Text

1 & 2; Shearon Harris Nuclear Power Plant 1; Catawba Nuclear Station 1 & 2; Mcguire Nuclear Station 1 & 2; and Oconee Nuclear Station 1, 2, & 3: Issuance of Amendments Regarding Adoption of TSTF-523 (CAC Nos. MF6413-MF6422)
	ML16085A113
Person / Time
Site:	Oconee, Mcguire, Catawba, Harris, Brunswick, McGuire
Issue date:	04/29/2016
From:	Jeffrey Whited; Plant Licensing Branch II
To:	Repko R; Duke Energy Carolinas
	Whited J, NRR/DORL/LPLII-1
References
	CAC MF6412, CAC MF6422
	Download: ML16085A113 (104)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 Mr. Regis T. Repko Senior Vice President Governance, Projects, & Engineering Duke Energy Carolinas, LLC P.O. Box 1006/EC07H Charlotte, NC 28201-1006 April 29, 2016

SUBJECT:

BRUNSWICK STEAM ELECTRIC PLANT, UNIT NOS. 1 AND 2; SHEARON HARRIS NUCLEAR POWER PLANT, UNIT 1; CATAWBA NUCLEAR STATION, UNITS 1 AND 2; MCGUIRE NUCLEAR STATION, UNITS 1 AND 2; AND OCONEE NUCLEAR STATION, UNITS 1, 2, AND 3: ISSUANCE OF AMENDMENTS REGARDING ADOPTION OF TSTF-523 (CAC NOS. MF6413 THROUGH MF6422)

Dear Mr. Repko:

The U.S. Nuclear Regulatory Commission (NRC) has issued the enclosed Amendment Nos.

270 and 298 to Renewed Facility Operating License (RFOL) Nos. DPR-71 and DPR-62, respectively, for the Brunswick Steam Electric Plant, Unit Nos. 1 and 2; Amendment No. 150 to RFOL No. NPF-63, for the Shearon Harris Nuclear Power Plant, Unit 1; Amendment Nos. 282 and 278 to RFOL Nos. NPF-35 and NPF-52, respectively, for the Catawba Nuclear Station, Units 1 and 2; Amendment Nos. 285 and 264 to RFOL Nos. NPF-9 and NPF-17, respectively, for the McGuire Nuclear Station, Units 1 and 2; and Amendment Nos. 398, 400, and 399 to RFOL Nos. DPR-38, DPR-47, DPR-55, respectively, for the Oconee Nuclear Station, Units 1, 2, and 3.

The amendments are in response to your application dated June 24, 2015, as supplemented by letter dated January 18, 2016. The amendments revise or add Surveillance Requirements to the Technical Specifications, to verify that the system locations susceptible to gas accumulation are sufficiently filled with water and to provide allowances which permit performance of the verification. These changes are requested to address the concerns discussed in NRC Generic Letter 2008-01, "Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems."

A copy of the related Safety Evaluation is also enclosed. A Notice of Issuance will be included in the Commission's biweekly Federal Register notice.

If you have any questions, please contact me by phone at 301-415-4090, or by e-mail at jeffrey.whited@nrc.gov.

Sincerely,

~A l/4--

Jeffrey A. Whited, Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos.

50-325, 50-324, 50-400, 50-413, 50-414, 50-369, 50-370 50-269, 50-270, and 50-287

Enclosures:

1. Amendment No. 270 to RFOL DPR-71

2. Amendment No. 298 to RFOL DPR-62

3. Amendment No. 150 to RFOL NPF-63

4. Amendment No. 282 to RFOL NPF-35

5. Amendment No. 278 to RFOL NPF-52

6. Amendment No. 285 to RFOL NPF-9

7. Amendment No. 264 to RFOL NPF-17

8. Amendment No. 398 to RFOL DPR-38

9. Amendment No. 400 to RFOL DPR-47

10. Amendment No. 399 to RFOL DPR-55

11. Safety Evaluation cc w/encls: Distribution via Listserv

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY PROGRESS, INC.

DOCKET NO. 50-325 BRUNSWICK STEAM ELECTRIC PLANT. UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 270 Renewed License No. DPR-71

1.

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

A.

The application for amendment to the Brunswick Steam Electric Plant, Unit 1 (the facility), Renewed Facility Operating License No. DPR-71, filed by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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; 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. DPR-71 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 270, are hereby incorporated in the license. Duke Energy Progress, Inc. shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION

-~4~

Benjamin G. Beasley, Chief Plant Licensing Branch 11-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: April 2 9, 2o1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 270 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-71 DOCKET NO. 50-325 Replace the following page of Renewed Facility Operating License No. DPR-71 with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

REMOVE Page 6 INSERT Page 6 Replace the following page of the Appendix A Technical Specifications with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

REMOVE 3.4-16 3.4-18 3.5-4 3.5-5 3.5-10 3.5-13 3.6-25 3.9-12 3.9-15 INSERT 3.4-16 3.4-18 3.5-4 3.5-5 3.5-10 3.5-13 3.6-25 3.9-12 3.9-15 (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 licensee's fire protection program may not be made without prior NRC review and approval unless the change has been demonstrated to have no more than a minimal risk impact, as described in 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. 270, are hereby incorporated in the license. Duke Energy Progress, Inc. 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 Renewed License No. DPR-71 Amendment No. 270

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SR 3.4.7.2 Brunswick Unit 1 SURVEILLANCE

N 0 TE---------------------------------

N o t required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

FREQUENCY Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

N 0 TE-------------------------------

N o t required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

3.4-16 Amendment No. 270 I

ACTIONS (continued}

CONDITION B.

No RHR shutdown cooling B.1 subsystem in operation.

No recirculation pump in operation.

SURVEILLANCE REQUIREMENTS AND B.2 RHR Shutdown Cooling System-Cold Shutdown 3.4.8 REQUIRED ACTION COMPLETION TIME Verify reactor coolant 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months from circulating by an alternate discovery of no method.

reactor coolant circulation Monitor reactor coolant temperature.

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Once per hour SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

SR 3.4.8.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 1 3.4-18 Amendment No. 270

ACTIONS (continued)

CONDITION J.

Two or more low pressure J.1 ECCS injection/spray subsystems inoperable for reasons other than Condition A or B.

HPCI System and two or more required ADS valves inoperable.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION Enter LCO 3.0.3.

SURVEILLANCE SR 3.5.1.1 Brunswick Unit 1 Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

3.5-4 ECCS-Operating 3.5.1 COMPLETION TIME Immediately FREQUENCY 92 days (continued)

Amendment No. 270

ECCS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.2 SR 3.5.1.3 SR 3.5.1.4 SR 3.5.1.5 Brunswick Unit 1 SURVEILLANCE

N 0 TES----------------------------

1.

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) shutdown cooling isolation pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

2.

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

FREQUENCY Verify each ECCS injection/spray subsystem manual, 31 days power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify ADS pneumatic supply header pressure is

~ 95 psig.

Verify the RHR System cross tie valve is locked closed.

N 0 TE-----------------------------

N o t required to be performed if performed within the previous 31 days.

31 days 31 days Verify each recirculation pump discharge valve and Once each startup bypass valve cycles through one complete cycle of full prior to exceeding travel or is de-energized in the closed position.

25% RTP (continued) 3.5-5 Amendment No. 270

ECCS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 Brunswick Unit 1 SURVEILLANCE FREQUENCY Verify, for each required core spray (CS) subsystem, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the:

a.

Suppression pool water level is;::>: -31 inches; or b.

N 0 TE----------------------------

0 n ly one required CS subsystem may take credit for this option during OPDRVs.

Condensate storage tank water volume is

~ 228,200 gallons.

Verify, for each required ECCS injection/spray 31 days subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

N 0 TES------------------------------

1.

One LPCI subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

2.

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

Verify each required ECCS injection/spray subsystem 31 days manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

(continued) 3.5-10 Amendment No. 270

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 Brunswick Unit 1 SURVEILLANCE FREQUENCY Verify the RCIC System locations susceptible to gas 92 days accumulation are sufficiently filled with water.

N 0 TE-------------------------------

N o t required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual, power operated, 31 days and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

N 0 TE--------------------------------

1.

Use of auxiliary steam for the performance of the SR is not allowed.

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 reactor pressure~ 945 psig and :$ 1045 psig, the RCIC pump can develop a flow rate

~ 400 gpm against a system head corresponding to reactor pressure.

3.5-13 92 days (continued)

Amendment No. 270

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling subsystem 31 days manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate 92 days

~ 7700 gpm through the associated heat exchanger while operating in the suppression pool cooling mode.

SR 3.6.2.3.3 Verify RHR suppression pool cooling subsystem 92 days locations susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 1 3.6-25 Amendment No. 270

' SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is operating.

SR 3.9.7.2 Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 1 3.9-12 RHR-High Water Level 3.9.7 FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 31 days Amendment No. 270

SURVEILLANCE REQUIREMENTS SURVEILLANCE RHR-Low Water Level 3.9.8 FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operating.

SR 3.9.8.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 1 3.9-15 Amendment No. 270

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY PROGRESS, INC.

DOCKET NO. 50-324 BRUNSWICK STEAM ELECTRIC PLANT, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 298 Renewed License No. DPR-62

1.

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

A.

The application for amendment to the Brunswick Steam Electric Plant, Unit 2 (the facility), Renewed Facility Operating License No. DPR-62, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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; 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. DPR-62 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 298, are hereby incorporated in the license. Duke Energy Progress, Inc. shall operate the facility in accordance with the Technical Specifications.

3.

