Text

Issuance of Amendment Nos. 188, 188, and 188, Adoption of TSTF-425, Rev. 3, Relocate Surveillance Frequencies to Licensee Control - Risk Informed Technical Specification Task Force (RITSTF) Initiative 5b
	ML112620293
Person / Time
Site:	Palo Verde
Issue date:	12/15/2011
From:	Lauren Gibson; Plant Licensing Branch IV
To:	Edington R; Arizona Public Service Co
	Gibson, Lauren, NRR/DORL/LPL4, 415-1056
References
	TAC ME6010, TAC ME6011, TAC ME6012
	Download: ML112620293 (145)
	v • d • e

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 December 15, 2011 Mr. Randall K. Edington Executive Vice President Nuclear!

Chief Nuclear Officer Mail Station 7602 Arizona Public Service Company P.O. Box 52034 Phoenix, AZ. 85072-2034

SUBJECT:

PALO VERDE NUCLEAR GENERATING STATION, UNITS 1,2, AND 3 ISSUANCE OF AMENDMENTS RE: ADOPTION OF TSTF-425, REVISION 3, "RELOCATE SURVEILLANCE FREQUENCIES TO LICENSEE CONTROL RITSTF INITIATIVE 5B" (TAC NOS. ME6010, ME6011, AND ME6012)

Dear Mr. Edington:

The U.S. Nuclear Regulatory Commission (NRC, the Commission) has issued the enclosed Amendment No. 188 to Renewed Facility Operating License No. NPF-41, Amendment No. 188 to Renewed Facility Operating License No. NPF-51, and Amendment No. 188 to Renewed Facility Operating License No. NPF-74 for the Palo Verde Nuclear Generating Station, Units 1, 2, and 3, respectively. The amendments consist of changes to the Technical Specifications (TSs) in response to your application dated March 31,2011, as supplemented by letter dated August 12, 2011.

The amendments revise the TSs by relocating certain surveillance frequencies to a licensee controlled program in accordance with Nuclear Energy Institute (NEI) 04-10, "Risk-Informed Technical Specification Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies." The amendments adopt NRC-approved Technical Specification Task Force (TSTF)-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control - RITSTF

[Risk-Informed TSTF] Initiative 5b." When implemented, TSTF-425 relocates most periodic frequencies of TS surveillances to a licensee-controlled program, the Surveillance Frequency Control Program, and provides requirements for the new program in the Administrative Controls section of the TSs. The amendments also approve two deviations from TSTF-425, Revision 3:

an administrative change which would allow it to retain a definition that also appears in a portion of the plants' TS that are not subject to TSTF-425 and TS Bases changes recommended by the NRC to the TSTF in a letter dated April 14, 2010.

R. Edington

-2 A copy of the related Safety Evaluation is also enclosed. The Notice of Issuance will be included in the Commission's next biweekly Federal Register notice.

Sincerely, Lauren K. Gibson, Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation Docket Nos. STN 50-528, STN 50-529, and STN 50-530

Enclosures:

1. Amendment No. 188 to NPF-41

2. Amendment No. 188 to NPF-51

3. Amendment No. 188 to NPF-74

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

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 ARIZONA PUBLIC SERVICE COMPANY, ET AL.

DOCKET NO. STN 50-528 PALO VERDE NUCLEAR GENERATING STATION, UNIT 1 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 188 License No. NPF-41

1.

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

A.

The application for amendment by the Arizona Public Service Company (APS or the licensee) on behalf of itself and the Salt River Project Agricultural Improvement and Power District, EI Paso Electric Company, Southern California Edison Company, Public Service Company of New Mexico, Los Angeles Department of Water and Power, and Southern California Public Power Authority dated March 31, 2011, as supplemented by letter dated August 12, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations set forth in 10 CFR Chapter I; B.

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

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

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

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

- 2

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C(2) of Renewed Facility Operating License No. NPF-41 is hereby amended to read as follows:

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated into this license. APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in speCific license conditions.

3.

This license amendment is effective as of the date of issuance and shall be implemented within 180 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License No. NPF-41 and Technical Specifications Date of Issuance: December 15. 2011

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 ARIZONA PUBLIC SERVICE COMPANY, ET AL.

DOCKET NO. STN 50-529 PALO VERDE NUCLEAR GENERATING STATION, UNIT 2 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 188 License No. NPF-51

1.

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

A.

