Text

Issuance of Amendments Regarding Adoption of Technical Specification Task Force (TSTF)-425, Revision 3, Relocate Surveillance Frequencies to Licensee Control - Risk-Informed Technical Specification Task Force
	ML110470446
Person / Time
Site:	Oconee
Issue date:	03/21/2011
From:	Stang J; Plant Licensing Branch II
To:	Gillespie P; Duke Energy Carolinas
	Stang J, NRR/DORL, 415-1345
References
	TAC ME3840, TAC ME3841, TAC ME3842
	Download: ML110470446 (131)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 March 21, 2011 Mr. Preston Gillespie Site Vice President Oconee Nuclear Station Duke Energy Carolinas, LLC 7800 Rochester Highway Seneca, SC 29672

SUBJECT:

OCONEE NUCLEAR STATION, UNITS 1,2, AND 3, ISSUANCE OF AMENDMENTS REGARDING ADOPTION OF TECHNICAL SPECIFICATION TASK FORCE (TSTF) -425, REVISION 3, "RELOCATE SURVEILLANCE FREQUENCIES TO LICENSEE CONTROL - RISK-INFORMED TECHNICAL SPECIFICATION TASK FORCE (RITSTF) INITIATIVE 5b" (TAC NOS. ME3840, ME3841, AND ME3842)

Dear Mr. Gillespie:

The Nuclear Regulatory Commission (NRC) has issued the enclosed Amendment Nos. 372, 374, and 373 to Renewed Facility Operating Licenses DPR-38, DPR-47, and DPR-55, for the Oconee Nuclear Station, Units 1,2, and 3, respectively. The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated March 17,2010, as supplemented January 14, 2011.

These amendments revise the TSs to adopt the NRC-approved Technical Specification Task Force (TSTF) - 425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control

[Risk-Informed Technical Specification Task Force] (RITSTF) Initiative 5b". When implemented, TSTF-425 Revision 3 relocates most periodic frequencies of TS surveillances to a licensee-controlled program, the Surveillance Frequency Control Program, and will provide requirements for the new program in the Administrative Controls Section of TSs.

The licensee proposed changes to TS Sections 5.5.18, 5.5.19, and 5.5.20. These proposed changes are outside the scope of TSTF-425, Revision 3. The NRC staff will review these proposed TS changes in a separate amendment.

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.

P. Gillespie

- 2 If you have any questions, please call me at 301-415-1345.

n Stang. Senior Project Manager P nt Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-269, 50-270, and 50-287

Enclosures:

1. Amendment No. 372 to DPR-38

2. Amendment No. 374 to DPR-47

3. Amendment No. 373 to DPR-55

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

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. 372 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 filed by the Duke Energy Carolinas, LLC (the licensee), dated March 17,2010, and supplemented January 14, 2011, 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 setforth 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

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.3 72

, 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 180 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION C~*

Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to Renewed Facility Operating License No. DPR-38 and the Technical Specifications Date of Issuance: March 21, 2011

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. 374 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 filed by the Duke Energy Carolinas, LLC (the licensee), March 17,2010, and supplemented January 14, 2011, 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 setforth 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

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. 374

, 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 180 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to Renewed Facility Operating License No. DPR-47 and the Technical Specifications Date of Issuance: March 21, 2011

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 OPERATING LICENSE Amendment No. 373 Renewed License No. DPR-55

1.

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

A.

The application for amendment to the Oconee Nuclear Station, Unit 3 (the facility),

Renewed Facility Operating License No. DPR-55 filed by the Duke Energy Carolinas, LLC (the licensee), March 17, 2010, and supplemented January 14, 2011, 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

2.

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

B.

Technical Specifications The Technical Specifications contained in Appendix A, as revised through Amendment No. 373

, 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 180 days of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Gloria Kulesa, Chief Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to Renewed Facility Operating License No. DPR-55 and the Technical Specifications Date of Issuance:

March 21, 2011

ATTACHMENT TO LICENSE AMENDMENT NO. 372 RENEWED FACILITY OPERATING LICENSE NO. DPR-38 DOCKET NO. 50-269 AND TO LICENSE AMENDMENT NO. 374 RENEWED FACILITY OPERATING LICENSE NO. DPR-47 DOCKET NO. 50-270 AND TO LICENSE AMENDMENT NO. 373 RENEWED FACILITY OPERATING LICENSE NO. DPR-55 DOCKET NO. 50-287 Replace the following pages of the Licenses and the Appendix A Technical Specifications (TSs) with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Remove Pages Insert Pages Licenses Licenses License No. DPR-38, page 3 License No. DPR-38, page 3 License No. DPR-47, page 3 License No. DPR-47, page 3 License No. DPR-55, page 3 License No. DPR-55, page 3 TSs TSs 1.1-6 1.1-6 3.1.1-1 3.1.1-1 3.1.2-2 3.1.2-2 3.1.4-4 3.1.4-4 3.1.5-2 3.1.5-2 3.1.6-1 3.1.6-1 3.1.7-1 3.1.7-1 3.1.8-2 3.1.8-2 3.2.1-3 3.2.1-3

Oconee 1/2/3

-2 Remove Pages Insert Pages 3.2.2-1 3.2.2-1 3.2.3-4 3.2.3-4 3.3.1-3 3.3.1-3 3.3.1-4 3.3.1-4 3.3.3-2 3.3.3-2 3.3.4-2 3.3.4-2 3.3.5-2 3.3.5-2 3.3.5-3 3.3.5-3 3.3.6-2 3.3.6-2 3.3.7-2 3.3.7-2 3.3.8-4 3.3.8-4 3.3.9-2 3.3.9-2 3.3.10-2 3.3.10-2 3.3.11-2 3.3.11-2 3.3.12-2 3.3.12-2 3.3.13-1 3.3.13-1 3.3.14-2 3.3.14-2 3.3.15-1 3.3.15-1 3.3.16-2 3.3.16-2 3.3.17-1 3.3.17-1 3.3.18-2 3.3.18-2 3.3.19-2 3.3.19-2 3.3.20-2 3.3.20-2 3.3.21-2 3.3.21-2 3.3.22-1 3.3.22-1 3.3.23-2 3.3.23-2 3.3.27-3 3.3.27-3 3.3.28-1 3.3.28-1 3.4.1-2 3.4.1-2 3.4.3-2 3.4.3-2 3.4.4-1 3.4.4-1 3.4.5-2 3.4.5-2 3.4.6-2 3.4.6-2 3.4.7-3 3.4.7-3 3.4.8-2 3.4.8-2 3.4.9-2 3.4.9-2 3.4.11-2 3.4.11-2 3.4.12-4 3.4.12-4

Oconee 1/2/3

- 3 Remove Pages Insert Pages 3.4.12-5 3.4.12-5 3.4.13-3 3.4.13-3 3.4.14-3 3.4.14-3 3.4.15-3 3.4.15-3 3.5.1-2 3.5.1-2 3.5.1-3 3.5.2-4 3.5.2-4 3.5.2-5 3.5.2-5 3.5.3-2 3.5.3-2 3.5.3-3 3.5.3-3 3.5.4-2 3.5.4-2 3.6.2-4 3.6.2-4 3.6.3-4 3.6.3-4 3.6.3-5 3.6.3-5 3.6.4-1 3.6.4-1 3.6.5-4 3.6.5-4 3.6.5-5 3.6.5-5 3.7.2-2 3.7.2-2 3.7.4-1 3.7.4-1 3.7.5-4 3.7.5-4 3.7.6-1 3.7.6-1 3.7.7-2 3.7.7-2 3.7.7-3 3.7.7-3 3.7.8-1 3.7.8-1 3.7.8-2 3.7.8-2 3.7.8-3 3.7.8-3 3.7.9-2 3.7.9-2 3.7.11-1 3.7.11-1 3.7.12-2 3.7.12-2 3.7.14-1 3.7.14-1 3.7.16-3 3.7.16-3 3.8.1-13 3.8.1-13 3.8.1-14 3.8.1-14 3.8.1-15 3.8.1-15 3.8.1-16 3.8.1-16 3.8.1-17 3.8.1-17 3.8.3-4 3.8.3-4 3.8.5-3 3.8.5-3

Oconee 1/2/3 Remove Pages 3.8.6-2 3.8.7-2 3.8.8-4 3.8.9-2 3.9.1-1 3.9.2-2 3.9.3-2 3.9.4-2 3.9.5-2 3.9.6-2 3.9.7-2 3.10.1-3 3.10.1-4 3.10.1-5 3.10.2-2 5.0-22

- 4 Insert Pages 3.8.6-2 3.8.7-2 3.8.8-4 3.8.9-2 3.9.1-1 3.9.2-2 3.9.3-2 3.9.4-2 3.9.5-2 3.9.6-2 3.9.7-2 3.10.1-3 3.10.1-4 3.10.1-5 3.10.2-2 5.0-22

- 3 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.3 7'2 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. 372 I

-3 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.3 74 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. 374

-3 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 N0373 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. 373

1.1 Definitions 1.1 Definitions THERMAL POWER THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

OCONEE UNITS 1, 2, & 3 1,1-6 Amendment Nos.372, 374, 373

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

LCO 3.1.1 The SDM shall be within the limit specified in the COLR.

APPLICABILITY:

MODES 3, 4, and 5.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

SDM not within limit.

A.1 Initiate boration to 15 minutes restore SDM to within limit.

I SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.1.1 Verify SDM is within the limit specified in the COLR.

FREQUENCY I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.1.1-1 Amendment Nos. 372, 374, 373 I

Reactivity Balance 3.1.2 SURVEILLANCE REQUIREMENTS SURVEI LLANCE SR 3.1.2.1

NOTE S -----------------------

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

Verify measured core reactivity balance is within +/-1 % L'lk/k of predicted values.

FREQUENCY Prior to entering MODE 1 after each fuel loading AND

N 0 T E ----------

Only required after 60 EFPD In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.1.2-2 Amendment Nos. 372,374, 373 I

CONTROL ROD Group alignment Limits 3.1.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual CONTROL ROD positions are within 6.5% of their group average height.

In accordance with the Surveillance Frequency Control Program SR 3.1.4.2 Verify CONTROL ROD freedom of movement (trippability) by moving each individual CONTROL ROD that is not fully inserted by an amount in any direction sufficient to demonstrate the absence of thermal binding.

In accordance with the Surveillance Frequency Control Program SR 3.1.4.3 Verify the rod drop time for each CONTROL ROD, from the fully withdrawn position, is

0;; 1.66 seconds at reactor coolant full flow conditions or :0;; 1.40 seconds at no flow conditions from power interruption at the CONTROL ROD drive breakers to % insertion (25% withdrawn position).

Prior to reactor criticality after each removal of the reactor vessel head OCONEE UNITS 1, 2, &3 3.1.4-4 Amendment Nos. 372, 374, 373 I

Safety Rod Position Limits 3.1.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TI ME B.

More than one safety rod not fully withdrawn.

B.1.1 Verify SDM is within the limit specified in the COLR.

OR B.1.2 Initiate boration to restore SDM to within limit.

AND B.2 Be in MODE 3.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 1 hour 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each safety rod is fully withdrawn.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.1.5-2 Amendment Nos. 372, 374, 373 1

APSR Alignment Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 AXIAL POWER SHAPING ROD (APSR) Alignment Limits LCO 3.1.6 Each APSR shall be OPERABLE and aligned within 6.5% of its group average height.

APPLICABILITY:

MODES 1 and 2, when the APSRs are not fully withdrawn.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One APSR inoperable, not aligned within its limits, or both.

A.1 Perform SR 3.2.2.1.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after each APSR movement B.

Required Action and associated Completion Time not met.

8.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.6.1 Verify position of each APSR is within 6.5% of the group average height.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.1.6-1 Amendment Nos.372, 374, 373 I

Position Indicator Channels 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Position Indicator Channels LCO 3.1.7 One position indicator channel for each CONTROL ROD and APSR shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

The required position indicator channel inoperable for one or more rods.

A.1 Declare the rod(s) inoperable.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.1.7.1 Perform CHANNEL CHECK of required position indicator channel.

FREQUENCY In accordance with the SUrveillance Frequency i Control Program OCONEE UNITS 1, 2, & 3 3.1.7-1 Amendment Nos. 372, 374, 373 I

PHYSICS TESTS Exceptions - MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETIOI'J TIME B.

