materials that leak from the primary containment into the shield building (secondary containment) following a DBA are filtered and adsorbed prior to exhausting to the environment. The containment has a secondary containment called the shield building, which is a concrete structure that surrounds the steel primary containment vessel. Between the containment vessel and the shield building inner wall is an annular space that collects any containment leakage that may occur following a LOCA or rod ejection accident.

The AVS establishes a negative pressure in the annulus between the shield building and the steel containment vessel. Filters in the system then control the release of radioactive contaminants to the environment. The AVS consists of two separate and redundant trains. Each train includes a heater, cooling coils, a prefilter, moisture separators, a HEPA filters, an activated charcoal adsorber section for removal of radioiodines, and a fan. Ductwork, valves and/or dampers, and instrumentation also form part of the system. The system initiates and maintains a negative air pressure in the shield building by means of filtered exhaust ventilation of the shield building following receipt of a safety injection signal. The purpose of SR 3.6.10.3 is to verify proper actuation of all train components, including dampers, on an actual or simulated actuation signal. The purpose of SR 3.6.10.4 is to ensure that the system is functioning properly by operating the filter bypass valves. The AVS is the McGuire equivalent to the SBACS LCO 3.6.13 in the approved TSTF-541.

The CRAVS ensures that the CRE will remain habitable for occupants following an uncontrolled release of radioactivity, hazardous chemicals, or smoke. The purpose of SR 3.7.9.3 is to verify that each train/subsystem starts and operates on an actual or simulated actuation signal. The CRAVS is the McGuire equivalent to the CREFS LCO 3.7.10 in the approved TSTF-541.

The ABFVES limits radioactive release from the ECCS pump rooms to within 10 CFR 50.67, Accident source term, limits following a LOCA. The ABFVES, in conjunction with other normally operating systems, also provides environmental control of temperature and humidity in the ECCS pump room area and the auxiliary building. Ductwork, valves or dampers, and instrumentation also form part of the system, as well as demisters functioning to reduce the relative humidity of the air stream. During emergency operations, the ABFVES dampers are realigned, and fans are started to begin filtration, and air is drawn from the ECCS pump rooms and the mechanical penetration area. and discharged through the system filters. The prefilters remove any large particles in the air, and any entrained water droplets present, to prevent excessive loading of the HEPA filters and charcoal adsorbers. The purpose of SR 3.7.11.3 is to verify that each ABFVES train starts and operates with flow through the HEPA filters and carbon adsorbers on an actual or simulated actuation signal. The ABFVES is the McGuire equivalent to the ECCS penetration room air cleanup system LCO 3.7.12 in the approved TSTF-541.

Oconee Nuclear Station, Unit Nos. 1, 2, and 3 The control room ventilation system (CRVS) booster fans provide a protected environment from which occupants can control the unit following an uncontrolled release of radioactivity, hazardous chemicals, or smoke. The purpose of SR 3.7.9.3 is to verify that the control room envelope isolates on a manual actuation signal. The CRVS is the Oconee equivalent to the CREVS LCO 3.7.10 in the approved TSTF-541.

Shearon Harris Nuclear Power Plant, Unit No. 1 The CREFS provides a protected environment from which occupants can control the unit following an uncontrolled release of radioactivity, hazardous chemicals, or smoke. The purpose of SR 4.7.6.d.2 is to verify the system automatically switches into an isolation with recirculation mode of operation with flow through the HEPA filters and charcoal adsorber banks that on either a safety injection or a high radiation test signal.

The licensee requested TSTF-541 changes be applied for the following systems that: 1) were not included in TSTF-541; 2) have SRs similar to those that are affected by TSTF-541; 3) already have an exception for valves and dampers that are locked, sealed, or otherwise secured in the actuated position for the equivalent SRs in the standard technical specifications (STS);

and 4) do not have this exception in the Harris SRs:

The containment spray system ensures that containment depressurization and cooling capability will be available in the event of a LOCA or steam line break. The containment spray system also provides a mechanism for removing iodine from the containment atmosphere. The purpose of SR 4.6.2.1.c.1 is to verify that each automatic valve in the containment spray flowpath actuates to its correct position on a containment spray actuation signal. The purpose of SR 4.6.2.1.c.3 is to verify that coincident with an indication of containment spray pump running, each automatic valve from the sump and the refueling water storage tank (RWST) actuates to their appropriate position following a RWST lo-lo test signal.