The application for amendment by the Arizona Public Service Company (APS or the licensee) on behalf of itself and the Salt River Project Agricultural Improvement and Power District, EI Paso Electric Company, Southern California Edison Company, Public Service Company of New Mexico, Los Angeles Department of Water and Power, and Southern California Public Power Authority dated March 31, 2011, as supplemented by letter dated August 12, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations set forth in 10 CFR Chapter I; B.

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

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

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

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

-2

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C(2} of Renewed Facility Operating License No. NPF-51 is hereby amended to read as follows:

{2}

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated into this license. APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

3.

This license amendment is effective as of the date of issuance and shall be implemented within 180 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley, Chief Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating License No. NPF-51 and Technical Specifications Date of Issuance: December 15, 2011

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555-0001 ARIZONA PUBLIC SERVICE COMPANY, ET AL.

DOCKET NO. STN 50-530 PALO VERDE NUCLEAR GENERATING STATION, UNIT 3 AMENDMENT TO RENEWED FACILITY OPERATING LICENSE Amendment No. 188 License No. NPF-74

1.

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

A.

The application for amendment by the Arizona Public Service Company (APS or the licensee) on behalf of itself and the Salt River Project Agricultural Improvement and Power District, EI Paso Electric Company, Southern California Edison Company, Public Service Company of New Mexico, Los Angeles Department of Water and Power, and Southern California Public Power Authority dated March 31 t 2011 t as supplemented by letter dated August 12, 2011, complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act) and the Commission's regulations set forth in 10 CFR Chapter I; B.

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

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

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

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

- 2

2.

Accordingly, the license is amended by changes to the Technical Specifications as indicated in the attachment to this license amendment, and Paragraph 2.C(2) of Renewed Facility Operating license No. NPF-74 is hereby amended to read as follows:

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188. and the Environmental Protection Plan contained in Appendix B. are hereby incorporated into this license. APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

3.

This license amendment is effective as of the date of issuance and shall be implemented within 180 days of the date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Michael T. Markley. Chief Plant licensing Branch IV Division of Operating Reactor licensing Office of Nuclear Reactor Regulation

Attachment:

Changes to the Renewed Facility Operating license No. NPF-74 and Technical Specifications Date of Issuance: December 15, 2011

-5 (1)

Maximum Power Level Arizona Public Service Company (APS) is authorized to operate the facility at reactor core power levels not in excess of 3990 megawatts thermal (100% power), in accordance with the conditions specified herein.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated into this renewed operating license.

APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

(3)

Antitrust Conditions This renewed operating license is subject to the antitrust conditions delineated in Appendix C to this renewed license.

(4)

Operating Staff Experience Reguirements Deleted (5)

Post-Fuel-Loading Initial Test Program (Section 14, SER and SSER 2>*

Deleted (6)

Environmental Qualification Deleted (7)

Fire Protection Program APS shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility, as supplemented and amended, and as approved in the SER through Supplement 11, subject to the following provision:

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

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

Renewed Facility Operating License No. NPF-41 Amendment No. 188

-6 (1)

Maximum Power Level Arizona Public Service Company (APS) is authorized to operate the facility at reactor core power levels not in excess of 3990 megawatts thermal (100% power) in accordance with the conditions specified herein.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated into this renewed operating license.

APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

(3)

Antitrust Conditions This renewed operating license is subject to the antitrust conditions delineated in Appendix C to this renewed operating license.

(4)

Operating Staff Experience Requirements (Section 13.1.2. SSER 9)'

Deleted (5)

Initial Test Program (Section 14. SER and SSER 2)

Deleted (6)

Fire Protection Program APS shall implement and maintain in effect all provisions of the approved fire protection program as described in the Final Safety Analysis Report for the facility, as supplemented and amended, and as approved in the SER through Supplement 11, subject to the following provision:

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

(7)

Inservice Inspection Program (Sections 5.2.4 and 6.6. SER and SSER 9)

Deleted

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

Renewed Facility Operating License No. NPF-51 Amendment No. 188

-4 (4)

Pursuant to the Act and 10 CFR Part 30, 40, and 70, APS to receive, possess, and use in amounts required any byproduct, source or special nuclear material without restriction to chemical or physical form, for sample analysis or instrument calibration or associated with radioactive apparatus or components; and (5)

Pursuant to the Act and 10 CFR Parts 30, 40, and 70, APS to possess, but not separate, such byproduct and special nuclear materials as may be produced by the operation of the facility.

C.

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

(1)

Maximum Power Level Arizona Public Service Company (APS) is authorized to operate the facility at reactor core power levels not in excess of 3990 megawatts thermal (100% power), in accordance with the conditions specified herein.