SDM not within limit.

8.1 AND B.2 Initiate boration to restore SDM to within limit.

Suspend PHYSICS TESTS exceptions.

15 minutes 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months C.

Nuclear overpower trip set point is not within limit.

OR Nuclear instrumentation wide range high startup rate COI'JTROL ROD withdrawal inhibit inoperable.

C.1 Suspend PHYSICS TESTS exceptions.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Verify nuclear overpower trip setpoint is

5% RTP.

Once within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months prior to performance of PHYSICS TESTS SR 3.1.8.2 Verify SDM is within the limit specified in the COLR.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.1.8-2 Amendment Nos. 372, 374, 3731

Regulating Rod Position Limits 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.1.1 Verify regulating rod groups are within the sequence and overlap limits as specified in the COLR.

FREQUENCY In accordance with the Surveillance Frequency

Control Program SR 3.2.1.2 Verify regulating rod groups meet the position limits as specified in the COLR.

SR 3.2.1.3 Verify SOM to be within the limit as specified in the COLR.

In accordance with the Surveillance Frequency Control Program Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior to achieving criticality OCONEE UNITS 1, 2, & 3 3.2.1-3 Amendment Nos. 372, 374, 373/

AXIAL POWER IMBALANCE Operating Limits 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 AXIAL POWER IMBALANCE Operating Limits LCO 3.2.2 AXIAL POWER IMBALANCE shall be maintained within the limits specified in the COLR.

APPLICABILITY:

MODE 1 with THERMAL POWER> 40% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

AXIAL POWER IMBALANCE not within limits.

A.1 Restore AXIAL POWER IMBALANCE to within limits.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months B.

Required Action and associated Completion Time not met.

B.1 Reduce THERMAL POWER to

<:;40% RTP.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.2.1 Verify AXIAL POWER IMBALANCE is within limits as specified in the COLR.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.2.2-1 Amendment Nos. 372, 374, 373 I

QPT 3.2.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.3.1 Verify QPT is within limits as specified in the COLR.

FREQUENCY In accordance with the Surveillance Frequency Control Program When QPT has been restored to less than or equal to the steady state limit, 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months for 12 consecutive hours, or until verified acceptable at

95% RTP OCONEE UNITS 1, 2, & 3 3.2.3-4 Amendment Nos. 372, 374, 3731

3.3.1 RPS Instrumentation SURVEILLANCE REQUIREMENTS Refer to Table 3.3.1-1 to determine which SRs apply to each RPS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency I Control Program SR 3.3.1.2

NOTE--'----------------------

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

Compare results of calorimetric heat balance calculation to the power range channel output and adjust power range channel output if.

calorimetric exceeds power range channel output by ~ 2% RTP.

In accordance with the Surveillance Frequency Control Program SR 3.3.1.3

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

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

Compare out of core measured AXIAL POWER IMBALANCE (APlo) to incore measured AXIAL POWER IMBALANCE (API,)

as follows:

(RTP/TP)(APlo - (CS X API I))

imbalance error where CS is CORRELATION SLOPE Adjust power range channel output if the In accordance with the Surveillance Frequency Control Program absolute vail,.le of imbalance error is

~2% RTP.

(continued)

OCONEE UNITS 1, 2, &3 3.3.1-3 Amendment Nos. 372, 374, 373

3.3.1 i

NO T E --------------------------

Not applicable to Unit(s) with RPS digital upgrade complete.

Perform CHANNEL FUNCTIONAL TEST.

SURVEILLANCE SR 3.3.1.4 RPS Instrumentation FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.1.5

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

Only applicable to Unit(s) with RPS digital upgrade complete.

Manually verify the setpoints are correct.

In accordance with the Surveillance Frequency Control Program SR 3.3.1.6

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

Only applicable to Unit(s) with RPS digital upgrade complete.

Manually actuate the output channel interposing relays.

I n accordance with the Surveillance Frequency Control Program SR 3.3.1.7

NOT E -------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.1-4 Amendment Nos. 372, 374, 373

3.3.3 RPS - RTC ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Two or more RTCs inoperable in MODE 1, 2, or 3.

B.1 Be in MODE 3.

AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OR Required Action and associated Completion Time not met in B.2.1 Open all CRD trip breakers.

OR 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months MODE 1, 2, or 3.

B.2.2 Remove power from all CRD trip breakers.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C.

Two or more RTCs inoperable in MODE 4 or 5.

OR C.1 Open all CRD trip breakers.

OR 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Required Action and associated Completion Time not met in MODE 4 or 5.

C.2 Remove power from all CRD trip breakers.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.3-2 Amendment Nos. 372, 374, 373

3.3.4 CRD Trip Devices ACTIONS (continued)

C.

D.

CONDITION Required Action and associated Completion Time not met in MODE 1,2, or 3.

Required Action and associated Completion Time not met in MODE 4 or 5.

REQUIRED ACTION C.1 Be in MODE 3.

AND C.2.1 Open all CRD trip breakers.

C.2.2 Remove power from all CRD trip breakers.

0.1 Open all CRD trip breakers.

0.2 Remove power from all CRD trip breakers.

COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 12 hours 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 6 hours 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL FUNCTIONAL TEST.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.4-2 Amendment Nos. 372, 374, 373

ESPS Input Instrumentation 3,3,5 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B,

(continued)

B,2,2

NO T E ----------

Only required for RCS Pressure - Low Low.

Reduce RCS pressure

< 900 psig.

AND B,2,3

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

Only required for Reactor Building Pressure High and High High.

Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5,1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.3.5-2 Amendment Nos. 372, 374, 373

3.3.5 ESPS Input Instrumentation SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.5.2

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

Only applicable to Unit(s) with ESPS digital upgrade complete.

Manually verify that the setpoints are correct.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.3

NOT E --------------------------

Not applicable to Unit(s) with ESPS digital upgrade complete.

Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.4 Perform CHANNEL CALIBRATION.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.5-3 Amendment Nos. 372, 374, 373

ESPS Manual Initiation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action and associated Completion Time not met.

B.1 AND B.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL FUNCTIONAL TEST.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.6-2 Amendment Nos.372, 374, 373 I

3.3.7 ESPS Automatic Actuation Output Logic Channels SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1

NOT E --------------------------

Only applicable to Unit(s) with the ESPS digital upgrade complete Manually actuate the output channel interposing relays.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform automatic actuation output logic CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency

. Control Program I

OCONEE UNITS 1, 2, & 3 3.3.7-2 Amendment Nos. 372, 374, 373

PAM Instrumentation 3.3.8 SURVEILLANCE REQUIREMENTS

NOT E -------------------------------------------------------

These SRs apply to each PAM instrumentation Function in Table 3.3.8-1 except where indicated.

SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

In accordance with the Surveillance Frequency Control Program SR 3.3.8.2

N 0 T E ----------------------

Only applicable to PAM Functions 7 and 22.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.8.3

N0 T E S--------------------

1.

Neutron detectors are excluded from CHANNEL CALIBRATION.

2.

Not applicable to PAM Functions 7 and

22.

. Surveillance Frequency Control Program Perform CHANNEL CALIBRATION.

. In accordance with the OCONEE UNITS 1, 2, & 3 3.3.8-4 Amendment Nos. 372, 374, 373 I

Source Range Neutron Flux 3.3.9 ACTIONS CONDITIoN REQUIRED ACTION COMPLETION TIME B.

(continued)

B.4 Verify SDM to be within the limit specified in the COLR.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter C.

One or more required source range neutron flux channel(s) inoperable with THERMAL POWER level> 4E-4% RTP on the wide range neutron flux channels.

C.1 Initiate action to restore affected channel(s) to OPERABLE status.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.9.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.9.2

NOT E -------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the

, Surveillance Frequency I Control Program OCONEE UNITS 1. 2. &3 3.3.9-2 Amendment Nos372, 374, 373 I

Wide Range Neutron Flux 3.3.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.10.2

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

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program SR 3.3.10.3 Verify at least one decade overlap between source range and wide range neutron flux channels.

Once each reactor startup prior to the source range indication exceeding 105 cps if not performed within the previous 7 days OCONEE UNITS 1, 2, & 3 3.3.10-2 Amendment Nos. 372, 374, 3731

AFIS Instrumentation 3.3.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

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

C.1 AND C.2 Be in MODE 3.

Reduce main steam header pressure to

<700 psig.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 18 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.11.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.11.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Fr.equency Control Program SR 3.3.11.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.11-2 Amendment Nos. 372, 374, 373 I

AFIS Manual Initiation 3.3.12 SURVEILLANCE IREMENTS SURVEILLANCE FREQUENCY SR 3.3.12.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1,2, &3 3.3.12-2 Amendment Nos. 372, 374, 3731

AFIS Digital Channels 3.3.13 3.3 INSTRUMENTATION 3.3.13 Automatic Feedwater Isolation System (AFIS) Digital Channels LCO 3.3.13 Two AFIS digital channels per steam generator (SG) shall be OPERABLE.

APPLICABILITY:

MODES 1 and 2, MODE 3 with main steam header pressure;;:: 700 psig.

ACTIONS

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

Separate Condition entry is allowed for each SG.

CONDITION A.

One digital channel inoperable.

A.1 REQUIRED ACTION Restore digital channel to OPERABLE status.

COMPLETION TIME 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B.

Two digital channels inoperable.

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

B.1 AND B.2 Be in MODE 3.

Reduce main steam header pressure to

< 700 psig 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 18 hours SU RVEI LLANCE FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.13.1 Perform CHANNEL FUNCTIONAL TEST.

OCONEE UNITS 1,2, & 3 3.3.13-1 Amendment Nos. 372, 374, 373 I

3.3.14 EFW Pump Initiation Circuitry SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.14.1 Perform CHANNEL FUNCTIONAL TEST for each LOMF pump instrumentation channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.14.2 Perform CHANNEL FUNCTIONAL TEST for each manual initiation circuit.

In accordance with the Surveillance Frequency Control Prog ram SR 3.3.14.3 Perform CHANNEL FUNCTIONAL TEST for

'In accordance with the each automatic initiation circuit.

SR 3.3.14.4 Perform CHANNEL CALIBRATION for each LOMF pump instrumentation channel.

Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.14-2 Amendment Nos.372, 374, 373

TSV Closure 3.3.15 3.3 INSTRUMENTATION 3.3.15 Turbine Stop Valve (TSV) Closure LCO 3.3.15 Two TSV Closure channels shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3 except when all TSVs are closed.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One or more TSV A.1 Declare the TSVs 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Closure channel(s) inoperable.

inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.15.1 Perform CHANNEL FUNCTIONAL TEST.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.15-1 Amendment Nos. 372, 374, 373 I

RB Purge Isolation - High Radiation 3.3.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.16.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.16.2 Perform CHANNEL FUNCTIONAL TEST.

Once each refueling outage prior to movement of recently irradiated fuel assemblies within containment SR 3.3.16.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.16-2 Amendment Nos. 372, 374, 3731

EPSL Automatic Transfer Functions 3.3.17 3.3 INSTRUMENTATION 3.3.17 Emergency Power Switching Logic (EPSL) Automatic Transfer Function LCO 3.3.17 Two channels of the EPSL Automatic Transfer Function shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One channel inoperable.

A.1

N 0 T E----------

The Completion Time is reduced when in Condition L of LCO 3.8.1.

Restore channel to OPERABLE status.

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

Required Action and associated Completion Time not met.

B.1 AND B.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 84 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.17.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the

Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.17-1 Amendment Nos. 372, 374, 373 I

EPSL Voltage Sensing Circuits 3.3.18 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action and B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time not met in AND MODES 1, 2, 3, and 4.

B.2 Be in MODE 5.

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

Two or more channels C.1 Declare affected AC Immediately of a required circuit power source{s) inoperable when not in inoperable.

MODES 1, 2, 3, and 4.

OR Required Action and associated Completion Time not met when not in MODES 1, 2, 3, and 4.

D.

Required Action and D.1 Suspend movement of Immediately associated Completion irradiated fuel Time not met during assemblies.

movement of irradiated fuel assemblies.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.18.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.18-2 Amendment Nos*372, 374, 373 I

EPSL 230 kV Switchyard DGVP 3.3.19 ACTIONS (continued)

CO t',mlTl ON REQUIRED ACTION COMPLETION TIME D.