The spray additive system ensures that sufficient sodium hydroxide (NaOH) is added to the containment spray in the event of a LOCA. The limits on NaOH volume and concentration ensure a pH value of between 7.0 and 11.0 for the solution recirculated within containment after a LOCA. This pH band minimizes the evolution of iodine and minimizes the effect of chloride and caustic stress corrosion on mechanical systems and components. The purpose of SR 4.6.2.2.c is to verify that each automatic valve in the spray additive system flowpath actuates to their correct position on a containment spray or containment isolation phase A test signal.

The component cooling water system ensures that sufficient cooling capacity is available for continued operation of safety-related equipment during normal and accident conditions. The purpose of SR 4.7.3.b.1 is to verify that each automatic valve servicing safety-related equipment or isolating nonsafety related components actuates to its correct position on a safety injection test signal. The purpose of SR 4.7.3.b.3 is to verify that each automatic valve serving the gross failed fuel detector and sample system heat exchangers actuates to its correct position on a low surge tank level test signal.

The emergency service water system ensures that sufficient cooling capacity is available for continued operation of safety-related equipment during normal and accident conditions. The purpose of SR 4.7.4.b.1 is to verify that each automatic valve servicing safety-related equipment or isolating non-safety portions of the system actuates to its correct position on a safety injection test signal.

In addition, the licensee requested to apply TSTF-541 to the essential services chilled water system, a plant-specific technical specification (LCO 3/4.7.13) not included in TSTF-541. As stated in the LAR, the essential services chilled water system ensures that sufficient cooling capacity is available for continued operation of safety related equipment during normal and accident conditions. The Westinghouse plant STS has no equivalent TS, but the Harris TS is similar to STS LCO 3.7.8, Service Water System. STS SRs 3.7.8.1 and 3.7.8.2 that contain allowances similar to the allowance in the approved TSTF-541. The purpose of SR 4.7.13.b.1 is to verify that non-essential portions of the system are automatically isolated upon receipt of a safety injection actuation signal.

1.2 Description of Proposed Changes to Adopt TSTF 541 In accordance with NRC staff-approved TSTF-541, the licensee proposed to revise certain SRs by adding exceptions to the SRs for automatic valves or dampers that are locked, sealed or, otherwise secured in the actuated position. The proposed revisions, therefore, allow the licensee to meet the LCOs without having to test for actuation those values or dampers that are already secured in the actuated position. Specifically, each licensee proposed the following changes to adopt TSTF-541. The proposed new text is shown in italics.

Brunswick Steam Electric Plant, Unit Nos. 1 and 2 SR 3.5.1.9 Verify each ECCS injection/spray subsystem actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SR 3.5.3.5 Verify the RCIC System actuates on an actual or simulated automatic initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SR 3.6.4.3.3 Verify each SGT subsystem actuates on an actual or simulated initiation signal, except for dampers that are locked, sealed, or otherwise secured in the actuated position.

SR 3.7.2.5 Verify each required SW System automatic component actuates on an actual or simulated initiation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SR 3.7.3.4 Verify each CREV subsystem actuates on an actual or simulated initiation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

Catawba Nuclear Station, Unit Nos. 1 and 2 SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the open position.

SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be opened, except for valves that are locked, sealed, or otherwise secured in the open position.

SR 3.7.10.3 Verify each CRAVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

SR 3.7.12.3 Verify each ABFVES train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

H. B. Robinson Steam Electric Plant, Unit No. 2 SR 3.7.9.3 Verify each CREFS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

McGuire Nuclear Station, Unit Nos. 1 and 2 SR 3.6.10.3 Verify each AVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the open position.

SR 3.6.10.4 Verify each AVS filter cooling bypass valve can be opened, except for valves that are locked, sealed, or otherwise secured in the open position.

SR 3.7.9.3 Verify each CRAVS train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

SR 3.7.11.3 Verify each ABFVES train actuates on an actual or simulated actuation signal, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position.