(2)

Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A, as revised through Amendment No. 188, and the Environmental Protection Plan contained in Appendix 8, are hereby incorporated into this renewed operating license.

APS shall operate the facility in accordance with the Technical Specifications and the Environmental Protection Plan, except where otherwise stated in specific license conditions.

(3)

Antitrust Conditions This renewed operating license is subject to the antitrust conditions delineated in Appendix C to this renewed operating license.

(4)

Initial Test Program (Section 14, SER and SSER 2)

Deleted (5)

Additional Conditions The Additional Conditions contained in Appendix 0, as revised through Amendment No. 171, are hereby incorporated into this renewed operating license. The licensee shall operate the facility in accordance with the Additional Conditions.

Renewed Facility Operating License No. NPF-74 Amendment No. 188

ATTACHMENT TO LICENSE AMENDMENT NOS. 188. 188. AND 188 RENEWED FACILITY OPERATING LICENSE NOS. NPF-41, NPF-51. AND NPF-74 DOCKET NOS. STN 50-528. STN 50-529. AND STN 50-530 Replace the following pages of the Renewed Facility Operating Licenses Nos. NPF-41, NPF-51, and NPF-74, and Appendix A Technical Specifications with the attached revised pages. The revised pages are identified by amendment number and contain marginal lines indicating the areas of change.

Renewed Facilit~ OQerating License No. NPF-41 REMOVE INSERT 5

5 Renewed Facilit~ OQerating License No. NPF-51 REMOVE INSERT 6

6 Renewed Facilit~ OQerating License No. NPF-74 REMOVE INSERT 4

4 Technical S~ecifications REMOVE INSERT REMOVE INSERT REMOVE INSERT REMOVE INSERT 3.1.1-1 3.1.1-1 3.3.10-3 3.3.10-3 3.5.3-2 3.5.3-2 3.8.1-9 3.8.1-9 3.1.2-2 3.1.2-2 3.3.11-2 3.3.11-2 3.5.3-3 3.5.3-3 3.8.1-10 3.8.1-10 3.1.3-2 3.1.3-2 3.3.12-3 3.3.12-3 3.5.5-2 3.5.5-2 3.8.1-11 3.8.1-11 3.1.5-3 3.1.5-3 3.4.1-2 3.4.1-2 3.5.6-1 3.5.6-1 3.8.1-12 3.8.1-12 3.1.6-2 3.1.6-2 3.4.2-1 3.4.2-1 3.6.2-4 3.6.2-4 3.8.1-13 3.8.1-13 3.1.7-3 3.1.7-3 3.4.3-2 3.4.3-2 3.6.3-5 3.6.3-5 3.8.1-14 3.8.1-14 3.1.8-2 3.1.8-2 3.4.4-1 3.4.4-1 3.6.3-6 3.6.3-6 3.8.1-15 3.8.1-15 3.1.9-2 3.1.9-2 3.4.5-2 3.4.5-2 3.6.4-1 3.6.4-1 3.8.1-16 3.8.1-16 3.1.10-2 3.1.10-2 3.4.6-2 3.4.6-2 3.6.5-1 3.6.5-1 3.8.1-17 3.8.1-17 3.2.1-2 3.2.1-2 3.4.6-3 3.4.6-3 3.6.6-2 3.6.6-2 3.8.3-3 3.8.3-3 3.2.2-2 3.2.2-2 3.4.7-3 3.4.7-3 3.7.4-2 3.7.4-2 3.8.4-2 3.8.4-2 3.2.3-3 3.2.3-3 3.4.8-2 3.4.8-2 3.7.5-3 3.7.5-3 3.8.4-3 3.8.4-3 3.2.4-2 3.2.4-2 3.4.9-2 3.4.9-2 3.7.5-4 3.7.5-4 3.8.4-4 3.8.4-4 3.2.5-1 3.2.5-1 3.4.11-2 3.4.11-2 3.7.6-1 3.7.6-1 3.8.6-2 3.8.6-2 3.3.1-3 3.3.1-3 3.4.12-1 3.4.12-1 3.7.7-2 3.7.7-2 3.8.6-3 3.8.6-3 3.3.1-4 3.3.1-4 3.4.12-2 3.7.8-2 3.7.8-2 3.8.7-2 3.8.7-2 3.3.1-5 3.3.1-5 3.4.13-3 3.4.13-3 3.7.9-1 3.7.9-1 3.8.8-2 3.8.8-2 3.3.1-6 3.3.1-6 3.4.14-2 3.4.14-2 3.7.10-1 3.7.10-1 3.8.9-2 3.8.9-2 3.3.2-3 3.3.2-3 3.4.15-2 3.4.15-2 3.7.11-3 3.7.11-3 3.8.10-2 3.8.10-2 3.3.2-4 3.3.2-4 3.4.15-3 3.4.15-3 3.7.12-2 3.7.12-2 3.9.1-1 3.9.1-1 3.3.3-4 3.3.3-4 3.4.16-2 3.4.16-2 3.7.13-1 3.7.13-1 3.9.2-2 3.9.2-2 3.3.4-3 3.3.4-3 3.4.16-3 3.4.16-3 3.7.13-2 3.7.13-2 3.9.3-2 3.9.3-2 3.3.5-3 3.3.5-3 3.4.17-2 3.4.17-2 3.7.14-1 3.7.14-1 3.9.4-2 3.9.4-2 3.3.6-3 3.3.6-3 3.4.17-3 3.4.17-3 3.7.15-2 3.7.15-2 3.9.5-2 3.9.5-2 3.3.7-3 3.3.7-3 3.5.1-2 3.5.1-2 3.7.16-1 3.7.16-1 3.9.6-1 3.9.6-1 3.3.8-2 3.3.8-2 3.5.1-3 3.8.1-6 3.8.1-6 3.9.7-1 3.9.7-1 3.3.8-3 3.3.8-3 3.5.2-2 3.5.2-2 3.8.1-7 3.8.1-7 5.5-17 5.5-17 3.3.9-2 3.3.9-2 3.5.2-3 3.5.2-3 3.8.1-8 3.8.1-8 5.5-18 3.3.9-3 3.3.9-3