Two or more voltage sensing channels inoperable.

D.1 Declare the overhead emergency power path inoperable.

Immediately Two actuation logic channels inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.19.1 Perform a CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.19.2 Perform a CHANNEL CALIBRATION of the voltage sensing channel with the setpoint allowable value as follows:

Degraded voltage ~ 226 kV and 5 229 kV with a time delay of 9 seconds +/- 1 second.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.19-2 Amendment Nos. 372, 374, 3731

EPSL CT-5 DGVP 3.3.20 SURVEILLANCE REQUIREIVIENTS SURVEILLANCE FREQUENCY SR 3.3.20.1 Perform a CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.20.2 Perform a CHANNEL CALIBRATION of the voltage sensing channel with the setpoint allowable value as follows:

a.

Degraded voltage :2 4143 V and ~ 4185 V with a time delay of 9 seconds +/- 1 second for the first level undervoltage inputs; and

b.

Degraded voltage :2 3871 V and ~ 3901 V for the second level undervoltage inputs.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.20-2 Amendment Nos. 372, 374, 373 I

EPSL Keowee Emergency Start Function 3.3.21 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.21.1 Perform CHANNEL FUNCTIONAL TEST.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.21-2 Amendment Nos. 372, 374, 3731

EPSL Manual Keowee Emergency Start Function 3.3.22 3.3 INSTRUMENTATION 3.3.22 Emergency Power Switching Logic (EPSL) Manual Keowee Emergency Start Function LCO 3.3.22 One channel of the EPSL Manual Keowee Emergency Start Function shall be OPERABLE.

APPLICABILITY:

MODES 5 and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Required channel inoperable.

A.i Declare both Keowee Hydro Units inoperable.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.22.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.22-1 Amendment Nos*372, 374, 373 I

MFBMP 3.3.23 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TI ME D.

Required Action and associated Completion Time not met.

0.1 Initiate action in accordance with Specification 5.6.6.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.23.1 Perform a CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.23-2 Amendment Nos. 372, 374, 3731

LPSW RB Waterhammer Prevention Circuitry 3.3.27 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.27.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.27.2 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the

. Surveillance Frequency Control Program SR 3.3.27.3 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.3.27-3 Amendment Nos. 372, 374, 373 I

3.3.28 LPSW Standby Pump Auto-Start Circuitry 3.3 INSTRUMENTATION 3.3.28 Low Pressure Service Water (LPSW) Standby Pump Auto-Start Circuitry LCO 3.3.28 LPSW Standby Pump Auto-Start Circuitry shall be OPERABLE.

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

LPSW Standby Pump auto-start circuit is not required to be OPERABLE on running LPSW pumps.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

LPSW standby pump auto-start circuitry inoperable.

A.1 Restore LPSW standby pump auto-start circuitry to OPERABLE status.

7 days B.

Required Action and associated Completion Time not met.

B.1 AND B.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 60 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.28.1 Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.28.2 Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.3.28-1 Amendment Nos. 372, 374, 373

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 SURVEILLANCE REQUIREMEI\\JTS SURVEILLANCE FREQUENCY SR 3.4.1.1

N OT E ------------------------

With three RCPs operating, the limits are applied to the loop with the highest pressure.

Verify RCS loop pressure is within limits specified in the COLR.

In accordance with the Surveillance Frequency Control Program SR 3.4.1.2

NOT E ------------------------

With three RCPs operating, the limits are applied to the loop with the lowest loop average temperature for the condition where there is a OaF t!Tc setpoint.

Verify RCS loop average temperature is within limits specified in the COLR.

In accordance with the Surveillance Frequency Control Program SR 3.4.1.3 Verify RCS total flow is within limits specified in the COLR.

In accordance with the Surveillance Frequency

Control Program SR 3.4.1.4

NOT E------------------------

Not required to be performed until 7 days after stable thermal conditions are established in the higher power range of MODE 1.

Verify by measurement RCS total flow rate is within limit specified in the COLR.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.1-2 Amendment Nos. 372, 374, 373/

3.4.3 RCS PIT Limits ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action and B.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

AND B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C.

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

Required Action C.2 shall be completed whenever this Condition is entered.

Requirements of LCO not met in other than MODE 1, 2, 3, or4.

C.1 AND C.2 Initiate action to Immediately restore parameter(s) to within limit.

Determine RCS is acceptable for continued operation.

i Prior to entering MODE 4 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.3.1

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

Only required to be performed during RCS heatup and cooldown operations and RCS leak and hydrostatic testing.

Verify RCS pressure, RCS temperature and RCS heatup and cooldown rates are within limits.

FREQUEI'JCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1,2, & 3 3.4.3-2 Amendment Nos. 372, 374, 373

RCS Loops - MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCO 3.4.4 Two RCS Loops shall be in operation, with:

a.

Four reactor coolant pumps (RCPs) operating; or

b.

Three RCPs operating and THERMAL POWER restricted to 75% RTP.

APPLICABILITY:

MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Requirements of LCO not met.

A.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify required RCS loops are in operation.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.4-1 Amendment Nos. 372, 374, 373 I

RCS Loops MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Two RCS loops inoperable.

OR Required RCS loop not in operation.

C.1 AND C.2 Suspend all operations involving a reduction of RCS boron concentration.

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

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.5.2 Verify correct breaker alignment and indicated power available to the required pump that is not in operation.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.5-2 Amendment Nos. 372, 374, 3731

RCS Loops - MODE 4 3.4.6 ACTIONS (continued) cor-*mITlON REQUIRED ACTION COMPLETION TIME B.

Two required loops inoperable.

OR Required loop not in operation.

B.1 AND B.2 Suspend all operations involving a reduction in RCS boron concentration.

I nitiate action to restore one loop to Immediately Immediately OPERABLE status and operation.

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

In accordance with the Surveillance Frequency Control Program SR 3.4.6.2 Verify correct breaker alignment and indicated power available to the required pump that is not in operation.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.6-2 Amendment Nos. 372, 374, 3731

RCS Loops - MODE 5, Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.7.1 Verify required DHR loop is in operation.

SR 3.4.7.2 Verify required SG secondary side water levels are:;:: 50%.

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

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 3.4.7-3 Amendment Nos. 372, 374, 373 I

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

CONDITION REQUIRED ACTION COMPLETION TIME B.

Two DHR loops inoperable.

OR Required DHR loop not in operation.

B.1 AND B.2 Suspend all operations involving reduction in RCS boron concentration.

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

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify required DHR loop is in operation.

In accordance with the Surveillance Frequency

. Control Program SR 3.4.8.2 Verify correct breaker alignment and indicated In accordance with the power available to the required DHR pump Surveillance Frequency that is not in operation.

Control Program OCONEE UNITS 1, 2, &3 3.4.8-2 Amendment Nos. 372, 374, 3731

Pressurizer 3.4.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

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

0.1 AND 0.2 Be in MODE 3.

Reduce RCS temperature to

c; 325°F.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 18 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level :c; 285 inches.

In accordance with the Surveillance Frequency Control Program SR 3.4.9.2 Verify capacity of required pressurizer heaters and associated power supplies are

400 kW.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1,2, & 3 3.4.9-2 Amendment Nos.372, 374, 373 I

RCS Specific Activity 3.4.11 CONDITION REQUIRED ACTION COMPLETION TIME C.

Gross specific activity C.1 Be in MODE 3 with 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months of the coolant not within RCS Average limit.

Temperature < 500°F.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify reactor coolant gross specific activity

~ 100lE !-lCi/gm.

In accordance with the Surveillance Frequency Control Program SR 3.4.11.2

N 0 T E ----------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 specific activity ~ 1.0 !-lCi/gm.

In accordance with the Surveillance Frequency Control Program Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after THERMAL POWER change of;::: 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period SR 3.4.11.3

NOT E -------------------

Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for;::: 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

Determine E.

I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.4.11-2 Amendment Nos. 372, 374, 373 I

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify HPI is deactivated.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.2 Verify each CFT is isolated.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.3 Verify pressurizer level is level necessary to assure ~ 10 minutes are available for operator action to mitigate an L TOP event.

30 minutes during RCS heatup and cooldown AND I n accordance with the Surveillance Frequency Control Program SR 3.4.12.4 Verify PORV block valve is open.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.5 Perform CHANNEL FUNCTIONAL TEST for PORV.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1,2, & 3 3.4.12-4 Amendment Nos. 372, 374, 373 1

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.6 Verify Administrative Controls, other than limits for pressurizer level, that assure ~ 10 minutes are available for operator action to mitigate an L TOP event are implemented for the following:

a.

RCS pressure when RCS temperature is < 325°F;

b.

Makeup flow rate;

c.

Alarms;

d.

High pressure Nitrogen System; and

e.

Verify pressurizer heater bank 3 or 4 is deactivated In accordance with the Surveillance Frequency Control Program SR 3.4.12.7 Perform CHANNEL CALIBRATION for PORV.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.4.12-5 Amendment Nos. 372, 374, 373 1

3.4.13 RCS Operational LEAKAGE SURVEILLANCE REQUIREMEI\\JTS SURVEILLANCE FREQUENCY SR 3.4.13.1

NOT E S-----------------------

1. Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

2. Not applicable to primary to secondary LEAKAGE.

Evaluate RCS Operational LEAKAGE.

In accordance with the Surveillance Frequency Control Prog ram SR 3.4.13.2

N 0 T E -------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after establishment of steady state operation.

Verify primary to secondary LEAKAGE is s; 150 gallons per day through anyone SG.

In accordance with the Surveillance Frequency Control Prog ram OCONEE UNITS 1,2, & 3 3.4.13-3 Amendment Nos. 372, 374, 373

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SU RVEI LLANCE SR 3.4.14.1

NOT E -------------------------

Not required to be performed in MODES 3 and 4.

Verify leakage from each required RCS PIV is equivalent to s; 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure ~ 2150 psia and s; 2190 psia.

FREQUENCY In accordance with the Surveillance Frequency Control Program Prior to entering MODE 2 whenever the unit has been in MODE 5 for

~ 7 days, if leakage testing has not been performed in the previous 9 months.

OCONEE UNITS 1, 2, & 3 3.4.14-3 Amendment Nos. 372, 374, 373 1

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program SR 3.4.15.2 Perform CHANNEL FUNCTIONAL TEST of required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program SR 3.4.15.3 Perform CHANNEL CALIBRATION of required containment sump level indication.

In accordance with the Surveillance Frequency Control Program SR 3.4.15.4 Perform CHANNEL CALIBRATION of required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.4.15-3 Amendment Nos. 372, 374, 373 1

CFTs 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each CFT isolation valve is fully open.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.2 Verify borated water volume in each CFT is 2: 1010 fe and S; 1070 fe.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each CFT is 2: 575 psig and s; 625 psig.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.4 Verify boron concentration in each CFT is within the limit specified in the COLR.

In accordance with the Surveillance Frequency Control Program AND

NOT E -----------

Only required to be performed for affected CFT Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after each solution volume increase of 2: 80 gallons that is not the result of addition from a borated water source that meets CFT boron concentration requirements.

OCONEE UNITS 1, 2, & 3 3.5.1-2 Amendment Nos. 372, 374, 3731

CFTs 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1.5 Verify power is removed from each CFT In accordance with the isolation valve operator.

Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.1-3 Amendment Nos. 372, 37~, 373 I

HPI 3.5.2 ACTIONS (continued)

CONDITIOI\\J REQUIRED ACTION COMPLETION TIME F.

One LPI-HPI flow F.1 Restore LPI-HPI flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months path inoperable.

path to OPERABLE status.

G.

H.

Required Action and associated Completion Time of Condition B, C, 0, or F not met.

Two HPI trains inoperable.

G.1 AND G.2 H.1 Be in MODE 3.

Reduce RCS temperature to s 350°F.

Enter LCO 3.0.3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 60 hours Immediately OR Two LPI-HPI flow paths inoperable.

SURVEILLANCE REQUIREMENTS SU RVE I LLANCE FREQUENCY SR 3.5.2.1 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.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.2

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

Not applicable to operating HPI pump(s).

Vent each HPI pump casing.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, &3 3.5.2-4 Amendment Nos. 372, 374, 3731

HPI 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.3 Verify each HPI pump's developed head at the test flow point is greater than or equal to the required developed head.