This license amendment is effective as of its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION

~~

Benjamin G. Beasley, Chief Plant Licensing Branch 11-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: April 2 9, 2o1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 298 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-62 DOCKET NO. 50-324 Replace the following page of Renewed Facility Operating License No. DPR-62 with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

REMOVE Page 6 INSERT Page 6 Replace the following page of the Appendix A Technical Specifications with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

REMOVE 3.4-16 3.4-18 3.5-4 3.5-5 3.5-10 3.5-13 3.6-25 3.9-12 3.9-15 INSERT 3.4-16 3.4-18 3.5-4 3.5-5 3.5-10 3.5-13 3.6-25 3.9-12 3.9-15 (c)

Transition License Conditions

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

B. This renewed license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 1 O 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. 298, are hereby incorporated in the license. Duke Energy Progress, Inc. 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, Renewed License No. DPR-62 Amendment No. 298

RHR Shutdown Cooling System-Hot Shutdown 3.4.7 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SR 3.4.7.2 Brunswick Unit 2 SURVEILLANCE

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

Not required to be met until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

FREQUENCY Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

N 0 TE-------------------------------

N o t required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reactor steam dome pressure is less than the RHR shutdown cooling isolation pressure.

Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

3.4-16 31 days Amendment No. 298 J

ACTIONS (continued)

CONDITION B.

No RHR shutdown cooling subsystem in operation.

No recirculation pump in operation.

SURVEILLANCE REQUIREMENTS B.1 AND B.2 RHR Shutdown Cooling System-Cold Shutdown 3.4.8 REQUIRED ACTION Verify reactor coolant circulating by an alternate method.

Monitor reactor coolant temperature.

COMPLETION TIME 1 hourfrom discovery of no reactor coolant circulation Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter Once per hour SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one required RHR shutdown cooling subsystem 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months or recirculation pump is operating.

SR 3.4.8.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 2 3.4-18 Amendment No. 298 I

ACTIONS (continued)

CONDITION J.

Two or more low pressure J.1 ECCS injection/spray subsystems inoperable for reasons other than Condition A or B.

HPCI System and two or more required ADS valves inoperable.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION Enter LCO 3.0.3.

SURVEILLANCE SR 3.5.1.1 Brunswick Unit 2 Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

3.5-4 ECCS-Operating 3.5.1 COMPLETION TIME Immediately FREQUENCY 92 days (continued)

Amendment No. 298

ECCS-Operating 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.1.2 SR 3.5.1.3 SR 3.5.1.4 SR 3.5.1.5 Brunswick Unit 2 SURVEILLANCE

N 0 TES-------------------------------

1.

Low pressure coolant injection (LPCI) subsystems may be considered OPERABLE during alignment and operation for decay heat removal with reactor steam dome pressure less than the Residual Heat Removal (RHR) shutdown cooling isolation pressure in MODE 3, if capable of being manually realigned and not otherwise inoperable.

2.

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

FREQUENCY Verify each ECCS injection/spray subsystem manual, 31 days power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify ADS pneumatic supply header pressure is

~ 95 psig.

Verify the RHR System cross tie valve is locked closed.

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

Not required to be performed if performed within the previous 31 days.

31 days 31 days Verify each recirculation pump discharge valve and Once each startup bypass valve cycles through one complete cycle of full prior to exceeding travel or is de-energized in the closed position.

25% RTP (continued}

3.5-5 Amendment No. 298 I

EGGS-Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.2 SR 3.5.2.3 SR 3.5.2.4 Brunswick Unit 2 SURVEILLANCE FREQUENCY Verify, for each required core spray (CS) subsystem, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the:

a.

Suppression pool water level is :2: -31 inches; or

b.

N 0 TE-----------------------------

0 n ly one required CS subsystem may take credit for this option during OPDRVs.

Condensate storage tank water volume is

2: 228,200 gallons.

Verify, for each required ECCS injection/spray 31 days subsystem, locations susceptible to gas accumulation are sufficiently filled with water.

N 0 TES------------------------------

1.

One LPCI subsystem may be considered OPERABLE during alignment and operation for decay heat removal if capable of being manually realigned and not otherwise inoperable.

2.

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

Verify each required ECCS injection/spray subsystem 31 days manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

(continued) 3.5-10 Amendment No. 298

RCIC System 3.5.3 SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SR 3.5.3.2 SR 3.5.3.3 Brunswick Unit 2 SURVEILLANCE FREQUENCY Verify the RCIC System locations susceptible to gas 92 days accumulation are sufficiently filled with water.

N 0 TE-----------------------------

N o t required to be met for system vent flow paths opened under administrative control.

Verify each RCIC System manual, power operated, 31 days and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

N 0 TES----------------------------

1.

Use of auxiliary steam for the performance of the SR is not allowed.

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 reactor pressure~ 945 psig and ~ 1045 psig, the RCIC pump can develop a flow rate

~ 400 gpm against a system head corresponding to reactor pressure.

3.5-13 92 days (continued)

Amendment No. 298 J

RHR Suppression Pool Cooling 3.6.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.3.1 Verify each RHR suppression pool cooling subsystem 31 days manual, power operated, and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position or can be aligned to the correct position.

SR 3.6.2.3.2 Verify each RHR pump develops a flow rate 92 days

7700 gpm through the associated heat exchanger while operating in the suppression pool cooling mode.

SR 3.6.2.3.3 Verify RHR suppression pool cooling subsystem 92 days locations susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 2 3.6-25 Amendment No. 298 I

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.7.1 Verify one RHR shutdown cooling subsystem is operating.

SR 3.9.7.2 Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 2 3.9-12 RHR-High Water Level 3.9.7 FREQUENCY 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 31 days Amendment No. 298 I

SURVEILLANCE REQUIREMENTS SURVEILLANCE RHR-Low Water Level 3.9.8 FREQUENCY SR 3.9.8.1 Verify one RHR shutdown cooling subsystem is 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months operating.

SR 3.9.8.2 Verify RHR shutdown cooling subsystem locations 31 days susceptible to gas accumulation are sufficiently filled with water.

Brunswick Unit 2 3.9-15 Amendment No. 298 I

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY PROGRESS, INC.

DOCKET NO. 50-400 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 150 Renewed License No. NPF-63

1.

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

A.

The application for amendment to the Shearon Harris Nuclear Power Plant, Unit 1 (the facility), Renewed Facility Operating License No.* NPF-63, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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; 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. 150, are hereby incorporated into this license.

Duke Energy Progress, Inc. shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

3.

This license amendment is effective as of its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Benjamin G. Beasley, Chief Plant Licensing Branch 11-2 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: April 2 9, 2O1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 150 RENEWED FACILITY OPERATING LICENSE NO. NPF-63 DOCKET NO. 50-400 Replace the following page of Renewed Facility Operating License No. NPF-63 with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove Page 4 Insert Page 4 Replace the following page of the Appendix A Technical Specifications with the attached revised page. The revised page is identified by amendment number and contains a marginal line indicating the area of change.

Remove 3/4 4-5 3/4 4-6 3/4 4-7 3/4 5-4 3/4 6-11 3/4 9-9 3/4 9-10 Insert 3/4 4-5 3/4 4-6 3/4 4-7 3/4 5-4 3/4 6-11 3/4 9-9 3/4 9-10

1 C.

This license shall be deemed to contain and is subject to the conditions specified in the Commission's regulations set forth in 1 O 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, Inc. 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. 150, are hereby incorporated into this license. Duke Energy Progress, Inc. shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan.

(3)

Antitrust Conditions Duke Energy Progress, Inc. 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.

The 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.

Renewed License No. NPF-63 Amendment No. 150

REACTOR COOLANT SYSTEM HOT SHUTDOWN SURVEILLANCE REQUIREMENTS 4.4.1.3.1 The required reactor coolant pump(s), if not in operation, shall be determined OPERABLE once per 7 days by verifying correct breaker alignments and indicated power availability.

4.4.1.3.2 The required steam generator(s) shall be determined OPERABLE by verifying wide range (WR) secondary side water level is greater than 7 4% or narrow range (NR) secondary side water level is greater than 30% at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.3.3 At least one reactor coolant or RHR loop shall be verified in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.3.4 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days.*

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

SHEARON HARRIS - UNIT 1 3/44-5 Amendment No. 150

REACTOR COOLANT SYSTEM COLD SHUTDOWN - LOOPS FILLED LIMITING CONDITION FOR OPERATION 3.4.1.4.1 At least one residual heat removal (RHR) loop shall be OPERABLE and in operation*,

and either:

a.

One additional RHR loop shall be OPERABLE**, or

b.

The secondary side water level of at least two steam generators shall be greater than 74% wide range (WR) or greater than 30% narrow range (NR).

APPLICABILITY: MODE 5 with reactor coolant loops filled***.

ACTION:

a.

With one of the RHR loops inoperable and with less than the required steam generator water level, immediately initiate corrective action to return the inoperable RHR loop to OPERABLE status or restore the required steam generator water level as soon as possible.

b.

With no RHR loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required RHR loop to operation.

SURVEILLANCE REQUIREMENTS 4.4.1.4.1.1 The secondary side water level of at least two steam generators when required shall be determined to be within limits at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.4.1.2 At least one RHR loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.4.1.3 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days.

The RHR pump may be deenergized for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months provided: (1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and (2) core outlet temperature is maintained at least 10°F below saturation temperature.

- One RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided the other RHR loop is OPERABLE and in operation.

- - A reactor coolant pump shall not be started with one or more of the Reactor Coolant System cold leg temperatures less than or equal to 325°F unless the secondary water temperature of each steam generator is less than 50°F above each of the Reactor Coolant System cold leg temperatures.