SDM Reactor Trip Breakers Open 3,1.1 3,1 REACTIVITY CONTROL SYSTEMS 3,1,1 SHUTDOWN MARGIN (SDM)

Reactor Trip Breakers Open LCO 3,1,1 SDM shall be ~ the value in the COLR, APPLICABILITY:

MODES 3, 4, and 5 with the Reactor Trip Breakers Open or the drive system not capable of CEA withdrawal, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A,

SDM not within limit, A,l Initi boration to restore SDM to within

1imit, 15 minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3,1.1.1 Verify SDM is ~ the value in the COLR, In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3,1.1-1

,~MENDMENT NO, ill, 188

SDM - Reactor Trip Breakers Closed 3.1. 2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 2.1 Verify SDM is;?: the value in the COLR.

In accordance with the Surveillance Frequency Control Program SR 3.1. 2.2 NOTE Only required if Te S 500°F.

Veri fy KN-1 < 0.99.

In accordance with the Surveillance Frequency Control Program SR 3.1. 2.3 Verify criticality cannot be achieved with shutdown group CEA movement.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2.3 3.1.2-2 AMENDMENT NO. W. 188

Reactivity Balance 3.1 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.l. 3.1

NOTES 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 (EFPO) after each fuel loading.

Verify overall core reactivity balance is within +/- 1.0% Ak/k of predicted values.

FREQUENCY Prior to entering MODE 1 after fuel loading AND

NOTE Only requi red after 60 EFPO In accordance with the Surveillance Frequency Control Program PALO UNITS 1. 2,3 3.l.32 AMENDMENT NO.

, 188

CEA Alignment 3.1. 5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 5.1 Verify the indicated position of each full strength and part strength CEA is within 6.6 inches of all other CEAs in i group.

In accordance with the Surveillance Frequency Control Program SR 3.1. 5. 2 Verify that. for each CEA. i OPERABLE CEA position indicator channels indi within 5.2 inches of each other.

In accordance with the Surveillance Frequency Control Program SR 3.1. 5.3 Verify full strength CEA freedom of movement (tr'j ppabi 1ity) by movi ng each individual full strength CEA that is not fully inserted in the core at 1 5

inches.

In accordance with the Surveillance Frequency Control Program SR 3.1. 5.4 Perform a CHANNEL FUNCTIONAL reed switch position transmi of each channel.