I n accordance with the Inservice Testing Program SR 3.5.2.4 Verify each HPI 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.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.5 Verify each HPI pump starts automatically on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.6 Verify, by visual inspection, each HPI train reactor building sump suction inlet is not restricted by debris and suction inlet strainers show no evidence of structural distress or abnormal corrosion.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.7 Cycle each HPI discharge crossover valve and LPI-HPI flow path discharge valve.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.2-5 Amendment Nos. 372, 374, 373 I

LPI 3.5.3 ACTIONS (continued)

CONDITION C.

Required Action and associated Completion Time of Condition A or B not met.

C.1 AND REQUIRED ACTION Be in MODE 3.

COMPLETION TIME 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months C.2 Be in MODE 4.

60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months D.

One required LPI train inoperable in MODE 4.

D.1 AND D.2 Initiate action to restore required LPI train to OPERABLE status.

NOTE----------

Only required if DHR loop is OPERABLE.

Be in MODE 5.

Immediately 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.3.1 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.

FREQUENCY In accordance with the Surveillance Frequency Control Program (continued) 373 1 OCONEE UNITS 1, 2, & 3 3.5.3-2 Amendment Nos. 372, 374,

LPI 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.2 Not applicable to operating LPI pump(s).

Vent each LPI pump casing.

I n accordance with the Surveillance Frequency Control Program SR 3.5.3.3 Verify each LPI pump's developed head at the test flow pOint is greater than or equal to the required developed head.

In accordance with the Inservice Testing Program SR 3.5.3.4 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.

I n accordance with the Surveillance Frequency Control Program SR 3.5.3.5 Verify each LPI pump starts automatically on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.6 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.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.5.3-3 Amendment Nos. 372, 374, 37i

BWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.5.4.1

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

Only required to be performed when ambient air temperature is < 45°F or > 115°F.

Verify BWST borated water temperature is 2: 45°F and s; 115°F.

FREQUENCY I n accordance with the Surveillance Frequency

Control Program SR 3.5.4.2 Verify BWST borated water volume is 2: 350,000 gallons.

SR 3.5.4.3 Verify BWST boron concentration is:

a.

Within limits specified in the COLR; AND

b.

2220 ppm.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program Amendment Nos. 372, 374, 3731 OCONEE UNITS 1, 2, & 3

Containment Air Locks 3.6.2 SURVEILLAI\\JCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1

1.

An inoperable air lock door does not invalidate the previous successful performance of the overall air lock leakage test.

2.

Results shall be evaluated against acceptance criteria of SR 3.6.1.2 in accordance with 10 CFR 50, Appendix J. Option A, as modified by approved exemptions.

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

SR 3.0.2 is not applicable Perform required air lock leakage rate testing in accordance with 10 CFR 50, Appendix J, Option A, as modified by approved exemptions.

In accordance with 10 CFR 50, Appendix J, Option A, as modified by approved exemptions SR 3.6.2.2 Verify only one door in the air lock can be opened at a time.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.6.2-4 Amendment Nos. 372, 374, 37i

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.6.3.1 Verify each 48 inch purge valve is sealed closed.

In accordance with the Surveillance Frequency Control Program SR 3.6.3.2

NOT E-------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual and non-automatic power operated valve and blind flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

In accordance with the Surveillance Frequency Control Program SR 3.6.3.3

NOT E -------------------------

Valves and blind flanges in high radiation areas may be verified by use of administrative means.

Verify each containment isolation manual and non-automatic power operated valve and blind flange that is located inside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days (continued)

OCONEE UNITS 1, 2, & 3 3.6.3-4 Amendment Nos. 372, 374, 373 I

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4 Verify the isolation time of each automatic power operated containment isolation valve is within limits.

In accordance with the Inservice Testing Program SR 3.6.3.5 Verify each automatic containment isolation valve that is not locked, sealed, or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.6.3-5 Amendment Nos. 372, 374, 373 r

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be 2: -2.45 psig and s; +1.2 psig.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Containment pressure not within limits.

A.1 Restore containment pressure to within limits.

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months B.

Required Action and associated Completion Time not met.

8.1 AND B.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits.

In accordance with the Surveillance Frequency Control Program 373 1 OCONEE UNITS 1, 2, & 3 3.6.4-1 Amendment Nos. 372, 374,

Reactor Building Spray and Cooling Systems 3.6.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1

NOT E --------------------------

Applicable for RB cooling system after the completion of the LPSW RB Waterhammer Modification on the respective Unit.

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.

In accordance with the Surveillance Frequency Control Program SR 3.6.5.2 Operate each required reactor building cooling train fan unit for;:::: 15 minutes.

In accordance with the Surveillance Frequency Control Program SR 3.6.5.3 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.

In accordance with the Inservice Testing Program SR 3.6.5.4 Verify that the containment heat removal capability is sufficient to maintain post accident conditions within design limits.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.6.5-4 Amendment Nos. 372, 374, 3731

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

SURVEILLANCE FREQUENCY SR 3.6.5.5

NOT E--------------------------

Applicable for RB cooling system after the completion of the LPSW RB Waterhammer Modification on the respective Unit.

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.

In accordance with the Surveillance Frequency Control Program SR 3.6.5.6 Verify each required reactor building spray pump starts automatically on an actual or simulated actuation signal.

I n accordance with the Surveillance Frequency Control Program SR 3.6.5.7 Verify each required reactor building cooling train starts automatically on an actual or simulated actuation signal.

I n accordance with the Surveillance Frequency Control Program SR 3.6.5.8 Verify each spray nozzle is unobstructed.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.6.5-5 Amendment Nos. 372, 374, 373 I

TSVs 3.7.2 SURVEILLANCE REQUJREMENTS SURVEILLANCE FREQUEI\\JCY SR 3.7.2.1

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

Only required to be performed in MODES 1 and 2.

Verify closure time of each TSV is

S; 1.0 seconds on an actual or simulated actuation signal from Channel A.

In accordance with the Surveillance Frequency Control Program SR 3.7.2.2

NOT E -------------------------

Only required to be performed in MODES 1 and 2.

Verify closure time of each TSV is

S; 1.0 second on an actual or simulated actuation signal from Channel B.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.2-2 Amendment Nos. 372, 374, 373 1

ADV Flow Paths 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Atmospheric Dump Valve (ADV) Flow Paths LCO 3.7.4 The ADV flow path for each steam generator shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, and MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION I

REQUIRED ACTION COMPLETION TIME A.

One or both ADV flow A.1 path(s) inoperable.

I A.2 Be in MODE 3.

Be in MODE 4 without reliance upon steam generator for heat removal.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 24 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.4.1 Cycle the valves that comprise the ADV flow paths.

FREQUENCY I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.4-1 Amendment Nos. 372, 374, 3731

EFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each EFW manual, and non-automatic power operated valve in each water flow path and in the steam supply flow path to the turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.7.5.2 Verify the developed head of each EFW pump at the flow test point is greater than or equal to the required developed head.

In accordance with the Inservice Testing Program SR 3.7.5.3

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

!'Jot required to be met in MODES 3 and 4.

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

In accordance with the Surveillance Frequency Control Program SR 3.7.5.4

NOT E -------------------------

Not required to be met in MODES 3 and 4.

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

In accordance with the Surveillance Frequency Control Program SR 3.7.5.5 Verify proper alignment of the required EFW flow paths by verifying valve alignment from the upper surge tank to each steam generator.

Prior to entering MODE 2 whenever unit has been in MODE 5 or 6 for> 30 days OCONEE UNITS 1, 2, & 3 3.7.5-4 Amendment Nos. 372, 374, 373\\

UST and HW 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Upper Surge Tank (UST) and Hotwell (HW)

LCO 3.7.6 The UST and HW shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, and 3, MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Requirements of the LCO not met.

A.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months A.2 Be in MODE 4 without reliance on steam generator for heat removal.

24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.6.1 Verify combined inventory in the UST and HW is 2: 155,000 gal.

Inventory in the UST is 2: 30,000 gal.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.6-1 Amendment Nos. 372, 374, 373 I

LPSW System 3.7.7 SURVEILLANCE REQUIREMENTS SR 3.7.7.1 SURVEILLANCE Verify LPSW leakage accumulator level is within Water levels between 20.5" to 41" for Units with LPSW RB Waterhammer modification installed.

During LPSW testing, accumulator level> 41" is acceptable.

FREQUENCY I n accordance with the Surveillance Frequency Control Program SR 3.7.7.2

N 0 T E ------------------------

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

Verify each LPSW manual, and non automatic power operated valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program SR SR 3.7.7.3 3.7.7.4 Verify each LPSW 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 LPSW pump starts automatically on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program I n accordance with the Surveillance Frequency i Control Program SR 3.7.7.5 Verify LPSW leakage accumulator is able to provide makeup flow lost due to boundary valve leakage on Units with LPSW RB Waterhammer modification installed.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.7.7-2 Amendment Nos. 372, 374, 373 I

SURVEILLANCE REQUIREMENTS (continued SURVEILLANCE SR 3.7.7.6 Verify LPSW WPS boundary valve leakage is s 20 gpm for Units with LPSW RB Waterhammer modification installed.

LPSW System 3.7.7 FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.7-3 Amendment Nos. 372, 374, 373 I

ECCW 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Emergency Condenser Circulating Water (ECCW) System LCO 3.7.8 Two ECCW siphon headers shall be OPERABLE.

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

Not applicable on each Unit until after completion of the Service Water upgrade modifications on the respective Unit.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One required ECCW siphon header inoperable.

A.1 Restore required ECCW siphon header to OPERABLE status.

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B.

Required Action and associated Completion Time not met.

B.1 AND 8.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 60 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.8.1 Verify required Essential Siphon Vacuum (ESV) pumps are in operation.

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

OCONEE UNITS 1, 2, & 3 3.7.8-1 Amendment Nos. 372, 374, 373 I

ECCW 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.2 Verify Keowee Lake water level is within limits.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.3 Verify average water temperature of Condenser Circulating Water (CCW) inlet is

~ gO°F.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.4 Verify each manual and non-automatic power operated valve in each ECCW siphon header flow path, required ESV flow paths and required SSW flow paths that is not locked, sealed, or otherwise secured in position is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.5 Verify upon an actual or simulated actuation signal each ESV float valve actuates to the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.6 Verify upon an actual or simulated actuation signal each required ESV and Siphon Seal Water (SSW) valve actuates to the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.7 Verify the developed capacity of each In accordance with the required ESV pump at the test point is greater Surveillance Frequency than or equal to the required capacity.

Control Program (continued)

OCONEE UNITS 1, 2, &3 3.7.8-2 Amendment Nos. 372, 374, 3731

ECCW 3.7.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.8.8 Verify each required ESV pump automatically starts in ~ 1200 seconds upon an actual or simulated restoration of emergency power.

In accordance with the Surveillance Frequency Control Program SR 3.7.8.9

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

Not required to be performed for Units 1 and 2 with the shared Unit 1 and 2 LPSW System taking suction from the siphon.

Verify upon an actual or simulated trip of the CCW pumps and ESV pumps that the rate of water level drop in the ECCW siphon header is within limits.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.8-3 Amendment Nos. 372, 374, 3731

CRVS Booster Fans 3.7.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D.

E.

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

Required Action and associated Completion Time not met during movement of recently irradiated fuel assemblies.

D.1 AND D.2 E.1 Be in MODE 3.

Be in MODE 5 Suspend movement of recently irradiated fuel assemblies.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 36 hours Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Operate each CRVS Booster Fan train for

1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

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

In accordance with the VFTP SR 3.7.9.3 Verify two CRVS Booster Fan trains can maintain the Control Room at a positive pressure.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.9-2 Amendment Nos. 372, 374, 3731

Spent Fuel Pool Water Level 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Spent Fuel Pool Water Level LCO 3.7.11 The Spent Fuel Pool water level shall be::::: 21.34 ft over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY:

During movement of irradiated fuel assemblies in the Spent Fuel Pool, During movement of cask over the Spent Fuel Pool.

ACTIONS 1

CONDITION REQUIRED ACTION COMPLETION TIME A.

Spent Fuel Pool water level not within limit.

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

LCO 3.0.3 is not applicable.

A.1 Suspend movement of irradiated fuel assemblies in Spent Fuel Pool.