SHEARON HARRIS - UNIT 1 3/4 4-6 Amendment No. 150

REACTOR COOLANT SYSTEM COLD SHUTDOWN - LOOPS NOT FILLED LIMITING CONDITION FOR OPERATION 3.4.1.4.2 Two residual heat removal (RHR) loops shall be OPERABLE* and at least one RHR loop shall be in operation.**

APPLICABILITY: MODE 5 with reactor coolant loops not filled.

ACTION:

a.

With less than the above required RHR loops OPERABLE, immediately initiate corrective action to return the required RHR loops to OPERABLE status as soon as possible.

b.

With no RHR loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required RHR loop to operation.

SURVEILLANCE REQUIREMENTS 4.4.1.4.2.1 At least one RHR loop shall be determined to be in operation and circulating reactor coolant at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.4.1.4.2.2 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days.

One RHR loop may be inoperable for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months for surveillance testing provided the other RHR loop is OPERABLE and in operation.

- The RHR pump may be deenergized for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months provided: (1) no operations are permitted that would cause dilution of the Reactor Coolant System boron concentration, and (2) core outlet temperature is maintained at least 10°F below saturation temperature.

SHEARON HARRIS - UNIT 1 3/44-7 Amendment No. 150

EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

CP&L Valve No.

1Sl-107 1 Sl-86 1Sl-52 1Sl-340 1 Sl-341 1 Sl-359

b.

EBASCO Valve No.

Valve Function Valve Position 2Sl-V500SA-1 High Head Safety Injection to Reactor Closed Coolant System Hot' Legs 2Sl-V501 SB-1 High Head Safety Injection to Reactor Closed Coolant System Hot Legs 2Sl-V502SA-1 High Head Safety Injection to Reactor Closed Coolant System Cold Legs 2Sl-V579SA-1 Low Head Safety Injection to Reactor Open Coolant System Cold Legs 2Sl-V578SB-1 Low Head Safety Injection to Reactor Open Coolant System Cold Legs 2Sl-V587SA-1 Low Head Safety Injection to Reactor Closed Coolant System Hot Legs At least once per 31 days by:

1.

Verifying that ECCS locations susceptible to gas accumulation are sufficiently filled with water, and

2.

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.*

c.

By a visual inspection which verifies that no loose debris (rags, trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause restriction of the pump suctions during LOCA conditions. This visual inspection shall be performed:

1.

For all accessible areas of the containment prior to establishing CONTAINMENT INTEGRITY, and

2.

Of the areas affected within containment at the completion of each containment entry when CONTAINMENT INTEGRITY is established.

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

SHEARON HARRIS - UNIT 1 3/4 5-4 Amendment No. 150

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 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 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.

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

a.

At least once per 31 days 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 lnservice Testing Program;

c.

At least once per 18 months by:

1.

Verifying that each automatic valve in the flow path actuates to its correct position on a containment spray actuation test signal 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.

d.

At least once per 10 years by performing an air or smoke flow test through each spray header and verifying each spray nozzle is unobstructed.

e.

At least once per 92 days by verifying that containment spray locations susceptible to gas accumulation are sufficiently filled with water.

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

SHEARON HARRIS - UNIT 1 3/4 6-11 Amendment No. 150

REFUELING OPERATIONS 3/4.9.8 RESIDUAL HEAT REMOVAL AND COOLANT CIRCULATION HIGH WATER LEVEL LIMITING CONDITION FOR OPERATION 3.9.8.1 At least one residual heat removal (RHR) loop shall be OPERABLE and in operation.*

APPLICABILITY:

MODE 6, with irradiated fuel in the vessel when the water level above the top of the reactor vessel flange is greater than or equal to 23 feet.

ACTION:

With no RHR loop OPERABLE and in operation, suspend all operations involving an increase in the reactor decay heat load or a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required RHR loop to OPERABLE and operating status as soon as possible. Close all containment penetrations providing direct access from the containment atmosphere to the outside atmosphere within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

SURVEILLANCE REQUIREMENTS 4.9.8.1.1 At least one RHR loop shall be verified in operation and circulating reactor coolant at a flow rate of greater than or equal to 2500 gpm at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

4.9.8.1.2 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days.

The RHR loop may be removed from operation for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 2-hour period during the performance of CORE AL TERA TIONS and core loading verification in the vicinity of the reactor vessel hot legs.

SHEARON HARRIS - UNIT 1 3/4 9-9

. Amendment No. 150

REFUELING OPERATIONS LOW WATER LEVEL LIMITING CONDITION FOR OPERATION 3.9.8.2 Two independent residual heat removal (RHR) loops shall be OPERABLE, and at least one RHR loop shall be in operation.*

APPLICABILITY:

MODE 6, with irradiated fuel in the vessel when the water level above the top of the reactor vessel flange is less than 23 feet.

ACTION:

a.

With less than the required RHR loops OPERABLE, immediately initiate corrective action to return the required RHR loops to OPERABLE status or to establish greater than or equal to 23 feet of water above the reactor vessel flange as soon as possible.

b.

With no RHR loop in operation, suspend all operations involving a reduction in boron concentration of the Reactor Coolant System and immediately initiate corrective action to return the required RHR loop to operation. Close all containment penetrations providing direct access from the containment atmosphere to the outside atmosphere within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

SURVEILLANCE REQUIREMENTS 4.9.8.2.1 At least one RHR loop shall be verified in operation and circulating reactor coolant at a flow rate of greater than or equal to 2500 gpm at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months whenever the water level is at or above the reactor vessel flange.

4.9.8.2.2 At least one RHR loop shall be verified in operation and circulating reactor coolant at a flow rate of greater than or equal to 900 gpm at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months whenever the water level is below the reactor vessel flange.

4.9.8.2.3 Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days.

The operating RHR loop may be removed from operation for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 2-hour period during the performance of CORE ALTERATIONS and core loading verification in the vicinity of the reactor vessel hot legs.

SHEARON HARRIS-UNIT 1 3/4 9-10 Amendment No. 150

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-413 CATAWBA NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 282 Renewed License No. NPF-35

1.

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

A.

The application for amendment to the Catawba Nuclear Station, Unit 1 (the facility), Renewed Facility Operating License No. NPF-35, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 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-35 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 282, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: April 29, 201 6

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS. LLC DOCKET NO. 50-414 CATAWBA NUCLEAR STATION. UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 278 Renewed License No. NPF-52

1.

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

A.

The application for amendment to the Catawba Nuclear Station, Unit 2 (the facility), Renewed Facility Operating License No. NPF-52, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 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-52 is hereby amended to read as follows:

(2)

Technical Specifications.

The Technical Specifications contained in Appendix A, as revised through Amendment No. 278, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION

~--z.~

Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: Apr i 1 2 9, 2O1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 282 RENEWED FACILITY OPERATING LICENSE NO. NPF-35 DOCKET NO. 50-413 AND LICENSE AMENDMENT NO. 278 RENEWED FACILITY OPERATING LICENSE NO. NPF-52 DOCKET NO. 50-414 Replace the following page of Renewed Facility Operating Licenses with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove NPF-35, page 4 NPF-52, page 4 Insert NPF-35, page 4 NPF-52, page 4 Replace the following page of the Appendix A Technical Specifications with the attached revised page. The revised page is identified by amendment number and contains a marginal line indicating the area of change.

Remove 3.4.6-3 3.4.7-3 3.4.8-2 3.5.2-2 3.6.6-1 3.6.6-2 3.9.4-2 3.9.5-2 Insert 3.4.6-3 3.4.7-3 3.4.8-2 3.5.2-2 3.6.6-1 3.6.6-2 3.9.4-2 3.9.5-2 (2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 282, 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 (Section 9.5.1, SER, SSER #2, SSER #3, SSER #4, SSER #5)*

Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report, as amended, for the facility and as approved in the SER through Supplement 5, subject to the following provision:

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

The parenthetical notation following the title of this renewed operating license condition denotes the section of the Safety Evaluation Report and/or its supplement wherein this renewed license condition is discussed.

Renewed License No. NPF-35 Amendment No. 282 (2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 278, 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 February 24, 2026, 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 (Section 9.5.1, SER, SSER #2, SSER #3, SSER #4, SSER #5)*

Duke Energy Carolinas, LLC shall implement and maintain in effect all provisions of the approved fire protection program as described in the Updated Final Safety Analysis Report, as amended, for the facility and as approved in the SER through Supplement 5, subject to the following provision:

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

The parenthetical notation following the title of this renewed operating license condition denotes the section of the Safety Evaluation Report and/or its supplements wherein this renewed license condition is discussed Renewed License No. NPF-52 Amendment No. 278

RCS Loops - MODES 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.4.6.3 Verify correct breaker alignment and indicated power are available to the required pump that is not in operation.

SR 3. 4. 6. 4

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

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

Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Catawba Units 1 and 2 3.4.6-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 282/278

RCS Loops - MODES 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS (continued)

SR 3.4.7.3 SR 3.4.7.4 SURVEILLANCE Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation.

Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Catawba Units 1 and 2 3.4.7-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 282/278

RCS Loops - MODES 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION B.

Required RHR loops inoperable.

No RHR loop in operation.

B.1 AND B.2 SURVEILLANCE REQUIREMENTS REQUIRED ACTION Suspend operations that would cause introduction of coolant into the RCS with boron concentration less than required to meet SOM of LCO 3.1.1.

Initiate action to restore one RHR loop to OPERABLE status and operation.

SURVEILLANCE SR 3.4.8.1 Verify one RHR loop is in operation.

SR 3.4.8.2 Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Catawba Units 1 and 2 3.4.8-2 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 282/278

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed.

Number Position Function Nl162A Open SI Cold Leg Injection Nl121A Closed SI Hot Leg Injection Nl152B Closed SI Hot Leg Injection Nl183B Closed RHR Hot Leg Injection N1173A Open RHRCold Leg Injection Nl178B Open RHR Cold Leg Injection Nl100B Open SI Pump Suction from RWST N1147B Open SI Pump Mini-Flow SR 3. 5.2. 2

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

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

Verify each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water.

SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow point is greater than or equal to the required developed head.

Catawba Units 1 and 2 3.5.2-2 ECCS - Operating 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program (continued)

Amendment Nos. 282/278

Containment Spray System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System LCO 3.6.6 Two containment spray trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION A.

One containment spray A.1 Restore containment spray train inoperable.

train to OPERABLE status.

B.

Required Action and B.1 Be in MODE 3.

associated Completion Time not met.

AND B.2 Be in MODE 5.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3. 6. 6.1

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

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

Verify each containment spray manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

Catawba Units 1 and 2 3.6.6-1 COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 6 hours 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months FREQUENCY In accordance with the Surveillance Frequency Control Program (continued}

Amendment Nos. 282/278

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the lnservice developed head.

Testing Program SR 3.6.6.3 Deleted.

SR 3.6.6.4 Deleted.

SR 3.6.6.5 Verify that each spray pump is de-energized and In accordance with prevented from starting upon receipt of a terminate signal the Surveillance and is allowed to manually start upon receipt of a start Frequency Control permissive from the Containment Pressure Control Program System (CPCS}.

SR 3.6.6.6 Verify that each spray pump discharge valve closes or is In accordance with prevented from opening upon receipt of a terminate the Surveillance signal and is allowed to manually open upon receipt of a Frequency Control start permissive from the Containment Pressure Control Program System (CPCS}.

SR 3.6.6.7 Verify each spray nozzle is unobstructed.

Following activities which could result in nozzle blockage SR 3.6.6.8 Verify containment spray locations susceptible to gas In accordance with accumulation are sufficiently filled with water.

the Surveillance Frequency Control Program Catawba Units 1 and 2 3.6.6-2 Amendment Nos. 282/278

RHR and Coolant Circulation - High Water Level 3.9.4 ACTIONS CONDITION A

(continued)

REQUIRED ACTION A.4 Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.4.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of~ 1000 gpm and RCS temperature is S 140°F.

SR 3.9.4.2 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Catawba Units 1 and 2 3.9.4-2 COMPLETION TIME 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 282/278

RHR and Coolant Circulation - Low Water Level 3.9.5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.2 Initiate action to restore Immediately one RHR loop to operation.

SURVEILLANCE REQUIREMENTS B.3 Close all containment penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE SR 3.9.5.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of ?:. 1000 gpm and RCS temperature is~ 140°F.

SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.

SR 3.9.5.3 Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Catawba Units 1 and 2 3.9.5-2 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 282/278

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-369 MCGUIRE NUCLEAR STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 285 Renewed License No. NPF-9

1.

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

A.

The application for amendment to the McGuire Nuclear Station, Unit 1 (the facility), Renewed Facility Operating License No. NPF-9, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 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-9 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 285, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: Apr i 1 2 9, 2o1 6

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-370 MCGUIRE NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 264 Renewed License No. NPF-17

1.

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

A.

The application for amendment to the McGuire Nuclear Station, Unit 2 (the facility), Renewed Facility Operating License No. NPF-17, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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;

8.

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-17 is hereby amended to read as follows:

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 264, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: Apr i 1 2 9, 2O1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 285 RENEWED FACILITY OPERATING LICENSE NO. NPF-9 DOCKET NO. 50-369 AND LICENSE AMENDMENT NO. 264 RENEWED FACILITY OPERATING LICENSE NO. NPF-17 DOCKET NO. 50-370 Replace the following page of Renewed Facility Operating Licenses with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove NPF-9, page 3 NPF-17, page 3 Insert NPF-9, page 3 NPF-17, 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 contains a marginal line indicating the area of change.

Remove 3.4.7-3 3.4.8-2 3.5.2-2 3.6.6-1 3.6.6-2 3.9.5-2 3.9.6-2 Insert 3.4.6-3 3.4.7-3 3.4.8-2 3.5.2-2 3.6.6-1 3.6.6-2 3.9.5-2 3.9.6-2 (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 3411 megawatts thermal (100%).

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 285, 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-9 Amendment No. 285 (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 Part 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 3411 megawatts thermal ( 100%).

(2)

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 264, 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.

Renewed License No. NPF-17 Amendment No. 264

RCS Loops - MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3. 4.6. 4

N 0 TE---------------------------------

N o t required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4.

Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

McGuire Units 1 and 2 3.4.6-3 FREQUENCY In accordance with the Surveillance Frequency Control Pro ram Amendment Nos. 285/264

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify SG secondary side water level is::::. 12% narrow In accordance with range in required SGs.

the Surveillance Frequency Control Program SR 3.4.7.3 Verify correct breaker alignment and indicated power are In accordance with available to the required RHR pump that is not in the Surveillance operation.

Frequency Control ProQram SR 3.4.7.4 Verify required RHR loop locations susceptible to gas In accordance with accumulation are sufficiently filled with water.

the Surveillance Frequency Control Proi:iram McGuire Units 1 and 2 3.4.7-3 Amendment Nos. 285/264

RCS Loops -MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required RHR loops inoperable.

B.1 Suspend operations that Immediately No RHR loop in operation.

SURVEILLANCE REQUIREMENTS would cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

B.2 Initiate action to restore one RHR loop to OPERABLE status and operation.

SURVEILLANCE SR 3.4.8.1 Verify one RHR loop is in operation.

SR 3.4.8.2 Verify correct breaker alignment and indicated power are available to the required RHR pump that is not in operation.

SR 3.4.8.3 Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

McGuire Units 1 and 2 3.4.8-2 Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 285/264

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.2.1 Verify the following valves are in the listed position with power to the valve operator removed.

Number Position Function Nl162A Open SI Cold Leg Injection Nl121A Closed SI Hot Leg Injection N1152B Closed SI Hot Leg Injection Nl183B Closed RHR Hot Leg Injection Nl173A Open RHR Cold Leg Injection Nl178B Open RHR Cold Leg Injection Nl100B Open SI Pump RWST Suction FW27A Open RHR/RWST Suction Nl147A Open SI Pump Mini-Flow SR 3. 5.2.2

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

N ot required to be met for system vent flow paths opened under administrative control.

Verify each ECCS manual, power operated, and automatic valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water.

McGuire Units 1 and 2 3.5.2-2 ECCS-Operating 3.5.2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control ProQram In accordance with the Surveillance Frequency Control Program (continued)

Amendment Nos. 285/264

Containment Spray System 3.6.6 3.6 CONTAINMENT SYSTEMS 3.6.6 Containment Spray System LCO 3.6.6 Two containment spray trains shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One containment spray A.1 Restore containment spray 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s*

train inoperable.

train to OPERABLE status.

B.

Required Action and B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

AND B.2 Be in MODE 5.

84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months

N 0 TE-------------------------------------------------------------

'A' Train Containment Spray is allowed to be inoperable for a total of 14 days for the correction of a degraded condition on the 'A' Train supply piping from the Standby Nuclear Service Water Pond (SNSWP). The 14 days may be taken consecutively or in parts until completion of the activity, or by March 1, 2017, whichever occurs first. During the period in which the 'A' Train NSWS supply piping from the SNSWP is not available, the 'A' Train NSWS will remain aligned to Lake Norman until the system is ready for post maintenance testing. Any maintenance that is performed on the remaining portions of 'A' Train NSWS during the period in which the 'A' NSWS from the SNSWP supply piping is not available will be limited to a 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months completion time. The latter will not count against the 14 day completion time. Allowance of the extended Completion Time is contingent on meeting the Compensatory Measures and Commitments described in MNS LAR submittal correspondence letter MNS-16-005.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3. 6.6.1

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

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

Verify each containment spray manual and power operated valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

McGuire Units 1 and 2 3.6.6-1 FREQUENCY In accordance with the Surveillance Frequency Control Pro ram (continued)

Amendment Nos. 285/264

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.2 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the lnservice developed head.

Testing Program SR 3.6.6.3 Not Used Not Used SR 3.6.6.4 Not Used Not Used SR 3.6.6.5 Verify that each spray pump is de-energized and In accordance with prevented from starting upon receipt of a terminate signal the Surveillance and is allowed to manually start upon receipt of a start Frequency Control permissive from the Containment Pressure Control Program System (CPCS).

SR 3.6.6.6 Verify that each spray pump discharge valve closes or is In accordance with prevented from opening upon receipt of a terminate the Surveillance signal and is allowed to manually open upon receipt of a Frequency Control start permissive from the Containment Pressure Control Program System (CPCS).

SR 3.6.6.7 Verify each spray nozzle is unobstructed.

Following activities which could result in nozzle blockage SR 3.6.6.8 Verify containment spray locations susceptible to gas In accordance with accumulation are sufficiently filled with water.

the Surveillance Frequency control Program McGuire Units 1 and 2 3.6.6-2 Amendment Nos. 285/264

RHR and Coolant Circulation - High Water Level 3.9.5 CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.5.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of~ 1000 gpm and RCS temperature is :::; 140°F.

SR 3.9.5.2 Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

McGuire Units 1 and 2 3.9.5-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 285/264

RHR and Coolant Circulation - Low Water Level 3.9.6 CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.2 Initiate action to restore Immediately one RHR loop to operation.

B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.6.1 Verify one RHR loop is in operation and circulating reactor coolant at a flow rate of~ 1000 gpm and RCS temperature is:::;; 140°F.

SR 3.9.6.2 Verify correct breaker alignment and indicated power available to the required RHR pump that is not in operation.

SR 3.9.6.3 Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water.

McGuire Units 1 and 2 3.9.6-2 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment No. 285/264

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-269 OCONEE NUCLEAR STATION. UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 398 Renewed License No. DPR-38

1.