Oconee Nuclear Station, Unit Nos. 1, 2, and 3 SR 3.7.9.3 Verify the control room isolates on a manual actuation signal, except for dampers that are locked, sealed, or otherwise secured in the actuated position.

Shearon Harris Nuclear Power Plant, Unit No. 1 SR 4.7.6.d.2 requires each CREFS train shall be demonstrated OPERABLE by Verifying that, on either a Safety Injection or a High Radiation test signal, the system automatically switches into an isolation with recirculation mode of operation with flow through the HEPA filters and charcoal adsorber banks, except for dampers and valves that are locked, sealed, or otherwise secured in the actuated position;[]

1.3 Additional Proposed TS Changes In addition to the changes proposed consistent with the traveler discussed in Section 1.1, the licensee proposed the following variations.

1.3.1 Editorial Variations The licensee noted that all facilities within the LAR have different numbering and titles than standard technical specifications (STSs).

The licensee noted that the Oconee TSs contain requirements that differ from the STS on which TSTF-541 was based. The licensee stated that the proposed Oconee SR 3.7.9.3 and the associated Bases refer only to automatic dampers, not automatic valves and dampers as in TSTF-541. The Oconee CRVS booster fans components tested by the SR do not include valves. Therefore, the licensees proposed changes only refer to dampers that have been locked in the actuated position.

The licensee described in Section 2.2 of the LAR the TS systems for each plant where the plant TSs do not include an SR equivalent to one that was included in TSTF-541. The licensee did not propose changes for those SRs in the LAR.

1.3.2 Other Variations The licensee proposed the following additional changes not included in TSTF-541 for each plant. The changes are shown in italics:

Brunswick Steam Electric Plant, Unit Nos. 1 and 2 SR 3.5.2.6 (RPV Water Inventory Control) Verify each valve credited for automatically isolating a penetration flow path actuates to the isolation position on an actual or simulated isolation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

This SR was added to the STS by the approved TSTF-542 which had not been incorporated into the STS at the time TSTF-541 was developed.

Catawba Nuclear Station, Unit Nos. 1 and 2 SR 3.6.17.3 (CVIWS) Verify each automatic valve actuates to its correct position on an actual or simulated actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

H. B. Robinson Steam Electric Plant, Unit No. 2 SR 3.6.8.4 (Isolation Valve Seal Water System) Verify each automatic valve in the IVSW System actuates to the correct position on an actual or simulated actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

Shearon Harris Nuclear Power Plant, Unit No. 1 SR 4.6.2.1.c.1 requires each containment spray system to be demonstrated OPERABLE by Verifying that each automatic valve in the flow path actuates to its correct position on a containment spray actuation test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and []

SR 4.6.2.1.c.3 requires each Containment Spray System shall be demonstrated OPERABLE by Verifying that, coincident with an indication of containment spray pump running, each automatic valve from the sump and RWST actuates to its appropriate position following an RWST Lo-Lo test signa, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SR 4.6.2.2.c requires the Spray Additive System shall be demonstrated OPERABLE At the frequency specified in the Surveillance Frequency Control Program by verifying that each automatic valve in the flow path actuates to its correct position on a containment spray or containment isolation phase A test signal as applicable; except for valves that are locked, sealed, or otherwise secured in the actuated position, and []

SR 4.7.3.b.1 requires at least two component cooling water flow paths shall be demonstrated OPERABLE by Each automatic valve servicing safety-related equipment or isolating nonsafety-related components actuates to its correct position on a Safety Injection test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and []

SR 4.7.3.b.3 requires at least two component cooling water flow paths shall be demonstrated OPERABLE by verifying that Each automatic valve serving the gross failed fuel detector and sample system heat exchangers actuates to its correct position on a Low Surge Tank Level test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position.

SR 4.7.4.b.1 requires at least two emergency service water loops shall be demonstrated OPERABLE by verifying that Each automatic valve servicing safety-related equipment or isolating non-safety portions of the system actuates to its correct position on a Safety Injection test signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and []

SR 4.7.13.b.1 requires the Essential Services Chilled Water System shall be demonstrated OPERABLE by demonstrating that Non-essential portions of the system are automatically isolated upon receipt of a Safety Injection actuation signal, except for valves that are locked, sealed, or otherwise secured in the actuated position, and []

2.0 REGULATORY EVALUATION

The regulation under 10 CFR 50.36(b) requires that:

Each license authorizing operation of a utilization facility will include technical specifications. The technical specifications will be derived from the analyses and evaluation included in the safety analysis report, and amendments thereto, submitted pursuant to [10 CFR] 50.34 [Contents of applications; technical information.] The Commission may include such additional technical specifications as the Commission finds appropriate.