AND A.2 Suspend movement of cask over Spent Fuel Pool.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.11.1 Verify the Spent Fuel Pool water level is

21.34 ft above the top of irradiated fuel assemblies seated in the storage racks.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.11-1 Amendment Nos. 372, 374, 373 I

Spent Fuel Pool Boron Concentration 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.12.1 Verify the spent fuel pool boron concentration is:

a.

Within limits specified in the COLR; AND

b.

~ 2220 ppm.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.12-2 Amendment Nos. 372, 374, 373 I

Secondary Specific Activity 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Secondary Specific Activity LCO 3.7.14 The specific activity of the secondary coolant shall be 0.10 fLCi/gm DOSE EQUIVALENT 1-131.

APPLICABILITY:

MODES 1,2,3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Specific activity not A.1 Be in MODE 3.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months within limit.

AND A.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.14.1 Verify the specific activity of the secondary coolant is s; 0.10 fLCil9m DOSE EQUIVALENT 1-131.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.14-1 Amendment Nos. 372, 374, 3731

CRACS 3.7.16 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.16.1 Verify temperature in Control Room and Cable Room is ~ 80°F and temperature in Electrical Equipment Room is ~ 85°F.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.7.16-3 Amendment Nos. 372, 374, 373 I

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M.

Required Action and associated Completion Time for Condition C, F, G, H, I, J, K or L not met.

Required Action and associated Completion Time not met for Required Action 0.1 or 0.3.

M.1 AND M.2 Be in MODE 3.

Be in MODE 5.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 84 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power availability for each required offsite source.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.2 Verify battery terminal voltage is 2 125 Von float charge for each KHU's battery.

I n accordance with the Surveillance Frequency Control Program SR 3.8.1.3 Verify the KHU associated with the underground emergency power path starts automatically and energizes the underground emergency power path. Manually close the In accordance with the Surveillance Frequency Control Program SK breaker to each de-energized standby bus. I

( continued)

OCONEE UNITS 1, 2, & 3 3.8.1-13 Amendment Nos.372, 374, 373 I

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.4

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

The requirement to energize the underground emergency power path is not applicable 1) when the overhead disconnects are open for the KHU associated with the underground emergency power path or 2) when complying with Required Action 0.1.

Verify the KHU associated with the overhead emergency power path starts automatically and automatically or manually synchronize it to the Yellow bus in 230 kV switchyard.

Energize the underground emergency power path after removing the KHU from the overhead emergency power path.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.5

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

Not required to be performed for an SL breaker when its standby bus is energized from a LCT via an isolated power path.

Verify each closed SL and each closed N breaker opens manually or on an actual or' simulated actuation signal.

In accordance with the Surveillance Frequency

. Control Program SR 3.8.1.6

NO T E -------------------------

Not required to be performed for an S breaker when its standby bus is energized from a LCT via an isolated power path.

Operate each S and each E breaker through a full cycle.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.8.1-14 Amendment Nos. 372, 374, 373 I

AC Sources -Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.7 Verify both KHU's underground tie breakers In accordance with the cannot be closed simultaneously.

. Surveillance Frequency i Control Program SR 3.8.1.8 Verify each KHU's overhead emergency power path tie breaker cannot be closed when tie breaker to underground emergency power path is closed.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.9 SR 3.8.1.10 Verify on an actual or simulated emergency actuation signal each KHU auto starts and:

a.

Achieves frequency ~ 57 Hz and ~ 63 Hz and voltage ~ 13.5 kV and ~ 14.49 kV in

~ 23 seconds; and

b.

Supplies the equivalent of one Unit's Loss of Coolant Accident (LOCA) loads plus two Unit's Loss of Offsite Power (LOOP) loads when synchronized to system grid and loaded at maximum practical rate.

Verify each KHU's battery capacity is adequate to supply, and maintain in OPERABLE status, required emergency loads for design duty cycle when subjected to a battery service test.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3.8.1.11 Verify each KHU's battery cells, cell end plates, and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.

In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.8.1-15 Amendment Nos. 372, 374, 373/

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR3.8.1.12 SURVEILLANCE Verify each KHU's battery cell to cell and terminal connections are clean and tight, and are coated with anti-corrosion material.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.1.13

NOT E --------------------------

Only applicable when the overhead electrical disconnects for the KHU associated with the underground emergency power path are closed.

Verify on an actual or simulated zone overlap fault signal each KHU's overhead tie breaker and underground tie breaker actuate to the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.14

NOT E -------------------------

Not required to be performed for an SL breaker when its standby bus is energized from a LCT via an isolated power path.

Verify each closed SL and closed N breaker opens on an actuation of each redundant trip coil.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.15 Verify each 230 kV switchyard circuit breaker In accordance with the actuates to the correct position on a Surveillance Frequency switchyard isolation actuation signal.

Control Program (conti nued)

OCONEE UNITS 1, 2, & 3 3.8.1-16 Amendment Nos. 372, 374, 373 1

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16

NOT E --------------------------

Only applicable when complying with Required Action C.2.2.4.

Verify one KHU provides an alternate manual AC power source capability by manual or automatic KHU start with manual synchronize, or breaker closure, to energize its non required emergency power path.

As specified by Required Action C.2.2.4 SR 3.8.1.17 Verify each KHU's Voltage and Frequency out of tolerance logic trips and blocks closure of the appropriate overhead or underground power path breakers. The allowable values with a time delay of 5 seconds +/- 1 second shall be as follows:

a. Undervoltage ~ 12.42 kV and::; 12.63 kV

b. Overvoltage ~ 14.90 kV and::; 15.18 kV

c. Underfrequency ~ 53.992 hz and

54.008 hz

d. Overfrequency ~ 65.992 hz and

66.008 hz In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.8.1-17 Amendment Nos. 372, 374, 373 I

DC Sources - Operating 3.8.3 SURVEILLANCE REQUIREMENTS SR 3.8.3.1 SURVEILLANCE Verify correct breaker alignments and voltage availability from required distribution centers to isolating transfer diodes.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.8.3.2 SR 3.8.3.3 Verify battery terminal voltage is ;::: 125V on float charge.

Verify battery cells, cell plates, and racks show no visual indication of physical damage or abnormal deterioration that could degrade battery performance.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3.8.3.4 Verify battery cell to cell and terminal connections are clean and tight, and are coated with anti-corrosion material.

In accordance with the Surveillance Frequency Control Program SR 3.8.3.5 Verify battery capacity is adequate to supply, and maintain in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

In accordance with the Surveillance Frequency Control Program SR 3.8.3.6 Verify battery capacity is in accordance with the Battery Discharge Testing Program.

In accordance with the Battery Discharge Testing Program OCONEE UNITS 1, 2, &3 3.8.3-4 Amendment Nos. 372, 374, 373 I

Battery Cell Parameters 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.5.1 Verify battery cell parameters meet Table 3.8.5-1 Category A limits.

In accordance with the Surveillance Frequency Control Program SR 3.8.5.2 Verify battery cell parameters meet Table 3.8.5-1 Category B limits.

In accordance with the Surveillance Frequency Control Program SR 3.8.5.3 Verify average electrolyte temperature of representative cells is ;e: 60°F.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.8.5-3 Amendment Nos. 372, 374, 373 I

Vital Inverters Operating 3.8.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.6.1 Verify correct inverter voltage, frequency, and alignment to required 120 VAC Vital Instrumentation power panelboards.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.8.6-2 Amendment Nos.372, 374, 373 I

Vital Inverters Shutdown 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.7.1 Verify correct inverter voltage, frequency, and alignments to required 120 VAC Vital Instrumentation power panelboards.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.8.7-2 Amendment Nos. 372, 374, 373 I

Distribution Systems - Operating 3.8.8 SURVEILLANCE REQUIREMENTS 3.8.8.1 SURVEILLANCE Verify correct breaker alignments and voltage to required main feeder buses.

FREQUENCY In accordance with the Surveillance Frequency Control Program 3.8.8.2 Verify correct breaker alignments and voltage availability to required ES power strings, 125 VDC Vital I&C power panelboards, 230 kV Switchyard 125 VDC power panel boards and 120 VAC Vital I nstrumentation Rower panelboards.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.8.8-4 Amendment Nos.372, 374, 373 I

Distribution Systems - Shutdown 3.8.9 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2.4 Initiate actions to restore required main feeder buses, ES power strings, 125 VDC Vitall&C power panel boards, 230 kV Switchyard 1 25 VDC power panelboards or 120 VAC Vital Instrumentation power panelboards to OPERABLE status.

AND A.2.5 Declare associated required decay heat removalloop(s) inoperable and not in operation.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to required main feeder buses.

In accordance with the Surveillance Frequency Control Program SR 3.8.9.2 Verify correct breaker alignments and voltage availability to required ES power strings, 125 VDC Vital I&C power panelboards, 230 kV Switchyard 125 VDC power panel boards and 120 VAC Vital Instrumentation power panel boards.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.8.9-2 Amendment Nos. 372, 374, 373 I

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of the Reactor Coolant System and the refueling canal shall be maintained within the limit specified in the COLR.

APPLICABILITY:

MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Boron concentration not within limit.

Ai AND A2 AND A3 Suspend CORE AL TERATIONS.

Suspend positive reactivity additions.

Initiate action to restore boron concentration to within limit.

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.9.1-1 Amendment Nos. 372, 374, 373 I

Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK.

I n accordance with the Surveillance Frequency Control Program SR 3.9.2.2

NOT E -------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.9.2-2 Amendment Nos. 372, 374, 3731

Containment Penetrations 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Verify each required containment penetration is in the required status.

In accordance with the Surveillance Frequency

. Control Program SR 3.9.3.2 Verify each required Reactor Building Purge supply and exhaust isolation valve that is not locked, sealed or otherwise secured in the isolation position actuates to the isolation position on an actual or simulated high radiation actuation signal.

Once each refueling outage prior to movement of recently irradiated fuel assemblies within containment OCONEE UNITS 1, 2, & 3 3.9.3-2 Amendment Nos. 372, 374, 3731

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

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

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify one DHR loop is in operation.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.9.4-2 Amendment Nos. 372, 374, 373 1

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

(continued)

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

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one DHR loop is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.9.5.2 Verify correct breaker alignment and indicated power available to the required DHR pump that is not in operation.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.9.5-2 Amendment Nos. 372, 374, 373 1

Fuel Transfer Canal Water Level 3.9.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.6.1 Verify fuel transfer canal water level is

21.34 ft above the top of reactor vessel flange.

FREQUENCY In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, &3 3.9.6-2 Amendment Nos. 372, 374, 373 I

Unborated Water Source Isolation Valves 3.9.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.7.1 Verify each valve that isolates unborated water sources is secured in the closed position.

FREQUENCY I n accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.9.7-2 Amendment Nos. 372, 374, 373 I

SSF 3.10.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.10.1.1

NOT E -----------------------------

Not applicable to RCS temperature instrument I channels.

Perform CHANNEL CHECK for each required SSF instrument channel.

In accordance with the Surveillance Frequency Control Program SR 3.10.1.2 Verify required SSF battery terminal voltage is 2: 125 VDC on float charge.

I n accordance with the Surveillance Frequency Control Program SR 3.10.1.3 Verify the day tank contains 2: 200 gallons of fuel.

In accordance with the Surveillance Frequency Control Program SR 3.10.1.4 Verify the underground oil storage tank contains 2: 25,000 gallons of fuel.

In accordance with the Surveillance Frequency Control. Program SR 3.10.1.5

:---------NOT E -----------------------------

Ail DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.

Verify the DG starts from standby conditions and achieves steady state voltage and frequency.

SR 3.10.1.6 Verify DG required air start receiver pressure is 2: 150 psig.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program (continued)

OCONEE UNITS 1, 2, & 3 3.10.1-3 Amendment Nos. 372, 374, 373 1

SSF 3.10.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEI LLANCE FREQUENCY SR 3.10.1.7 Verify the fuel oil transfer system operates to In accordance with the automatically transfer fuel oil from the storage Surveillance Frequency tank to the day tank.

Control Program SR 3.10.1.8 Verify the fuel oil properties of the fuel oil In accordance with the stored in the day tank and underground Surveillance Frequency storage tank are tested in accordance with, Control Program and maintained within the limits of the Diesel Fuel Oil Testing Program.