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

A.

The application for amendment to the Oconee Nuclear Station, Unit 1 (the facility), Renewed Facility Operating License No. DPR-38, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 3.B of Renewed Facility Operating License No. DPR-38 is hereby amended to read as follows:

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 398, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: Apr i 1 2 9, 2O1 6

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-270 OCONEE NUCLEAR STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 400 Renewed License No. DPR-47

1.

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

A.

The application for amendment to the Oconee Nuclear Station, Unit 2 (the.

facility), Renewed Facility Operating License No. DPR-47, by Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 3.B of Renewed Facility Operating License No. DPR-47 is hereby amended to read as follows:

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 400, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: Apr i 1 2 9, 2O1 6

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 DUKE ENERGY CAROLINAS, LLC DOCKET NO. 50-287 OCONEE NUCLEAR STATION, UNIT 3 AMENDMENT TO RENEWED FACILITY OPERA TING LICENSE Amendment No. 399 Renewed License No. DPR-55

1.

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

A.

The application for amendment by to the Oconee Nuclear Station, Unit 3 (the facility), Renewed Facility Operating License No. DPR-55, Duke Energy Progress, Inc., and Duke Energy Carolinas, LLC, dated June 24, 2015, as supplemented by letter dated January 18, 2016, 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 1 O 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. 0

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 3.8 of Renewed Facility Operating License No. DPR-55 is hereby amended to read as follows:

8.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 399, 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 its date of issuance and shall be implemented within one year from the date of issuance.

Attachment:

Changes to the Renewed License and the Technical Specifications FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Date of Issuance: April 2 9, 2O1 6

ATTACHMENT TO LICENSE AMENDMENT NO. 398 RENEWED FACILITY OPERATING LICENSE NO. DPR-38 DOCKET NO. 50-269 AND LICENSE AMENDMENT NO. 400 RENEWED FACILITY OPERATING LICENSE NO. DPR-47 DOCKET NO. 50-270 AND LICENSE AMENDMENT NO. 399 RENEWED FACILITY OPERATING LICENSE NO. DPR-55 DOCKET NO. 50-287 Replace the following page of Renewed Facility Operating Licenses with the attached revised page. The revised page is identified by amendment number and contains marginal lines indicating the areas of change.

Remove DPR-38, page 3 DPR-47, page 3 DPR-55, page 3 Insert DPR-38, page 3 DPR-47, 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 contains a marginal line indicating the area of change.

Remove 3.4.6-2 3.4.7-3 3.4.8-2 3.5.2-4 3.5.3-2 3.5.3-3 3.6.5-4 3.6.5-5 3.9.4-2 3.9.5-2 Insert 3.4.6-2 3.4.7-3 3.4.8-2 3.5.2-4 3.5.3-2 3.5.3-3 3.6.5-4 3.6.5-5 3.9.4-2 3.9.5-2 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2568 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 398, 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-38 Amendment No. 398 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2568 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 400, 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,-r1 (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. 400 A.

Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2568 megawatts thermal.

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 399, 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. 399

ACTIONS (continued)

CONDITION REQUIRED ACTION B.

Two required loops B.1 Suspend all operations inoperable.

involving a reduction in RCS boron OR concentration.

Required loop not in AND operation.

B.2 Initiate action to restore one loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SR 3.4.6.1 SR 3.4.6.2 SURVEILLANCE Verify required DHR or RCS loop is in operation.

Verify correct breaker alignment and indicated power available to the required pump that is not in operation.

SR 3.4. 6. 3

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

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

Verify required OHR loop locations susceptible to gas accumulation are sufficiently filled with water.

RCS Loops - MODE 4 3.4.6 COMPLETION TIME Immediately Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.6-2 Amendment Nos.. 398. 400, 399

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SR 3.4.7.2 SR 3.4.7.3 SR 3.4.7.4 SURVEILLANCE Verify required OHR loop is in operation.

Verify required SG secondary side water levels are ~ 50%.

Verify correct breaker alignment and indicated power available to the required DHR pump that is not in operation.

Verify required OHR loop locations susceptible to gas accumulation are sufficiently filled with water.

OCONEE UNITS 1, 2, & 3 3.4.7-3 FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. : 398. 400, 399

RCS Loops - MODE 5, Loops Not Filled 3.4.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Two DHR loops inoperable.

B.1 Suspend all operations.

Immediately involving reduction in RCS boron OR concentration.

Required DHR loop not AND in operation.

B.2 Initiate action to restore one OHR loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SR 3.4.8.1 SR 3.4.8.2 SR 3.4.8.3 SURVEILLANCE Verify required DHR loop is in operation.

Verify correct breaker alignment and indicated power available to the required DHR pump that is not in operation.

Verify DHR loop locations susceptible to gas accumulation are sufficiently filled with water.

Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.8-2 Amendment Nos. 398, 400, 399

ACTIONS (continued)

CONDITION REQUIRED ACTION F.

One LPl-HPI flow F.1 Restore LPl-HPI flow path inoperable.

path to OPERABLE status.

G.

Required Action and G.1 Be in MODE 3.

associated Completion Time of AND Condition 8, C, D, E, or F not met.

G.2 Reduce RCS temperature to

350°F.

H.

Two HPI trains H.1 Enter LCO 3.0.3.

inoperable.

OR Two LPl-HPI flow paths inoperable.

SURVEILLANCE REQUIREMENTS SR 3.5.2.1 SR 3.5.2.2 SURVEILLANCE

N 0 TE--------------------------

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

Verify each HPI manual and non-automatic power operated valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

Verify HPI locations susceptible to gas accumulation are sufficiently filled with water.

HPI 3.5.2 COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 12 hours 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months Immediately FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.5.2-4 Amendment Nos. 398, 400. 399

ACTIONS (continued)

CONDITION REQUIRED ACTION

c.

Required Action and C.1 Be in MODE 3.

associated Completion Time of Condition A or AND B not met.

C.2 Be in MODE 4.

D.

One required LPI train D.1 Initiate action to inoperable in MODE 4.

restore required LPI train to OPERABLE status.

AND D.2

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

Only required if OHR loop is OPERABLE.

Be in MODE 5.

SURVEILLANCE REQUIREMENTS SR 3.5.3.1 SURVEILLANCE

N 0 TE-----------------------

N o t required to be met for system vent flow paths opened under administrative control.

Verify each LPI manual and non-automatic power operated valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

LPI 3.5.3 COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 60 hours Immediately 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.5.3-2 Amendment Nos.

398, 400. 399

SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.3.2 SR 3.5.3.3 SR 3.5.3.4 SR 3.5.3.5 SR 3.5.3.6 SURVEILLANCE Verify LPI locations susceptible to gas accumulation are sufficiently filled with water.

Verify each LPI pump's developed head at the test flow point is greater than or equal to the required developed head.

Verify each LPI automatic valve in the flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

Verify each LPI pump starts automatically on an actual or simulated actuation signal.

Verify, by visual inspection, each LPI train reactor building sump suction inlet is not restricted by debris and suction inlet strainers show no evidence of structural distress or abnormal corrosion.

FREQUENCY LPI 3.5.3 In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.3-3 Amendment Nos. 398, 400, 399

Reactor Building Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS SR 3.6.5.1 SR 3.6.5.2 SR 3.6.5.3 SR 3.6.5.4 SURVEILLANCE

N 0 TE-----------------------

N o t required to be met for reactor building spray system vent flow paths opened under administrative control.

Verify each reactor building spray and cooling manual and non-automatic power operated valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

Operate each required reactor building cooling train fan unit for 2! 15 minutes.

Verify each required reactor building spray pump's developed head at the flow test point is greater than or equal to the required developed head.

Verify that the containment heat removal capability is sufficient to maintain post accident conditions within design limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the lnservice Testing Program In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.6.5-4 Amendment Nos. 398, 400, 399

Reactor Building Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS (continued)

SR 3.6.5.5 SR 3.6.5.6 SR 3.6.5.7 SR 3.6.5.8 SR 3.6.5.9 SURVEILLANCE Verify each automatic reactor building spray and cooling valve in each required flow path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

Verify each required reactor building spray pump starts automatically on an actual or simulated actuation signal.

Verify each required reactor building cooling train starts automatically on an actual or simulated actuation signal.

Verify each spray nozzle is unobstructed.

Verify reactor building spray locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.6.5-5 Amendment Nos.

398, 400, 399

ACTIONS DHR and Coolant Circulation - High Water Level 3.9.4 CONDITION REQUIRED ACTION COMPLETION TIME A. (continued}

A.4 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SR 3.9.4.1 SR 3.9.4.2 SURVEILLANCE Verify one DHR loop is in operation.

Verify required DHR loop locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.9.4-2 Amendment Nos.

398, 400, 399

ACTIONS DHR and Coolant Circulation - Low Water Level 3.9.5 CONDITION REQUIRED ACTION COMPLETION TIME B.

(continued)

B.3 Close all containment 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months penetrations providing direct access from containment atmosphere to outside atmosphere.

SURVEILLANCE REQUIREMENTS SR 3.9.5.1 SR 3.9.5.2 SR 3.9.5.3 SURVEILLANCE Verify one DHR loop is in operation.

Verify correct breaker alignment and indicated power available to the required OHR pump that is not in operation.

Verify OHR loop locations susceptible to gas accumulation are sufficiently filled with water.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.9.5-2 Amendment Nos. 398, 400. 399

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NOS. 270 AND 298 TO RENEWED FACILITY OPERATING LICENSE (RFOL)

NOS. DPR-71 AND DPR-62; AMENDMENT NO. 150 TO RFOL NO. NPF-63; AMENDMENT NOS. 282 AND 278 TO RFOL NOS. NPF-35 AND NPF-52; AMENDMENT NOS. 285 AND 264 TO RFOL NOS. NPF-9 AND NPF-17; AND AMENDMENT NOS. 398, 400, AND 399 TO RFOL NOS. DPR-38 DPR-47 AND DPR-55; DUKE ENERGY PROGRESS, INC.