Additionally, under 10 CFR 50.92(a), in determining whether an amendment to a license will be issued to the applicant, the Commission will be guided by the considerations which govern the issuance of initial licenses to the extent applicable and appropriate. The considerations for issuance of operating licenses in 10 CFR 50.57(a)(3) provide that there must be reasonable assurance that the activities at issue will not endanger the health and safety of the public.

The LAR asks for changes to SRs, which are controlled by 10 CFR 50.36(c)(3) (saying that SRs are requirements relating to test, calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the LCOs will be met). Accordingly, the amended SRs that no longer require verification of valves and dampers already in, and secured in, their actuated positions, must continue to meet the LCOs and the other standards of 10 CFR 50.36(c)(3).

The NRC staffs guidance for the review of TSs is in Chapter 16.0, Technical Specifications, of NUREG-0800, Revision 3, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR [Light-Water Reactor] Edition (SRP), March 2010 (ML100351425).

As described therein, as part of the regulatory standardization effort, the NRC staff has prepared STSs for each of the LWR nuclear designs. Accordingly, the NRC staffs review includes consideration of whether the proposed changes are consistent with the applicable STSs (i.e., the current STSs), as modified by NRC-approved travelers. The current STSs that are applicable to the facilities are:

NUREG-1430, Standard Technical Specifications, Babcock and Wilcox Plants, Volume 1, Specifications, and Volume 2, Bases, Revision 5.0, dated September 2021 (ML21272A363 and ML21272A370, respectively).

NUREG-1431, Standard Technical Specifications, Westinghouse Plants, Volume 1, Specifications, and Volume 2, Bases, Revision 5.0, dated September 2021 (ML21259A155 and ML21259A159, respectively).

NUREG-1433, Standard Technical Specifications, General Electric BWR/4 Plants, Volume 1, Specifications, and Volume 2, Bases, Revision 5.0, dated September 2021 (ML21272A357 and ML21272A358, respectively).

3.0 TECHNICAL EVALUATION

3.1 Proposed TS Changes to Adopt TSTF-541 The NRC staff compared the licensees proposed TS changes in Section 1.2 of this SE against the changes approved in TSTF-541 for Catawba, Robinson, McGuire, and Harris. In accordance with Chapter 16.0 of the SRP, the NRC staff determined that the STS changes approved in TSTF-541 are applicable to the TSs for Catawba, Unit Nos. 1 and 2, Robinson, Unit No. 2, McGuire, Unit Nos. 1 and 2, and Harris, Unit No. 1. They apply to these facilities because they are Westinghouse plant designs and the NRC staff approved the TSTF-541 changes for Westinghouse designs. Therefore, the NRC staff concludes that the licensees proposed changes to the TSs in Section 1.2 of this SE for these facilities are consistent with TSTF-541.

Similarly, the NRC staff compared the licensees proposed TS changes in Section 1.2 of this SE against the changes approved in TSTF-541 for Brunswick, Unit Nos. 1 and 2. In accordance with Chapter 16.0 of the SRP, the NRC staff determined that the STS changes approved in TSTF-541 are applicable to the TSs for Brunswick, Unit Nos. 1 and 2, because they are General Electric BWR4 plant designs and the NRC staff approved the TSTF-541 changes for General Electric designs. Therefore, the NRC staff concludes that the licensees proposed changes to the TSs in Section 1.2 of this SE for Brunswick, Unit Nos. 1 and 2, are consistent with TSTF-541.

The NRC staff also compared the licensees proposed TS changes in Section 1.2 of this SE against the changes approved in TSTF-541 for Oconee, Unit Nos. 1, 2, and 3. In accordance with Chapter 16.0 of the SRP, the NRC staff determined that the STS changes approved in TSTF-541 are applicable to the TSs for Oconee, Unit Nos. 1, 2, and 3, because they are Babcock and Wilcox (B&W) design plants and the NRC staff approved the TSTF-541 changes for B&W designs. Therefore, the NRC staff concludes that the licensees proposed changes to the TSs in Section 1.2 of this SE for Oconee, Unit Nos. 1, 2, and 3, are consistent with TSTF-541.