SR 3.10.1.9

NOTE S---------------------------

1.

DG loadings may include gradual loading as recommended by the manufacturer.

2.

Momentary transients outside the load range do not invalidate this test.

3.

All DG starts may be preceded by an engine prelube period followed by a warmup period prior to loading.

In accordance with the loaded and operated for 2': 60 minutes at a Verify the SSF DG is synchronized and Surveillance Frequency load 2': 3280 kW.

Control Program SR 3.10.1.10 Verify for required SSF battery that the cells, I n accordance with the cell plates and racks show no visual indication Surveillance Frequency of physical damage or abnormal deterioration Control Program that could degrade battery performance.

(continued)

OCONEE UNITS 1, 2, & 3 3.10.1-4 Amendment Nos. 372, 374, 3731

SSF 3.10.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.10.1.11 SR 3.10.1.12 Verify for required SSF battery that the cell to cell and terminal connections are clean, tight and coated with anti-corrosion material.

Verify battery capacity of required battery is adequate to supply, and maintain in OPERABLE status, the required maximum loads for the design duty cycle when subjected to a battery service test.

In accordance with the Surveillance Frequency Control Program I n accordance with the Surveillance Frequency Control Program SR 3.10.1.13 Perform CHANf\\IEL CALIBRATION for each required SSF instrument channel.

In accordance with the Surveillance Frequency Control Program SR 3.10.1.14 Verify OPERABILITY OF SSF valves in accordance with the I nservice Testing Program.

In accordance with the Inservice Testing Program SR 3.10.1.15

NOT E ----------------------------

Not applicable to the SSF submersible pump.

Verify the developed head of each required SSF pump at the flow test point is greater than or equal to the required developed head.

In accordance with the Inservice Testing Program SR 3.10.1.16 Verify the developed head of the SSF submersible pump at the flow test P9int is greater than or equal to the required developed head.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.10.1-5 Amendment Nos. 372, 374, 3731

SSF Battery Cell Parameters 3.10.2 ACTIONS (continued)

CONDITION REQUI ACTION COMPLETION TIME B.

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

OR Required SSF battery with average electrolyte temperature of the representative cells

< 60°F.

OR Required SSF battery with one or more battery cell parameters not within Category C values.

B.1 Declare SSF Power System inoperable.

Immediately SURVEILLANCE REQUIREMENTS SR 3.10.2.1 SR 3.10.2.2 SURVEI LLANCE Verify battery cell parameters meet Table 3.10.2-1 Category A limits.

Verify battery cell parameters meet Table 3.10.2-1 Category B limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program SR 3.10.2.3 Verify average electrolyte temperature of representative cells is ~ 60°F.

In accordance with the Surveillance Frequency Control Program OCONEE UNITS 1, 2, & 3 3.10.2-2 Amendment Nos. 372, 374, 3731

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.20 Battery Discharge Testing Program (continued)

b.

If battery capacity is determined to be < 80% of the manufacturer's rating an OPERABILITY evaluation shall be initiated immediately and completed within the guidelines of the Oconee OPERABILITY program. If the OPERABILITY evaluation determines the battery OPERABLE, battery capacity shall be restored to ~ 80% of the manufacturer's rating within a time frame commensurate with the safety significance of the issue.

Otherwise, the battery shall be declared inoperable and the applicable Condition of Specification 3.8.3 shall be entered.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Battery Discharge Testing Program surveillance frequencies.

5.5.21 Surveillance Freguency Control Program This program provides controls for Surveillance Frequencies. The program shall ensure that Surveillance Requirements specified in the Technical Specifications are performed at intervals sufficient to assure the associated Limiting Conditions for Operation are met.

a.

The Surveillance Frequency Control Program shall contain a list of Frequencies of those Surveillance Requirements for which the Frequency is controlled by the program.

b.

Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-I nformed Method for Control of Surveillance Frequencies," Revision 1.

c.

The provisions of Surveillance Requirements 3.0.2 and 3.0.3 are applicable to the Frequencies established in the Surveillance Frequency Control Program.

OCOI\\JEE UNITS 1, 2, & 3 5.0-22 Amendment Nos. 372, 374, 373 I

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NO. 372 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-38 AMENDMENT NO. 374 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-47 AND AMENDMENT NO. 373 TO RENEWED FACILITY OPERATING LICENSE NO. DPR-55 DUKE ENERGY CAROLINAS, LLC OCONEE NUCLEAR STATION, UNITS 1,2, AND 3 DOCKET NOS. 50-269, 50-270, AND 50-287

1.0 INTRODUCTION

By application dated March 17,2010 (Agencywide Documents Access and Management System (ADAMS), Accession No. ML100830349), as supplemented by letter dated January 14, 2011 (ADAMS Accession No. ML110190637), Duke Energy Carolinas, LLC (Duke, the licensee),

requested changes to the Technical Specifications (TSs) for the Oconee Nuclear Station, Units 1, 2, and 3 (Oconee 1/2/3). The supplement dated January 14, 2011, provided additional information that clarified the application, did not expand the scope of the application as originally noticed, and did not change the staffs original proposed no significant hazards consideration determination as published in the Federal Register on September 7, 2010 (75 FR 54393).

The licensee proposed changes to TS Sections 5.5.18, 5.5.19, and 5.5.20. These proposed changes are outside the scope of TSTF-425, Revision 3. The NRC staff will review these proposed TS changes in a separate amendment.

The proposed changes would adopt the Nuclear Regulatory Commission (NRC)-approved Technical Specification Task Force (TSTF) - 425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control- [Risk-Informed Technical Specification Task Force] (RITSTF)

Initiative 5b" (ADAMS Accession No. ML090850630). When implemented, TSTF-425, Revision 3 relocates most periodiC frequencies of TS surveillances to a licensee controlled program, the Surveillance Frequency Control Program (SFCP), and provides requirements for the new program in the Administrative Controls Section of the TSs. All surveillance frequencies can be relocated except:

- 2

Frequencies that reference other approved programs for the specific interval (such as the In-Service Testing Program or the Primary Containment Leakage Rate Testing Program);

Frequencies that are purely event driven (e.g., "each time the control rod is withdrawn to the 'full out' position");

Frequencies that are event-driven but have a time component for performing the surveillance on a one-time basis once the event occurs (e.g., "within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after thermal power reaching;;::: 95 percent RTP"); and

Frequencies that are related to specific conditions (e.g., battery degradation, age and capacity) or conditions for the performance of a surveillance requirement (e.g., "drywell to suppression chamber differential pressure decrease").

A new Program is added to the Administrative Controls of TSs Section 5 as Specification 5.5.21.

The new program is called the SFCP and describes the requirements for the program to control changes to the relocated surveillance frequencies. The TS Bases for each of the affected surveillance requirements are revised to state that the frequency is set in accordance with the SFCP. The proposed licensee changes to the Administrative Controls Section of the TSs to incorporate the SFCP include a specific reference to Nuclear Energy Institute (NEI) 04-10, (Revision 1), "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies," Industry Guidance Document, April 2007 (ADAMS Accession No. ML071360456) as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs.

By letter dated September 19, 2007 (ADAMS Accession No. ML072570267), the NRC staff approved NEI 04-10 (Revision 1) as acceptable for referencing in licensing actions to the extent specified and under the limitations delineated in NEI 04-10 (Revision1) and in the NRC staffs safety evaluation providing the basis for its acceptance of NEI 04-10.

2.0 REGULATORY EVALUATION

In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants" published on July 22, 1993, in the Federal Register (FR) (58 FR 39132) the NRC addressed the use of Probabilistic Safety Analysis (PSA, currently referred to as Probabilistic Risk Analysis or PRA) in determining the content of the Technical SpeCifications (TSs). In this notice, the NRC stated, in part:

The Commission believes that it would be inappropriate at this time to allow requirements which meet one or more of the first three criteria [of 10 CFR 50.36]

to be deleted from technical specifications based solely on PSA (Criterion 4).

However, if the results of PSA indicate that technical specifications can be relaxed or removed, a deterministic review will be performed....

The Commission Policy in this regard is consistent with its Policy Statement on "Safety Goals for the Operation of Nuclear Power Plants," 51 FR 30028, published on August 21, 1986. The Policy Statement on Safety Goals states in part, probabilistic results should also be reasonably balanced and supported through use of deterministic arguments. In this way, judgments can be made about the degree of confidence to be given these [probabilistic] estimates and assumptions.

- 3 This is a key part of the process for determining the degree of regulatory conservatism that may be warranted for particular decisions. This

'defense-in-depth' approach is expected to continue to ensure the protection of public health and safety.

The Commission will continue to use PSA, consistent with its policy on Safety Goals, as a tool in evaluating specific line item improvements to Technical Specifications, new requirements, and industry proposals for risk-based Technical Specification changes.

Approximately 2 years later the NRC provided additional detail concerning the use of PRA in the "Use of Probabilistic Risk Assessment Methods in Nuclear Regulatory Activities; Final Policy Statement," published in the Federal Reg;steron August 16, 1995 (60 FR 42622). The NRC addressed the use of PRA. In this notice, the NRC stated, in part:

The Commission believes that an overall policy on the use of PRA methods in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that would promote regulatory stability and efficiency. In addition, the Commission believes that the use of PRA technology in NRC regulatory activities should be increased to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach....

PRA addresses a broad spectrum of initiating events by assessing the event frequency. Mitigating system reliability is then assessed, including the potential for multiple and common-cause failures. The treatment, therefore, goes beyond the single failure requirements in the deterministic approach. The probabilistic approach to regulation is, therefore, considered an extension and enhancement of traditional regulation by considering risk in a more coherent and complete manner....

Therefore, the Commission believes that an overall policy on the use of PRA in nuclear regulatory activities should be established so that the many potential applications of PRA can be implemented in a consistent and predictable manner that promotes regulatory stability and efficiency. This policy statement sets forth the Commission's intention to encourage the use of PRA and to expand the scope of PRA applications in all nuclear regulatory matters to the extent supported by the state-of-the-art in terms of methods and data....

Therefore, the Commission adopts the following policy statement regarding the expanded NRC use of PRA:

(1) The use of PRA technology should be increased in all regulatory matters to the extent supported by the state-of-the-art in PRA methods and data and in a manner that complements the NRC's deterministic approach and supports the NRC's traditional defense-in-depth philosophy.

(2) PRA and associated analyses (e.g., sensitivity studies, uncertainty analyses, and importance measures) should be used in regulatory matters, where practical within the bounds of the state-of-the-art, to reduce unnecessary conservatism associated with current regulatory requirements, regulatory

- 4 guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with 10 CFR 50.109 (8ackfit Rule). Appropriate procedures for including PRA in the process should be developed and followed. It is, of course, understood that the intent of this policy is that existing rules and regulations shall be complied with unless these rules and regulations are revised.

(3) PRA evaluations in support of regulatory decisions should be as realistic as practicable and appropriate supporting data should be publicly available for review.

(4) The Commission's safety goals for nuclear power plants and subsidiary numerical objectives are to be used with appropriate consideration of uncertainties in making regulatory judgments on the need for proposing and backfitting new generic requirements on nuclear power plant licensees.

In Title 10 of the Code of Federal Regulations (10 CFR), Part 50, Section 50.36, the NRC established its regulatory requirements related to the content of the TSs. Pursuant to 10 CFR 50.36, TSs are required to include items in the following five specific categories related to station operation: (1) safety limits, limiting safety system settings, and limiting control settings; (2) limiting conditions for operation; (3) surveillance requirements; (4) design features; and (5) administrative controls.

As stated in 10 CFR 50.36(c)(3), "Surveillance requirements 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 limiting conditions for operation will be met." These categories will remain in the TSs. The new TS provides the necessary administrative controls to require that surveillances relocated to the SFCP are conducted at a frequency to assure that the necessary quality of systems and components is maintained, that facility operation will be within safety limits, and that the limiting conditions for operation will be met. Changes to surveillance frequencies in the SFCP are made using the methodology contained in NEI 04-10, Revision 1, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and are required to be documented. Furthermore, changes to frequencies are subject to regulatory review and oversight of the SFCP implementation through the rigorous NRC review of safety-related SSC performance provided by the reactor oversight process (ROP).