DUKE ENERGY CAROLINAS, LLC BRUNSWICK STEAM ELECTRIC PLANT, UNIT NOS 1 AND 2 DOCKET NOS. 50-325 AND 50-324 SHEARON HARRIS NUCLEAR POWER PLANT, UNIT 1 DOCKET NO. 50-400 CATAWBA NUCLEAR STATION, UNITS 1AND2 DOCKET NOS. 50-413 AND 50-414 MCGUIRE NUCLEAR STATION, UNITS 1 AND 2 DOCKET NOS. 50-369 AND 50-370 OCONEE NUCLEAR STATION, UNITS 1, 2, AND 3 DOCKET NOS. 50-269, 50-270, AND 50-287 1

1.0 INTRODUCTION

By letter dated June 24, 2015 (Reference 1 ), as supplemented by letter dated January 18, 2016 (Reference 2), Duke Energy Progress, Inc., and Duke Energy Carolina, LLC (Duke Energy, the licensees), requested changes to the Technical Specifications (TSs) for the Brunswick Steam Electric Plant, Units 1 and 2 (Brunswick), Shearon Harris Nuclear Power Plant, Unit 1 (Harris),

Catawba Nuclear Station, Units 1 and 2 (Catawba), McGuire Nuclear Station, Units 1 and 2 (McGuire), and Oconee Nuclear Station, Units 1, 2, and 3 (Oconee). Specifically, the licensees requested to adopt U.S. Nuclear Regulatory Commission (NRC)-approved Technical Specifications Task Force (TSTF) Standard Technical Specifications (STS) Change Traveler TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation" (Reference 3).

The availability of this TS improvement was announced in the Federal Register on January 15, 2014 (79 FR 2700) as part of the Consolidated Line Item Improvement Process.

The proposed changes would revise Surveillance Requirements (SRs) related to gas accumulation for the Emergency Core Cooling System (ECCS) and Reactor Core Isolation Cooling (RCIC) system. The proposed changes would also add new SRs related to gas accumulation for the Residual Heat Removal (RHR) and RHR shutdown cooling systems. to the licensees' applications provided TS Bases, which are summary statements of the bases or reasons for the requested technical specifications, but will not become part of the technical specifications.

The licensees stated that they have reviewed the information contained in the model safety evaluation dated December 23, 2013 (Reference 4) and that the License Amendment Requests (LAR) are consistent with NRG-approved TSTF 523.

The supplemental letter dated January 18, 2016, provided additional information that clarified the applications, did not expand the scope of the application as originally noticed, and did not change the Nuclear Regulatory Commission (NRC) staff's original proposed no significant hazards consideration determinations as published in the Federal Register on August 14, 2015 (80 FR 48923). This Federal Register notice was corrected on August 20, 2015 (80 FR 50663).

2.0 REGULATORY EVALUATION

2.1 Background

Gas accumulation in reactor systems can result in water hammer, pump cavitation, and pumping of non-condensable gas into the reactor vessel. These effects may result in the subject system being unable to perform its specified safety function. The NRC issued Generic Letter (GL) 2008-01, Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems (Reference 5), to address the issue of gas accumulation in ECCS, OHR, and CS systems. The industry and NRC staff agreed that a change to the STS and plant-specific TS would be necessary to address some issues discussed in GL 2008-01. TSTF-523 contains changes to the TS SRs and TS Bases to address some of the concerns in GL 2008-01. The licensees proposed amending the Brunswick, Harris, Catawba, McGuire, and Oconee TSs using a plant-specific adoptions of the TSTF-523 changes.

2.2 Technical Specification Changes For Brunswick, changes were proposed for SRs 3.5.1.1, 3.5.1.2, 3.5.2.3, 3.5.2.4, 3.5.3.1, and 3.5.3.2, as well as the addition of new SRs 3.4.7.2, 3.4.8.2, 3.6.2.3.3, 3.9.7.2, and 3.9.8.2 to TS 3.4. 7, "RHR Shutdown Cooling System - Hot Shutdown," TS 3.4.8, "RHR Shutdown Cooling System - Cold Shutdown," TS 3.5.1, "ECCS - Operating," TS 3.5.2, "ECCS - Shutdown," TS 3.5.3, "RCIC System," TS 3.6.2.3, "RHR Suppression Pool Cooling," TS 3.9.7, "RHR-High Water Level," and TS 3.9.8, "RHR - Low Water Level," respectively.

For Harris, changes were proposed for SRs 4.5.2.b, 4.6.2.1.a, as well as the addition of new SRs 4.4.1.3.4, 4.4.1.4.1.3, 4.4.1.4.2.2, 4.6.2.1.e, 4.9.8.1.2, and 4.9.8.2.3 to TS 3/4.4.1.3, "Reactor Coolant System (RCS), Hot Shutdown," TS 3/4.4.1.4.1, "Reactor Coolant System, Cold Shutdown - Loops Filled," TS 3/4.4.1.4.2, "Reactor Coolant System, Cold Shutdown -

Loops Not Filled," TS 3/4.5.2, "ECCS Subsystems - Tavg Greater Than or Equal to 350°F," TS 3/4.6.2.1, "Containment Spray System," TS 3/4.9.8.1, "Residual Heat Removal and Coolant Circulation, High Water Level," and TS 3/4.9.8.2, "Refueling Operations, Low Water Level,"

respectively.

For Catawba, changes were proposed for SRs 3.5.2.2, 3.5.2.3, 3.6.6.1, as well as the addition of new SRs 3.4.6.4, 3.4.7.4, 3.4.8.3, 3.6.6.8, 3.9.4.2, and 3.9.5.3 to TS 3.4.6, "RCS Loops -

MODE 4," TS 3.4.7, "RCS Loops - MODE 5, Loops Filled," TS 3.4.8, "RCS Loops - MODE 5, Loops Not Filled," TS 3.5.2, "ECCS - Operating," TS 3.6.6, "Containment Spray System," TS 3.9.4, "RHR and Coolant Circulation - High Water Level," and TS 3.9.5, "RHR and Coolant Circulation - Low Water Level," respectively.

For McGuire, changes were proposed for SRs 3.5.2.2, 3.5.2.3, 3.6.6.1, as well as the addition of new SRs 3.4.6.4, 3.4.7.4, 3.4.8.3, 3.6.6.8, 3.9.5.2, and 3.9.6.3 to TS 3.4.6, "Reactor Coolant System (RCS) Loops - MODE 4," TS 3.4.7, "RCS Loops - MODE 5, Loops Filled," TS 3.4.8, "RCS Loops - MODE 5, Loops Not Filled," TS 3.5.2, "ECCS - Operating," TS 3.6.6, "Containment Spray System," TS 3.9.4, "RHR and Coolant Circulation - High Water Level," and TS 3.9.5, "RHR and Coolant Circulation - Low Water Level," respectively.

For Oconee, changes were proposed for SRs 3.5.2.1, 3.5.2.2, 3.5.3.1, 3.5.3.2 and 3.6.5.1 as well as the addition of new SRs 3.4.6.3, 3.4.7.4, 3.4.8.3, 3.6.5.9, 3.9.4.2, and 3.9.5.3 to TS 3.4.6, "Reactor Coolant System (RCS) Loops - MODE 4," TS 3.4.7, "RCS Loops - MODE 5, Loops Filled," TS 3.4.8, "RCS Loops - MODE 5, Loops Not Filled," TS 3.5.2, "High Pressure Injection," TS 3.5.3, "Low Pressure Injection," TS 3.6.5, "Reactor Building Spray and Cooling Systems," TS 3.9.4, "OHR and Coolant Circulation - High Water Level," and TS 3.9.5, "OHR and Coolant Circulation - Low Water Level," respectively.

2.3 Regulatory Review The regulations in Appendix A to Title 10 of the Code of Federal Regulations (10 CFR) Part 50 or similar plant-specific principal design criteria provide design requirements. The regulatory requirements of 10 CFR Part 50, Appendix A, that are applicable to gas management in the subject systems include: General Design Criteria (GDC) 1, 34, 35, 36, 37, 38, 39 and 40.

GDC 1 requires that the subject systems be designed, fabricated, erected, and tested to quality standards. GDC 34 requires an RHR system designed to maintain specified acceptable fuel design limits and to meet design conditions that are not exceeded if a single failure occurs and specified electrical power systems fail. GDC 35, 36, and 37 require an ECCS design that meets performance, inspection, and testing requirements. GDC 38, 39, and 40 require a containment heat removal system design that meets performance, inspection, and testing requirements.

The NRC staff model SE for adoption of TSTF-523 was written for plants licensed to the GDC.

Brunswick and Oconee were licensed to design criteria that, for the purposes of TSTF-523 adoption, conform to the GDC. Section 3.1 of the Brunswick and Oconee Updated Final Safety Analysis Reports (UFSARs) discuss Brunswick and Oconee conformance to the GDC.

Additionally, the regulations in 10 CFR 50.46 provide specified ECCS performance criteria.

Quality assurance criteria provided in 10 CFR Part 50, Appendix B, that apply to gas management in the subject systems include: Criteria Ill, V, XI, XVI, and XVII. Criteria Ill and V require measures to ensure that applicable regulatory requirements and the design basis, as defined in 10 CFR 50.2, "Definitions," and as specified in the licensees' applications, are correctly translated into controlled specifications, drawings, procedures, and instructions.