As defined in STS 1.1 for the STSs listed in Section 2.0 above, a train shall be operable:

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).

The proposed SRs would exclude the need to verify actuation of dampers and valves that do not, in fact, actuate (e.g., change position) in response to an actuation signal. The licensees LAR contains the following statements:

While the proposed exceptions permit automatic valves and dampers that are locked, sealed, or otherwise secured in the actuated position to be excluded from the SR in order to consider the SR met, the proposed changes will not permit a system that is made inoperable by locking, sealing, or otherwise securing an automatic valve or damper in the actuated position to be considered operable. As discussed in the SR 3.0.1 Bases (4.0.1 Bases for HNP [Harris]), nothing in this Specification, however, is to be construed as implying that systems or components are operable when the systems or components are known to be inoperable, although still meeting the SRs.

Duke Energy acknowledges that under the proposed change, the affected valves and dampers may be excluded from the SR when locked, sealed or otherwise secured in the actuated position.

However, if the safety analysis assumes movement from the actuated position following an event, or the system is rendered inoperable by locking, sealing, or otherwise securing the valve or damper in the actuated position, then the system cannot perform its specified safety function and is inoperable regardless of whether the SR is met.

Duke Energy acknowledges for components for which the SR allowance can be utilized, the SR must be verified to have been met within its required Frequency after removing the valve or damper from the locked, sealed or otherwise secured status. If the SR exception is utilized to not test the actuation of a valve or damper and the specified Frequency of the SR is exceeded without testing the component, the SR must be performed on the component when it is returned to service in order to meet the SR.

Given the statements provided on the docket to adopt TSTF-541, the NRC staff determined that there is reasonable assurance that the licensee will continue to properly control affected equipment in accordance with existing regulations and requirements when using the exceptions added to the respective SRs.

The NRC staff finds that it is not necessary to verify actuation of valves and dampers that are already in their actuated positions, and are locked, sealed, or otherwise secured in those position, because the amended SRs will continue to require the licensee to verify that valves and dampers that must actuate perform their safety functions and support functions by being able to change position.

Therefore, the NRC staff determined that the amended TSs and revised SRs for Brunswick, Unit Nos. 1 and 2, Catawba, Unit Nos. 1 and 2, Robinson, Unit No. 2, McGuire, Unit Nos. 1 and 2, Oconee, Unit Nos. 1, 2, and 3, and Harris, Unit No. 1, will continue to meet the LCOs and other standards of 10 CFR 50.36(c)(3) as discussed in Section 3.0 of the NRC staffs SE of TSTF-541.

3.2 Additional Proposed TS Changes 3.2.1 Editorial The licensee noted that the TSs for all facilities included in the LAR have different numbering and titles than STS. The NRC staff reviewed the different TS numbering and title changes and determined that they do not substantively alter TS requirements. The NRC staff finds that the different TS numbering and title changes are acceptable because they do not substantively alter TS requirements.

The licensee noted that the Oconee TSs contain requirements that differ from the STS on which TSTF-541 was based. The licensee stated that the proposed Oconee SR 3.7.9.3 and the associated Bases refer only to automatic dampers, not automatic valves and dampers as in TSTF-541. The NRC staff finds that the lack of valves in a system does not impact the applicability of the TSTF-541 changes to the system dampers because the Oconee CRVS booster fans components tested by the SR do not include valves. Therefore, the licensees proposed changes only refer to dampers that have been locked in the actuated position. In addition, this change does not substantively change the TS requirements; therefore, this change is acceptable.