The licensee's SFCP assures that surveillance requirements specified in the TSs are performed at intervals sufficient to assure the above regulatory requirements are met. Existing regulatory requirements, such as 10 CFR 50.65, "Requirements for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants," and 10 CFR Part 50, Appendix 8 (corrective action program), require licensee monitoring of surveillance test failures and implementing corrective actions to address such failures. One of these actions may be to consider increasing the frequency at which a surveillance test is performed. In addition, the SFCP implementation guidance in NEI 04-10, Revision 1, requires monitoring of the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs.

- 5 This change is analogous with other NRC-approved TS changes in which the surveillance requirements are retained in the TSs but the related surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the Inservice Testing Program and the Primary Containment Leakage Rate Testing Program. Thus, this proposed change complies with 10 CFR 50.36(c)(3) by retaining the 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 limiting conditions for operation will be met and meet the first key safety principle articulated in Regulatory Guide (RG) 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," August 1998 (ADAMS Accession No. ML003740176) for plant-specific, risk-informed TS changes by complying with current regulations.

Licensees are required by the TSs to perform surveillance tests, calibrations, or inspections on specific safety-related system equipment such as reactivity control, power distribution, electrical, instrumentation, and others to verify system operability. Surveillance frequencies, currently identified in the TSs, are based primarily upon deterministic methods such as engineering judgment, operating experience, and manufacturer's recommendations. The licensee's use of NRC-approved PRA methodologies identified in NEI 04-10, Revision 1 provides a way to establish risk-informed surveillance frequencies that complement the deterministic approach and support the NRC's traditional defense-in-depth philosophy.

These regulatory requirements, and the monitoring required by NEI 04-10, Revision 1, assurethat surveillance frequencies are sufficient to satisfy that the requirements of 10 CFR 50.36 and that any performance deficiencies will be identified and appropriate corrective actions taken.

3.0 TECHNICAL EVALUATION

The licensee's adoption of TSTF-425, Revision 3, provides for administrative relocation of applicable surveillance frequencies, and provides for the addition of the SFCP to the administrative controls of the TSs. TSTF-425, Revision 3 also requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. The licensee's application for the changes proposed in TSTF-425, Revision 3, included documentation regarding the PRA technical adequacy consistent with the requirements of RG 1.200, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 1, January 2007 (ADAMS Accession No. ML070240001),

Section 4.2. In accordance with NEI 04-10, Revision 1, PRA methods are used, in combination with plant performance data and other considerations, to identify and justify modifications to the surveillance frequencies of equipment at nuclear power plants. This is in accordance with guidance provided in RG 1.174, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis," NRC, July 1998 (ADAMS Accession No. ML003740133) and RG 1.177 in support of changes to surveillance test intervals.

RG 1.177 identifies five key safety principles required for risk-informed changes to the TSs. Each of these principles is addressed by the industry methodology document, NEI 04-10, Revision 1.

The second through the fifth principles, which relate to the technical aspects of the proposed change, are discussed below. The first principle requires the proposed change to meet the current regulations. The NRC staff finds that the change meets that requirement.

- 6 3.1 The Proposed Change Is Consistent With the Defense-in-Depth Philosophy Consistency with the defense-in-depth philosophy, the second key safety principle of RG 1.177, is maintained if:

A reasonable balance is preserved among prevention of core damage, prevention of containment failure, and consequence mitigation.

Over-reliance on programmatic activities to compensate for weaknesses in plant design is avoided.

System redundancy, independence, and diversity are preserved commensurate with the expected frequency, consequences of challenges to the system, and uncertainties (e.g., no risk outliers). Because the scope of the proposed methodology is limited to revision of surveillance frequencies, the redundancy, independence, and diversity of plant systems are not impacted.

Defenses against potential common cause failures are preserved, and the potential for the introduction of new common cause failure mechanisms is assessed.

Independence of barriers is not degraded.

Defenses against human errors are preserved.

The intent of the General Design Criteria in 10 CFR Part 50, Appendix A, is maintained.

TSTF--425, Revision. 3, requires the application of NEI 04-10, Revision 1, for any changes to surveillance frequencies within the SFCP. NEI 04-10, Revision 1 uses both the core damage frequency (CDF) and the large early release frequency (LERF) metrics to evaluate the impact of proposed changes to surveillance frequencies. The guidance of RG 1.174 and RG 1.177 for changes to CDF and LERF is achieved by evaluation using a comprehensive risk analysis, which assesses the impact of proposed changes including contributions from human errors and common cause failures. Defense-in-depth is also included in the methodology explicitly as a qualitative consideration outside of the risk analysis, as is the potential impact on detection of component degradation that could lead to increased likelihood of common cause failures. Both the quantitative risk analysis and the qualitative considerations assure a reasonable balance of defense-in-depth is maintained to ensure protection of public health and safety, satisfying the second key safety principle of RG 1.177.

3.2 The Proposed Change Maintains Sufficient Safety Margins The engineering evaluation that will be conducted by the licensee under the SFCP when frequencies are revised will assess the impact of the proposed frequency change in accordance with the principle that sufficient safety margins are maintained. The guidelines used for making that assessment will include ensuring the proposed surveillance test frequency change is not in conflict with approved industry codes and standards or adversely affects any assumptions or inputs to the safety analysis, or, if such inputs are affected, justification is provided to ensure sufficient safety margin will continue to exist.

The design, operation, testing methods, and acceptance criteria for SSCs, specified in applicable codes and standards (or alternatives approved for use by the NRC) will continue to be met as

-7 described in the plant licensing basis (including the updated final safety analysis report and bases to the TSs), since these are not affected by changes to the surveillance frequencies. Similarly, there is no impact to safety analysis acceptance criteria as described in the plant licensing basis.

Thus, safety margins are maintained by the proposed methodology, and the third key safety principle of RG 1.177 is satisfied.

3.3 When Proposed Changes Result in an Increase in Core Damage Frequency or Risk, the Increases Should Be Small and Consistent With the Intent of the Commission's Safety Goal Policy Statement RG 1.177 provides a framework for risk evaluation of proposed changes to surveillance frequencies, which requires identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1, satisfies the intent of RG 1.177 requirements for evaluation of the change in risk, and for assuring that such changes are small by providing the technical methodology to support risk-informed TSs for control of surveillance frequencies.

3.4 Quality of the PRA The quality of the Oconee PRA is compatible with the safety implications of the proposed TS change and the role the PRA plays in justifying the change. That is, the more the potential change in risk or the greater the uncertainty in that risk from the requested TS change, or both, the more rigor that must go into ensuring the quality of the PRA.

The licensee used RG 1.200 to address the plant PRA technical adequacy. RG 1.200 is NRC-developed regulatory guidance, which addresses the use of the American Society of Mechanical Engineers (ASME) RA-Sb-2005, Addenda to ASME RA-S-2002 Standard for Probabilistic Risk Assessment for Nuclear Power Plant Applications, NEI 00-02, "PRA Peer Review Process Guidance," May 2006 (ADAMS Accession No. ML061510614), and NEI 05-04, Revision 0, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard," August 2006 (ADAMS Accession No. ML080670267). The licensee has performed an assessment of the PRA models used to support the SFCP against the requirements of RG 1.200 to assure that the PRA models are capable of determining the change in risk due to changes to surveillance frequencies of SSCs, using plant-specific data and models. Capability category II of ASME RA-Sb-2005 is applied as the standard, and any identified deficiencies to those requirements are assessed further in sensitivity studies to determine any impacts to proposed decreases to surveillance frequencies. This level of PRA quality, combined with the proposed sensitivity studies, is sufficient to support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177.

The NRC staff reviewed the licensee's assessment of the Oconee 112/3 PRA and the remaining open deficiencies that do not conform to capability category II of the ASME PRA standard (Table 2-1 of Attachment 2 of the licensee's March 17,2010, application). The NRC staff's assessment of these open "gaps," to assure that they may be addressed and dispositioned for each surveillance frequency evaluation per the NEI 04-10 methodology, is provided below.

- 8 Gap #1: Accident sequence notebooks and system model notebooks should document the phenomenological conditions created by the accident sequence progression. In the licensee's January 14, 2011, supplement, the licensee stated that for each surveillance frequency change evaluation, any phenomenological conditions created by the accident sequence progression will be identified, included and documented in the analysis.

Gap #2: Data calculations should be revised to group standby and operating component data.

Group components by service condition to the extent supported by the data. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will include sensitivity studies to consider the impact of grouping data into operating vs standby failure rates and by service condition.

Gap #3: As part of the Bayesian update process, checks are performed to assure that the posterior distribution is reasonable given the prior distribution and plant experience. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will verify that the Bayesian update process produces a reasonable posterior distribution.

Gap #4: Comparisons should be done of the component boundaries assumed for the generic common-cause failure (CCF) estimates to those assumed in the PRA to ensure that these boundaries are consistent. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will ensure that CCF probabilities are consistent with component boundaries and plant experience.

Gap #5: Human reliability analysis should consider the potential for calibration errors. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will identify and consider the impact that equipment calibration errors could have on the results and conclusions.

Gap #6: Maintenance and calibration activities that could simultaneously affect equipment in either different trains of a redundant system or diverse system should be identified. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will identify any work practices that could simultaneously affect equipment in either different trains of a redundant system or diverse systems.

Gap #7, #11: Mean values should be developed for pre-and post-initiator human error probabilities (HEPs). In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will use mean values for pre-and post-initiator HEPs.

Gap #8: When estimating HEPs, the impact of plant-specific and scenario-specific performance shaping factors should be considered and documented. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will use HEP values that have been quantified with consideration of plant-specific and scenario-specific performance shaping factors.

Gap #9, #10, #12: Human reliability analysis (HRA) documentation should be enhanced to include time available to complete actions, a review of human failure events (HFEs) and their final HEPs relative to each other, and appropriate credit if given for operator recovery actions. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will use HEP events with time available inputs based on plant-specific thermal hydraulic analyses; post-initiator HEPs will be reviewed against each other to check their

-9 reasonableness given the scenario context, plant procedures, operating practices and experience; and operator actions will only be credited if they are feasible.

Gap #13: Eight internal flooding supporting requirements are not met in the Oconee PRA. In the licensee's January 14, 2011, supplement, the licensee stated that a plan and schedule are in place for addressing internal flood issues related to the PRA Standard for Oconee. In the interim, for each surveillance frequency change, all supporting requirements not meeting capability category II will be evaluated with sensitivity studies.

Gap #14: In crediting HFEs that support the accident progression analysis, explicitly model reactor coolant system depressurization for small LOCAs and perform the dependency analysis on the HEPs. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will include a sensitivity study to assess the importance of explicitly modeling RCS depressurization for small LOCAs.

Gap #15, #18, #20, #22, #26: Collectively, these gaps identify deficiencies in the documentation process that do not directly affect the technical adequacy of the PRA model. These supporting requirements, however; do affect the long-term configuration management program. In the licensee's January 14, 2011, supplement, the licensee stated that the existence of gaps related to the content of documentation will be evaluated for each applicable surveillance test interval (STI) change.

Gap #16, #17: Enhancement to the uncertainty analysis by use of a documented, systematic process to identify significant assumptions is recommended. In the licensee's January 14, 2011, supplement, the licensee stated that use of this application will include a sensitivity analysis for these gaps per NEI 04-10 if applicable to the specific STI evaluation.

Gap #19: The acceptability of the results should be shown for the thermal hydraulic, structural, or other supporting engineering bases used to support the success criteria. In the licensee's January 14, 2011, supplement, the licensee stated that each surveillance frequency change evaluation will check and ensure the reasonableness and acceptability of the thermal hydraulic analyses result used to support the success criteria.

Gap #21, #24: System documentation should be enhanced to include an up-to-date system walkdown checklist and system engineer review for each system. In the licensee's January 14, 2011, supplement, the licensee stated that until each system notebook is updated, the impact of these gaps will be evaluated for each surveillance frequency change.

Gap #23: Quantitative evaluations should be provided for screening criterias associated with system unavailability and unreliability. In the licensee's January 14, 2011, supplement, the licensee stated that for each surveillance frequency change, the component and failure mode screening performed in the system analysis will be verified to meet the quantitative requirements provided in SY-A14.

Gap 25: A consideration of potential SSC failures due to adverse environmental conditions should be identified and documented. In the licensee's January 14, 2011, supplement, the licensee stated that for each surveillance frequency change, potential SSC failures due to adverse environmental conditions will be identified, included and documented in the analysis.

Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the level of PRA quality, combined with the proposed evaluation and disposition of gaps, is sufficient to

-10 support the evaluation of changes proposed to surveillance frequencies within the SFCP, and is consistent with Regulatory Position 2.3.1 of RG 1.177.

3.5 Scope of the PRA Oconee 1/2/3 is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10, Revision 1, to determine its potential impact on risk, due to impacts from internal events, fires, seismic, other external events, and from shutdown conditions. Consideration is made of both CDF and LERF metrics. In cases where a PRA of sufficient scope or where quantitative risk models were unavailable, the licensee uses bounding analyses, or other conservative quantitative evaluations. A qualitative screening analysis may be used when the surveillance frequency impact on plant risk is shown to be negligible or zero. The licensee's evaluation methodology is sufficient to ensure the scope of the risk contribution of each surveillance frequency change is properly identified for evaluation, and is consistent with Regulatory Position 2.3.2 of RG 1.177.

3.6 PRA Modeling The licensee will determine whether the SSCs affected by a proposed change to a surveillance frequency are modeled in the PRA. Where the SSC is directly or implicitly modeled, a quantitative evaluation of the risk impact may be carried out. The methodology adjusts the failure probability of the impacted SSCs, including any impacted common cause failure modes, based on the proposed change to the surveillance frequency. Where the SSC is not modeled in the PRA, bounding analyses are performed to characterize the impact of the proposed change to surveillance frequency. Potential impacts on the risk analyses due to screening criteria and truncation levels are addressed by the requirements for PRA technical adequacy consistent with guidance contained in RG 1.200, and by sensitivity studies identified in NEI 04-10, Revision 1.

The licensee will perform quantitative evaluations of the impact of selected testing strategy (i.e.,

staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141 and NUREG/CR-5497, as discussed in NEI 04-10 Revision 1.

Thus, through the application of NEI 04-10, Revision 1, the licensee's PRA modeling is sufficient to ensure an acceptable evaluation of risk for the proposed changes in surveillance frequency, and is consistent with Regulatory Position 2.3.3 of RG 1.177.

3.7 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the Oconee 1/2/3 PRA include a standby time-related contribution and a cyclic demand-related contribution. NEI 04-10, Revision 1, criteria adjust the time-related failure contribution of SSCs affected by the proposed change to surveillance frequency. This is consistent with RG 1.177, Section 2.3.3 which permits separation of the failure rate contributions into demand and standby for evaluation of surveillance requirements. If the available data do not support distinguishing between the time-related failures and demand failures, then the change to surveillance frequency is conservatively assumed to impact the total failure probability of the SSC, including both standby and demand contributions.

The SSC failure rate (per unit time) is assumed to be unaffected by the change in test frequency, and will be confirmed by the required monitoring and feedback implemented after the change in

- 11 surveillance frequency is implemented. The process requires consideration of qualitative sources of information with regards to potential impacts of test frequency on SSC performance, including industry and plant-specific operating experience, vendor recommendations, industry standards, and code-specified test intervals. Thus the process is not reliant upon risk analyses as the sole basis for the proposed changes.

The potential beneficial risk impacts of reduced surveillance frequency, including reduced downtime, lesser potential for restoration errors, reduction of potential for test caused transients, and reduced test-caused wear of equipment, are identified qualitatively. Thus, through the application of NEI 04-10, Revision 1, the licensee has employed reasonable assumptions with regard to extensions of surveillance test intervals, and is consistent with Regulatory Position 2.3.4 of RG 1.177.

3.8 Sensitivity and Uncertainty Analyses NEI 04-10, Revision 1 requires sensitivity studies to assess the impact of uncertainties from key assumptions of the PRA, uncertainty in the failure probabilities of the affected SSCs, impact to the frequency of initiating events, and of any identified deviations from capability Category II of ASME PRA Standard (ASME RA-Sb-2005). Where the sensitivity analyses identify a potential impact on the proposed change, revised surveillance frequencies are considered, along with any qualitative considerations that may bear on the results of such sensitivity studies. Required monitoring and feedback of SSC performance once the revised surveillance frequencies are implemented will also be performed. Thus, through the application of NEI 04-10, Revision 1, the licensee has appropriately considered the possible impact of PRA model uncertainty and sensitivity to key assumptions and model limitations, its approach is consistent with Regulatory Position 2.3.5 of RG 1.177.

3.9 Acceptance Guidelines The licensee will quantitatively evaluate the change in total risk (including internal and external events contributions) in terms of CDF and LERF for both the individual risk impact of a proposed change in surveillance frequency and the cumulative impact from all individual changes to surveillance frequencies using the guidance contained in NRC-approved NEI 04-10, Revision 1 in accordance with the TSs SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E-6 per year for a change to the CDF, and below 1 E-7 per year for a change to the LERF. These are consistent with the limits of RG 1.174 for very small changes in risk.

Where the RG 1.174 limits are not met, the process either considers revised surveillance frequencies which are consistent with RG 1.174 or the process terminates without permitting the proposed changes. Where quantitative results are unavailable to permit comparison to acceptance guidelines, appropriate qualitative analyses are required to demonstrate that the associated risk impact of a proposed change to surveillance frequency is negligible or zero.

Otherwise, bounding quantitative analyses are required which demonstrate the risk impact is at least one order of magnitude lower than the RG 1.174 acceptance guidelines for very small changes in risk. In addition to assessing each individual SSC surveillance frequency change, the cumulative impact of all changes must result in a risk impact below 1 E-5 per year for change to CDF, and below 1 E-6 per year for change to LERF, and the total CDF and total LERF must be reasonably shown to be less than 'I E-4 per year and 'I E-5 per year, respectively. These are consistent with the limits of RG 1.174 for acceptable changes in risk, as referenced by RG 1.177

- 12 for changes to surveillance frequencies. The NRC staff interprets this assessment of cumulative risk as a requirement to calculate the change in risk from a baseline model utilizing failure probabilities based on the surveillance frequencies prior to implementation of the SFCP, compared to a revised model with failure probabilities based on changed surveillance frequencies.

The NRC staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with small risk increases (less than 5E-B CDF and 5E-9 LERF) once the baseline PRA models are updated to include the effects of the revised surveillance frequencies.

The quantitative acceptance guidance of RG 1.174 is supplemented by qualitative information to evaluate the proposed changes to surveillance frequencies, including industry and plant-specific operating experience, vendor recommendations, industry standards, the results of sensitivity studies, and SSC performance data and test history.

The final acceptability of the proposed changes are based on all of the considerations and not solely on the PRA results compared to numerical acceptance guidelines. Post implementation performance monitoring and feedback are also required to assure continued reliability of the components. The licensee's application of NEI 04-10, Revision 1, provides reasonable acceptance guidelines and methods for evaluating the risk increase of proposed changes to surveillance frequencies, consistent with Regulatory Position 2.4 of RG 1.177. Therefore, the licensee's proposed methodology satisfies the fourth key safety principle of RG 1.177 by assuring any increase in risk is small consistent with the intent of the Commission's Safety Goal Policy Statement, "Use of Probabilistic Risk Assessment (PRA) Methods in Nuclear Regulatory Activities" (ADAMS Accession No. ML051610044).

3.10 The Impact of the Proposed Change Should Be Monitored Using Performance Measurement Strategies The licensee's adoption of TSTF-425, Revision 3, requires application of NEI 04-10, Revision 1, in the SFCP. NEI 04-10, Revision 1 requires performance monitoring of SSCs whose surveillance frequency has been revised as part of a feedback process to assure that the change in test frequency has not resulted in degradation of equipment performance and operational safety. The monitoring and feedback includes consideration of maintenance rule monitoring of equipment performance. In the event of degradation of SSC performance, the surveillance frequency will be reassessed in accordance with the methodology, in addition to any corrective actions which may apply as part of the maintenance rule requirements. The performance monitoring and feedback specified in NEI 04-10, Revision 1, is sufficient to reasonably assure acceptable SSC performance and is consistent with Regulatory Position 3.2 of RG 1.177. Thus, the fifth key safety principle of RG 1.177 is satisfied.

3.11 Addition of Surveillance Frequency Control Program to TS Section 5 The licensee has included the SFCP and specific requirements into TS Section 5.5.19, Administrative Controls, as follows:

This program provides controls for surveillance frequencies. The program ensures that surveillance requirements speCified in the TSs are performed at intervals (frequencies) sufficient to assure that the associated limiting conditions for operation are met.

- 13

a. The Surveillance Frequency Control Program contains a list of frequencies of those surveillance requirements for which the frequency is controlled by the program.

b. Changes to the frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, Revision 1.

c. The provisions of surveillance requirements 3.0.2 and 3.0.3 are applicable to the frequencies established in the Surveillance Frequency Control Program.

The NRC staff concludes that the proposed addition to the Administrative Controls sectioning the TSs adequately identifies the scope of the SFCP and defines the methodology to be used in a revision of SR frequencies. Therefore, the proposed TS change is acceptable.

4.0

SUMMARY

The NRC staff has reviewed the licensee's proposed relocation of certain surveillance frequencies to a licensee-controlled document, and controlling changes to surveillance frequencies in accordance with a new program, the SFCP, identified in the administrative controls of the TSs. The SFCP and TS Section 5.5.19 reference NEI 04-10, Revision 1, which provides a risk-informed methodology using plant-specific risk insights and performance data to revise surveillance frequencies within the SFCP. This methodology supports relocating surveillance frequencies from the TSs to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10, Revision 1, which is specified in the administrative controls of the TSs.

The proposed licensee's adoption of TSTF-425, Revision 3, and risk-informed methodology of NEI 04-10, Revision 1, as referenced in the administrative controls of the TSs, satisfies the key principles of risk-informed decision making applied to changes to the TSs as delineated in RG 1.177 and RG 1.174, in that:

The proposed change meets current regulations;

The proposed change is consistent with defense-in-depth philosophy;

The proposed change maintains sufficient safety margins;

Increases in risk resulting from the proposed change are small and consistent with the Commission's Safety Goal Policy Statement; and

The impact of the proposed change is monitored with performance measurement strategies.

Section 50.36(c)(3) states "Surveillance Requirements 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 limiting conditions for operation will be met." The NRC staff finds that with the proposed relocation of surveillance frequencies to an owner-controlled document and administratively controlled in accordance with the TS SFCP, Oconee 1/2/3 continues to meet the regulatory requirement of 10 CFR 50.36, and specifically. 10 CFR 50.36(c)(3), surveillance requirements.

- 14

5.0 STATE CONSULTATION

In accordance with the Commission's regulations, the South Carolina State official was notified of the proposed issuance of the amendments. The State official had no comments.

6.0 ENVIRONMENTAL CONSIDERATION

The amendments change a requirement with respect to the installation or use of facility components located within the restricted area as defined in 10 CFR Part 20 and change surveillance requirements. 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 published in the Federal Register on September 7, 2010 ( 75 FR 54393).

The amendments also relate to changes in recordkeeping, reporting, or administrative procedures or requirements. Accordingly, the amendments meet the eligibility criteria for categorical exclusions set forth in 10 CFR 51.22(c)(9) and 10 CFR 51.22(c)(1 0). Pursuant to 10 CFR 51.22(b) no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

7.0 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) 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.

Principal Contributor: J. Patel, NRRlDRA Date: March 21, 2011

P. Gillespie

- 2 If you have any questions, please call me at 301-415-1345.

Sincerely, IRA!

John Stang, Senior Project Manager Plant Licensing Branch 11-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. 50-269, 50-270, and 50-287

Enclosures:

1. Amendment No. 372 to DPR-38

2. Amendment No. 374 to DPR-47

3. Amendment No. 373 to DPR-55

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v t e Letter Sequence Approval
TAC:ME3840, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME3841, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME3842, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request Acceptance... Administration Questions Answers 14 January 2011 17 March 2011 Results Approval, Approval Other: ML11257A192
MONTHYEAR2011-03-21 [Table View]

ML110470446

Text

SUBJECT:

Dear Mr. Gillespie:

Enclosures:

Attachment:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

SUMMARY

5.0 STATE CONSULTATION

6.0 ENVIRONMENTAL CONSIDERATION

7.0 CONCLUSION

Enclosures:

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