Criterion XI requires a test program to ensure that the subject systems will perform satisfactorily in service and requires that test results shall be documented and evaluated to ensure that test requirements have been satisfied. Criterion XVI requires measures to ensure that conditions adverse to quality, such as failures, malfunctions, deficiencies, deviations, defective material and equipment, and non-conformances, are promptly identified and corrected, and that significant conditions adverse to quality are documented and reported to management.

Criterion XVII requires maintenance of records of activities affecting quality.

The NRC's regulatory requirements related to the content of the TSs are contained in 10 CFR 50.36(c). The regulations at 10 GFR 50.36 require that the TSs include items in the following categories: (1) safety limits, limiting safety systems settings, and limiting control settings; (2) Limiting Conditions for Operation (LCO); (3) SRs; (4) design features; and (5) administrative controls. 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. Typically, TS Section 5 requires that licensees establish, implement, and maintain written procedures covering the applicable procedures recommended in Appendix A to Regulatory Guide (RG) 1.33, "Quality Assurance Program Requirements (Operation)." Appendix A to RG 1.33 identifies instructions for filling and venting the ECCS and OHR system, as well as for draining and refilling heat exchangers. Standard TSs and most licensee TSs include SRs to verify that at least some of the subject systems piping is filled with water.

The NRC's guidance for the format and content of licensee TSs can be found in NUREG-1430, Standard Technical Specifications Babcock and Wilcox Plants (Reference 6), NUREG-1431, Standard Technical Specifications Westinghouse Plants (Reference 7), and NUREG-1433, Standard Technical Specifications General Electric Plants Boiling Water Reactor (BWR)/4 (Reference 8). The TS for Brunswick, Catawba, McGuire, and Oconee are in the STS format.

The Harris TS are in the format of an earlier version of Westinghouse TS, but the TSTF-523 changes can be applied to Harris TS with minor changes to the format and numbering of the TSTF-523 changes.

The NRC staff recognizes that the Standard Review Plan (SRP) is not the regulatory basis of the proposed TSs changes, and that the licensees are not required to confirm that the SRP guidance is applicable to Brunswick, Harris, Catawba, McGuire, and Oconee.

Regulatory guidance for the NRC staff's review of containment heat removal systems, ECCS, and RHR systems is provided in the following revisions and sections of NUREG-0800, "Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants:

LWR Edition" (SRP, Reference 9)) during the review.

Revision 3 of SRP, Section 6.2.2, "Containment Heat Removal Systems," (Reference 10),

provides the procedures concerning the review of containment heat removal under post-accident conditions to help ensure compliance with GDC 38, 39, and 40.

Revision 3 of SRP, Section 6.3, "Emergency Core Cooling System," (Reference 11),

provides the procedures concerning the review of ECCS to help ensure compliance with GDC 35, 36, and 37.

Revision 5 of SRP, Section 5.4.7, "Residual Heat Removal System," (Reference 12),

provides the procedures concerning the review of RHR system as it is used to cool the Reactor Coolant System during and following shutdown to help ensure compliance with GDC 34.

3.0 TECHNICAL EVALUATION

3.1 Site Specific TS Changes 3.1.1 Brunswick TS Changes For Brunswick, the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1433, Standard Technical Specifications General Electric Plants BWR/4, by TSTF-523.

The NRC staff compared the proposed changes to the existing SRs, as well as the regulatory requirements of 1 O CFR 50.36(c).

Specifically, for Brunswick, Duke Energy proposed the following TS changes:

(1)

Add SR 3.4.7.2, which states, "Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water" together with a note that states "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 dome pressure is less than the RHR shutdown cooling isolation pressure" and a frequency of 31 days.

(2)

Add SR 3.4.8.2, which states, "Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of 31 days.

(3)

Revise the language for SR 3.5.1.1 from "Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve" to "Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water."

(4)

Revise the Frequency for SR 3.5.1.1 from 31 days to 92 days.

(5)

Annotate the existing note to SR 3.5.1.2 as NOTE 1 and add NOTE 2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(6)

Revise the language for SR 3.5.2.3 from "Verify, for each ECCS injection/spray subsystem, the piping is filled with water from the pump discharge valve to the injection valve" to "Verify, for each ECCS injection/spray subsystem, locations susceptible to gas accumulation are sufficiently filled with water."

(7)

Annotate the existing note to SR 3.5.2.4 as NOTE 1 and add NOTE 2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(8)

Revise the language for SR 3.5.3.1 from "Verify the RCIC System piping is filled with water from the pump discharge valve to the injection valve" to "Verify the RCIC system locations susceptible to gas accumulation are sufficiently filled with water."

(9)

Revise the Frequency for SR 3.5.3.1 from 31 days to 92 days.

(10)

Add a note to SR 3.5.3.2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(11)

Add SR 3.6.2.3.3, which states, "Verify RHR suppression pool cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of 92 days.

(12)

Add SR 3.9.7.2, which states, "Verify required RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of 31 days.

(13)

Add SR 3.9.8.2, which states, "Verify RHR shutdown cooling subsystem locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of 31 days.

3.1.2 Harris TS Changes For Harris, the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1431, Standard Technical Specifications Westinghouse Plants, by TSTF-523.

The NRC staff compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36(c).

Specifically, for Harris, Duke Energy proposed the following TS changes:

( 1)

Add SR 4.4.1.3.4, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days." with a note that states "Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4" and a frequency of 31 days.

(2)

Add SR 4.4.1.4.1.3, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days."

(3)

Renumber SR 4.4.1.4.2 to SR 4.4.1.4.2.1 and add SR 4.4.1.4.2.2, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days."

(4)

Revise the language for SR 4.5.2.b.1 from "Verify ECCS piping is full of water" to "Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water."

(5)

Add a note to SR 4.5.2.b.2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(6)

Add a note to SR 4.6.2.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(7)

Add SR 4.6.2.1.e, which states, "At least once per 92 days by verifying that CS locations susceptible to gas accumulation are sufficiently filled with water."

(8)

Renumber SR 4.9.8.1 to SR 4.9.8.1.1 and add SR 4.9.8.1.2, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days."

(9)

Add SR 4.9.8.2.3, which states, "Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water at least once per 31 days."

3. 1. 3 Catawba TS Changes For Catawba, the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1431, Standard Technical Specifications Westinghouse Plants, by TSTF-523.

The NRC staff compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36(c).

Specifically, for Catawba, Duke Energy proposed the following TS changes:

(1)

Add SR 3.4.6.4, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a note that states "Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4" and a frequency of "In accordance with the Surveillance Frequency Control Program."

(2)

Add SR 3.4.7.4, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(3)

Add SR 3.4.8.3, which states "Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(4)

Add a note to SR 3.5.2.2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(5)

Revise the language for SR 3.5.2.3 from "Verify ECCS piping is full of water" to "Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water."

(6)

Add a note to SR 3.6.6.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(7)

Add SR 3.6.6.8, which states, "Verify containment spray locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(8)

Add SR 3.9.4.2, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(9)

Add SR 3.9.5.3, which states, "Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

3.1.4 McGuire TS Changes For McGuire, the proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1431, Standard Technical Specifications Westinghouse Plants, by TSTF-523.

The NRC staff compared the proposed changes to the existing SRs, as well as the regulatory requirements of 1 O CFR 50.36(c).

Specifically, for McGuire, Duke Energy proposed the following TS changes:

(1)

Add SR 3.4.6.4, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a note that states "Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4" and a frequency of "In accordance with the Surveillance Frequency Control Program."

(2)

Add SR 3.4.7.4, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(3)

Add SR 3.4.8.3, which states "Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(4)

Add a note to SR 3.5.2.2, which states, "Not required to be met for system vent flow paths opened under administrative control."

(5)

Revise the language for SR 3.5.2.3 from "Verify ECCS piping is full of water" to "Verify ECCS locations susceptible to gas accumulation are sufficiently filled with water."

(6)

Add a note to SR 3.6.6.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(7)

Add SR 3.6.6.8, which states, "Verify containment spray locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(8)

Add SR 3.9.5.2, which states, "Verify required RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(9)

Add SR 3.9.6.3, which states, "Verify RHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

3.1.5 Oconee TS Changes For Oconee, he proposed change adopted the TS format and content, to the extent practicable, contained in the changes made to NUREG-1430, Standard Technical Specifications Babcock and Wilcox Plants, by TSTF-523.

The NRC staff compared the proposed changes to the existing SRs, as well as the regulatory requirements of 10 CFR 50.36(c).

Specifically, for Oconee, Duke Energy proposed the following TS changes:

(1)

Add SR 3.4.6.3, which states, "Verify required OHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a note that states "Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering MODE 4" and a frequency of "In accordance with the Surveillance Frequency Control Program."

(2)

Add SR 3.4.7.4, which states, "Verify required OHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(3)

Add SR 3.4.8.3, which states "Verify OHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(4)

Add a note to SR 3.5.2.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(5)

Delete the Note from SR 3.5.2.2 which states "Not applicable to operating HPI pump(s)."

and revise the language for SR 3.5.2.2 from "Vent each HPI pump casing," to "Verify HPI locations susceptible to gas accumulation are sufficiently filled with water."

(6)

Add a note to SR 3.5.3.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(7)

Delete the Note from SR 3.5.3.2 which states "Not applicable to operating LPI pump(s)."

and revise the language for SR 3.5.3.2 from "Vent each LPI pump casing," to "Verify LPI locations susceptible to gas accumulation are sufficiently filled with water."

(8)

Add a note to SR 3.6.5.1, which states, "Not required to be met for system vent flow paths opened under administrative control."

(9)

Add SR 3.6.5.9, which states, "Verify reactor building spray locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(10)

Add SR 3.9.4.2, which states, "Verify required OHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

(11)

Add SR 3.9.5.3, which states, "Verify OHR loop locations susceptible to gas accumulation are sufficiently filled with water" with a frequency of "In accordance with the Surveillance Frequency Control Program."