3.2.2 Other Variations The changes in Section 1.3.2 of this SE fall into two categories. First, the licensees requested TS changes for Harris for SRs that in the STS have the same allowance provided in the approved TSTF-541, and as a result, were not included in the scope of TSTF-541. The specific changes that fall into this category include the requested changes to Harris SRs 4.6.2.1.c.1, 4.6.2.1.c.3, 4.6.2.2.c, 4.7.3.b.1, 4.7.3.b.3, and 4.7.4.b.1. The NRC staff compared these proposed TS changes against the changes approved in TSTF 541 and the equivalent SRs in the STS. In accordance with the Chapter 16.0 of the SRP, the NRC staff determined that the changes requested to these SRs for Harris are applicable to their TSs and consistent with the STS for Westinghouse Plants. The technical and regulatory basis for these changes are also consistent with TSTF-541.

The second category of changes proposed by the licensee that are described in Section 1.3.2 of this SE are to allow the TSTF-541 exceptions to be applied to SRs not included in the scope of TSTF-541 and do not have a similar allowance to that provided by TSTF-541 in the STS. The proposed SRs include both SRs that are included in the STS and plant-specific SRs that are not in the STS. The changes that fall into this category include the licensees proposed revisions to:

1) SR 3.5.2.6 (Reactor Pressure Vessel Water Inventory Control) for Brunswick, 2) SR 3.6.17.3 (Containment Valve Injection Water System) for Catawba, 3) SR 3.6.8.4 (Isolation Valve Seal Water) for Robinson, and 4) SR 4.7.13.b.1 (Essential Chilled Water System) for Harris.

The NRC staff determined that these SRs are similar to the type of SRs included in TSTF-541, and the proposed changes are equivalent. Specifically, the proposed changes to these SRs would exclude the need to verify actuation or repositioning of valves that do not that do not need to actuate or reposition to perform their safety function in response to an actuation signal because they are secured in a position where they are already performing their safety function.

The amended SRs would still require the licensee to verify that the affected valves and dampers that must reposition to perform their safety functions and support functions are able to change position when they are not locked in their actuated position.

The NRC staff reviewed the justification provided in TSTF-541, and the associated NRC staff SE, and found that it was equally applicable to the proposed changes to these SRs. Therefore, the proposed changes are acceptable to the NRC staff for the same reasons discussed in Section 3.1 of this SE. Specifically, the NRC staff finds that it is not necessary to verify actuation or repositioning of valves that are locked, sealed, or otherwise secured in their actuated positions for the following SRs:

Brunswick, Unit Nos. 1 and 2: SR 3.5.2.6 (Reactor Pressure Vessel Water Inventory Control)

Catawba, Unit Nos. 1 and 2: SR 3.6.17.3 (Containment Valve Injection Water System)

Robinson, Unit No. 2: SR 3.6.8.4 (Isolation Valve Seal Water)

Harris, Unit No. 1: SRs 4.6.2.1.c.1 and 4.6.2.1.c.3 (Containment Spray System); SR 4.6.2.2.c (Spray Additive System); SRs 4.7.3.b.1 and 4.7.3.b.3 (Component Cooling Water); SR 4.7.4.b.1 (Emergency Service Water); and SR 4.7.13.b.1 (Essential Services Chilled Water System).

Therefore, the NRC staff determined that the amended TSs and revised SRs for Brunswick, Unit Nos. 1 and 2, Catawba, Unit Nos. 1 and 2, Robinson, Unit No. 2, McGuire, Unit Nos. 1 and 2, Oconee, Unit Nos. 1, 2, and 3, and Harris, Unit No. 1, will continue to meet the LCOs and the other standards of 10 CFR 50.36(c)(3).

3.3 TS Change Consistency The NRC staff reviewed the proposed TS changes for technical clarity and consistency with the existing requirements for customary terminology and formatting. The NRC staff finds that the proposed changes are consistent with the terminology and formatting requirements of Chapter 16.0 of the SRP and are therefore acceptable.

4.0 CONCLUSION

The Commission has concluded, based on the considerations discussed above, that: (1) there is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner, (2) there is reasonable assurance that such activities will be conducted in compliance with the Commissions regulations, and (3) the issuance of the amendments will not be inimical to the common defense and security or to the health and safety of the public.