3.2 NRC Staff Review of TS Changes The new language for the SRs, as stated above, was developed using licensee responses to GL 2008-01 and the NRC discussion contained in Task Interface Agreement (TIA) 2008-03, Emergency Core Cooling System Voiding Relative to Compliance with SRs 3.5.1.1, 3.5.2.3, and 3.5.3.1 (Reference 13). Many of the GL 2008-01 responses stated that licensees identified system locations susceptible to gas accumulation. In the TIA, the NRC stated that the intent of the TS SRs, which state "full of water," may be met if the licensee can establish, through an Operability Determination, that there is a reasonable expectation that the system in question will perform its specified safety function. Therefore the phrase, "sufficiently filled with water" was recommended for the proposed TS changes. In the TS, "sufficiently filled with water" is understood to mean "sufficiently filled with water to support Operability." The regulation at 10 CFR 50.36(c)(3) states that one of the purposes of the SR is to verify that the LCO is met.

Therefore, the new SR language, "Verify the [system name] locations susceptible to gas accumulation are sufficiently filled with water," is acceptable since this language will allow the licensees to make a conclusion as to whether or not a system is operable.

The language for the notes that state that the SR does not have to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after entering Mode 4 is acceptable because the note provides a limited time to perform the Surveillance after entering the Applicability of the LCO; however, under the STS usage rules (STS Section 1.4), the requirement to manage gas accumulation is not affected. Licensees must have confidence that the SR can be met or the LCO must be declared not met.

The language for the notes that allow the SRs to not be met for system vent flow paths opened under administrative control is necessary to allow the licensees to credit administratively controlled manual action to close the system vent flow path in order to maintain system Operability during system venting and performance of the proposed gas accumulation SR.

Therefore, these notes are acceptable.

In Reference 1, the licensees proposed variations to the surveillance frequency in the following SRs:

Brunswick SR 3.5.1.1, "ECCS - Operating" (TS 3.5.1)

Brunswick SR 3.5.3.1, "RCIC System" (TS 3.5.3)

Brunswick SR 3.6.2.3.3, "RHR Suppression Pool Cooling" (TS 3.6.2.3)

Harris SR 4.6.2.1.e, "Containment Spray System" (TS 3.6.2.1)

Catawba SR 3.6.6.8, "Containment Spray System" (TS 3.6.6)

McGuire SR 3.6.6.8, "Containment Spray System" (TS 3.6.6)

Oconee SR 3.6.5.9, "Reactor Building Spray" (TS 3.6.5)

Specifically, for the above SRs, the licensees requested a 92-day surveillance frequency as opposed to the 31-day surveillance frequency delineated in TSTF-523. The licensees justified this variation by stating, in part, that:

Gas accumulation for these systems is currently monitored in accordance with each site's response to NRC Generic Letter (GL) 2008-01. Review of plant experience over a three year period ending on April 30, 2015 shows no instances of gas accumulation which would challenge the capability of these systems to perform their safety function.

Therefore, a Surveillance Frequency of 92 days is considered reasonable to provide assurance that these systems are sufficiently filled with water. For plants that have not adopted the [Surveillance Frequency Control Program] SFCP

([Brunswick and Harris]), the TS markups provided in Attachment 1 reflect this variation. For plants that have adopted the SFCP ([Catawba, McGuire, and Oconee]), the initial frequency established under the SFCP will be 92 days, and subsequent changes will be controlled under the provisions of the SFCP.

The licensees also provided a review of trending data for the systems noted above, detailing any instances when gas had been detected in the system. No gas was detected in any of the systems with the exception of two instances at Harris which were described and found to be within the allowable void size.

During its review of the proposed 92-day surveillance frequency, the NRC staff requested that the licensees provide more detailed surveillance history data regarding gas accumulation at Brunswick and Harris. The licensees provided the requested information in Reference 2. After reviewing the licensees' response, the NRC staff determined that the proposed 92-day surveillance frequency, for the SRs listed above, is supported by the operating history at Brunswick and Harris and, therefore, acceptable.

For Catawba, McGuire, and Oconee, the surveillance frequency for the above listed SRs is controlled in accordance with the SFCP. As stated above, the licensees have established the initial frequency for these SRs at 92 days. The NRC staff has determined that the initial 92-day surveillance frequency is acceptable based on a review of the trending data. The NRC staff has further determined that controlling subsequent changes of these surveillance frequencies under the provisions of the SFCP is consistent with TSTF-523 and, therefore, acceptable.

The NRC staff determined that the proposed SRs meet the regulatory requirements of 10 CFR 50.36 because they provide assurance that the necessary quality of systems and components will be maintained and that the LCO will be met. Therefore, the NRC staff concludes that the proposed amendments are acceptable.

4.0 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 amendments. The State officials had no comments.

5.0 ENVIRONMENTAL CONSIDERATION

The amendments change requirements with respect to installation or use of a facility component located within the restricted area as defined in 10 CFR Part 20 and changes SRs. The NRC staff has determined that the amendments involve 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 amendments involve no significant hazards consideration, and there has been no public comment on such finding (80 FR 48923 and 80 FR 50663). Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 1 O CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendment.

6.0 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 Commission's 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.

7.0 REFERENCES

1. Repko, Regis to U.S. Nuclear Regulatory Commission (NRC), Brunswick Steam Electric Plant, Unit Nos. 1 and 2; Shearon Harris Nuclear Power Plant, Unit 1; Catawba Nuclear Station, Units 1 and 2; McGuire Nuclear Station, Units 1 and 2; and Oconee Nuclear Station Units 1, 2, and 3, Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," Using The Consolidated Line Item Improvement Process, June 24, 2015 (Agencywide Documents Access and Management System (ADAMS) Package Accession No. ML15175A438).

2. Repko, Regis to NRC, Brunswick Steam Electric Plant, Unit Nos. 1 and 2; Shearon Harris Nuclear Power Plant, Unit 1, Response to Request for Additional Information Regarding, Application to Revise Technical Specifications to Adopt TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," January 18, 2016 (ADAMS Accession No. ML16018A001).

3. TSTF-523, Generic Letter 2008-01, Managing Gas Accumulation, Revision 2, February 21, 2013 (ADAMS Accession No. ML13053A075).

4. NRC Letter, Model Safety Evaluation for Plant-Specific Adoption of Technical Specifications Task Force Traveler TSTF-523, Revision 2, "Generic Letter 2008-01, Managing Gas Accumulation," Using the Consolidated Line Item Improvement Process, December 23, 2013 (ADAMS Accession No. ML13255A169).

5. NRC Generic Letter 2008-01, Managing Gas Accumulation in Emergency Core Cooling, Decay Heat Removal, and Containment Spray Systems, January 11, 2008 (ADAMS Accession No. ML072910759).

6. NRC NUREG-1430, Standard Technical Specifications, Babcock and Wilcox Plants, Revision 4.0, April 2012 (ADAMS Accession No. ML12100A177).

7. NRC NUREG-1431, Standard Technical Specifications, Westinghouse Plants, Revision 4.0, April 2012 (ADAMS Accession No. ML12100A222).

8. NRC NUREG-1433, Standard Technical Specifications, General Electric Plants Boiling Water Reactor (BWR)/4, Revision 4.0, April 2012 (ADAMS Accession No. ML12104A192).

9. NRC NUREG-0800, Standard Review Plan for the Review of Safety Analysis Reports for Nuclear Power Plants: LWR Edition, Revision 3, March 2007 (ADAMS Package Accession No. ML070660036).

10. SRP Section 6.2.2, Containment Heat Removal Systems, Revision 3, March 2007 (ADAMS Accession No. ML070160661).

11. SRP Section 6.3, Emergency Core Cooling System, Revision 3, March 2007 (ADAMS Accession No. ML070550068).

12. SRP Section 5.4.7, Residual Heat Removal System, Revision 5, May 2010 (ADAMS Accession No. ML100680577).

13. Task Interface Agreement 2008-03, Emergency Core Cooling System Voiding Relative to Compliance with SRs 3.5.1.1, 3.5.2.3, and 3.5.3.1, October 21, 2008 (ADAMS Accession No. ML082560209).

Principal Contributor:

M. Hamm W. Lyon Date of issuance: April 2 9, 2O1 6

ML16085A113

via memo dated **via e-mail dated OFFICE DORL/LPL2-1 /PM DORL/LPL2-1/LA DSS/SRXB/BC (A)

DSS/STSB/BC NAME JWhited SFigueroa EOesterle**

RElliott*

DATE 04/14/2016 04/14/2016 03/29/2016 03/04/2016 OFFICE OGC (NLO)

DORL/LPL2-1 /BC DORL/LPL2-2/BC DORL/LPL2-1 /PM NAME DRoth (w/ comments)

MMarkley BBeasley JWhited DATE 04/15/2016 04/29/2016 04/25/2016 04/29/2016

v t e Letter Sequence Approval
CAC:MF6412, Generic Letter 2008-01, Managing Gas Accumulation (Approved, Closed) CAC:MF6413, (Approved, Closed) CAC:MF6422, (Approved, Closed)
Initiation Request, Request Acceptance... Administration Questions 18 December 2015 Answers Results Approval, Approval Other: L-16-188, Amendment No. 6 to Indemnity Agreement No. B-98, ML16078A092, ML16083A512
MONTHYEAR2015-06-30 [Table View]

ML16085A113

Text

SUBJECT:

Dear Mr. Repko:

Enclosures:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

2.1 Background

3.0 TECHNICAL EVALUATION

4.0 STATE CONSULTATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

7.0 REFERENCES

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