NOTICES AND ENVIRONMENTAL FINDINGS RELATED TO BRUNSWICK STEAM ELECTRIC PLANT, UNIT NOS. 1 AND 2 AMENDMENT NOS. 310 AND 338 TO RENEWED FACILITY OPERATING LICENSE NOS. DPR-71 AND DPR-62, DOCKET NOS. 50-325 AND 50-324 CATAWBA NUCLEAR STATION, UNIT NOS. 1 AND 2 AMENDMENT NOS. 315 AND 311 TO RENEWED FACILITY OPERATING LICENSE NOS. NPF-35 AND NPF-52, DOCKET NOS. 50-413 AND 50-414 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT NO. 1 AMENDMENT NO. 196 TO RENEWED FACILITY OPERATING LICENSE NO. NPF-63, DOCKET NO. 50-400 MCGUIRE NUCLEAR STATION, UNIT NOS. 1 AND 2 AMENDMENT NOS. 325 AND 304 TO RENEWED FACILITY OPERATING LICENSE NOS. NPF-9 AND NPF-17, DOCKET NOS. 50-369 AND 50-370 OCONEE NUCLEAR STATION, UNIT NOS. 1, 2, AND 3 AMENDMENT NOS. 425, 427, AND 426 TO RENEWED FACILITY OPERATING LICENSE NOS. DPR-38, DPR-47, AND DPR-55, DOCKET NOS. 50-269, 50-270, AND 50-287 H. B. ROBINSON STEAM ELECTRIC PLANT, UNIT NO. 2 AMENDMENT NO. 272 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-23, DOCKET NO. 50-261 Application (i.e., initial and supplements)

Safety Evaluation Date ADAMS Accession No. ML22018A236, January 18, 2022 November 14, 2022

1.0 INTRODUCTION

Duke Energy Carolinas, LLC, and Duke Energy Progress, LLC (Duke Energy, the licensee),

requested changes to the technical specifications (TSs) for Brunswick Steam Electric Plant, Unit Nos 1 and 2, Catawba Nuclear Station, Unit No. 1 and 2, Shearon Harris Nuclear Power Plant, Unit No. 1, McGuire Nuclear Station, Unit Nos. 1 and 2, Oconee Nuclear Station, Unit No. 1, 2, and 3, and H.B. Robinson Steam Electric Plant, Unit No. 2, by license amendment request (LAR, application). In its application, Duke Energy requested that the U.S. Nuclear Regulatory Commission (NRC, the Commission) process the proposed amendment under the Consolidated Line Item Improvement Process (CLIIP). The proposed amendments are based on Technical Specifications Task Force (TSTF) Traveler TSTF-541, Revision 2, Add Exceptions to Surveillance Requirements for Valves and Dampers Locked in the Actuated Position (TSTF-541) (ML19240A315), and the associated NRC staff safety evaluation (SE) of TSTF-541 (ML19323E926).

2.0 STATE CONSULTATION

In accordance with the Commission's regulations, the North Carolina and South Carolina State officials were notified of the proposed issuance of the amendment on September 9, 2022. The State officials had no comments.

3.0 ENVIRONMENTAL CONSIDERATION

The amendments change requirements with respect to the installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and change SRs.

The NRC staff has determined that the amendment involves no significant increase in the amounts, and no significant change in the types, of any effluents that may be released offsite, and that there is no significant increase in individual or cumulative occupational radiation exposure. The Commission has previously issued a proposed finding that the amendment involves no significant hazards consideration, and there has been no public comment on such finding published in the Federal Register on February 22, 2022 (86 FR 9647). Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9).

Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

ML22256A253 OFFICE NRR/DORL/LPL2-2/PM NRR/DORL/LPL2-2/LA NRR/DSS/STSB/BC NAME LHaeg RButler VCusumano DATE 09/13/2022 09/22/2022 08/31/2022 OFFICE OGC - NLO NRR/DORL/LPL2-2/BC NRR/DORL/LPL2-2/PM NAME BAyersman DWrona LHaeg DATE 10/24/2022 11/10/2022 11/14/2022

v t e Letter Sequence Approval
EPID:L-2022-LLA-0011, Technical Specifications Task Force (Approved, Closed)
Initiation Request Acceptance Administration Questions Answers Results Approval Other:
MONTHYEAR2022-11-14 [Table View]

ML22256A253

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Dear Mr. Gibby:

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1.0 PROPOSED CHANGE

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

4.0 CONCLUSION

1.0 INTRODUCTION

2.0 STATE CONSULTATION

3.0 ENVIRONMENTAL CONSIDERATION

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