In accordance with the Surveillance Frequency Control Program SR 3.1. 5.5 Verify each full s 4.0 seconds.

strength CEA drop time Prior to reactor cri cality.

after each removal of the reactor head PALO VERDE UNITS 1.2.3 3.1.5 3 AMENDMENT NO. ++9. 188

Shutdown CEA Insertion Limits 3.1.6 SURVEILLANCE REQUIREMENTS SURVEILLANCE I

FR:EQUIIENCY SR 3.1. 6.1 Verify each shutdown CEA is withdrawn

147.75 inches.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN

1. 2,3 3.1. 2 AMENDMENT NO..ffl8, 188

Regulating CEA Insertion mits 3.1. 7 SURVEIllANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 7.1

NOTE--

This Surveillance is not required to be performed prior to entry into MODE 2.

Verify each regulating CEA group position is within its insertion limits.

In accordance with the Surveillance Frequency Control Program SR 3.1. 7.2 Verify the accumulated times during which the regulating CEA groups are inserted beyond the steady state insertion limits but within the transient insertion limits.

In accordance with the Surveillance Frequency Control Program SR 3.1. 7.3 Verify POll alarm circuit is OPERABLE.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.7-3 AMENDMENT I~O. W. 188

Part Strength CEA Insertion Limi 3.1. 8 ACTIONS (continued)

COND ON REQUIRED ACTION COMPLETION TIME C. Requi red on and associ Completion Time not C.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1. 8.1 Verify part strength CEA group position.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN 1.2,3 3.1.82 AMENDMENT NO. ++9, 188

-SCM 3.l. 9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.l. 9.1 Verify that the position of each not fully inserted is within the acceptance criteria for available negative reactivity addition.

In accordance with the Surveillance Frequency Control Program SR 3.l. 9.2 Verify each full strength CEA not fully inserted is capable of full insertion when tripped from at least the 50% withdrawn position.

Wi thi n 7 days prior to reducing SDM requirements to less than the 1i mi ts of LCO 3. l. 2 SR 3. l. 9.3

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

Only required to be performed in Mode 3.

Verify that with all full strength CEAs fully inserted, the reactor is subcritical within the acceptance criteria.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.1.9-2 AMENDMENT NO. ~. 188

STE - MODES 1 and 2 3.1.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.10.1 Verify THERMAL POWER equal to or less than the test power plateau.

In accordance with the Surveillance Frequency Control Program SR 3.1.10.2 Verify that the position of each CEA not fully inserted is within the acceptance criteria for available negative reactivity addition.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.1.10-2 AMENDI~ENT NO. +/-OO. 188

LHR 3.2 1 SURVEILLANCE REQUIREMENTS SLiRVEI LLANCE FREQUENCY SR 3.2.1.1

NOTE---

1.

Only applicable when COLSS is out of service.

With COLSS in service, LHR is continuously monitored

2.

Not requi red to be performed unti 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after MODE 1 with THERMAL POWER

> 20% RTP.

Verify LHR. as indicated on any OPERABLE local power density channel. is within its 1imits.

In accordance with the Surveillance Frequency Control Program SR 3.2.1. 2 Verify the COLSS margin alarm at a THERMAL POWER equal to or less than the core power operating limit based on LHR.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN

1. 2.3 3.2.1 2 AMENDMENT NO. ++/-+, 188

Fxy 3.2.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.2.1 Veri fy measured F~y obtai ned usi ng the Incore Detector System is equal to or less than the value of F;y used "in the COLSS and CPCs.

FREQUENCY Once after each fuel loading with THERMAL POWER > 40% RTP but prior to operations above 70% RTP In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.2.2-2 AMENDMENT I~O. W.188

T~

3.2.3 SURVEILLANCE REQUIREMENTS SR 3 2.3.1 SURVEILLANCE NOTES--

I.

Only applicable when COLSS is out of service. With COLSS in service. this parameter is continuously monitored.

2.

Not required to be performed until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after MODE 1 wi th THERI~AL POWER> 20% RTP.

Calculate Tq and verify it is within the 1imit.

FREQUENCY In accordance with the Surveillance Frequency Contro1 Program SR 3.2.3.2 Verify COLSS azimuthal tilt alarm is actuated at a Tq value less than the Tq value used in the CPCs.

In accordance with the Surveillance Frequency Control Program SR 3.2.3.3 Independently confirm the validity of the COLSS calculated Tq by use of the incore detectors.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.2.3-3 AMENDMENT NO. W. 188

DNBR 3.2.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

DNBR outside the region of acceptable operation when COLSS is out of service.

B.1 Determine trend in DNBR.

AND B.2.1 With an adverse trend. restore DNBR to within limit.

B.2.2 With no adverse trend. restore DNBR to within limit.

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

Required Action and associated Completion Time not met.

C.1 Reduce THERMAL POWER to ~ 20% RTP.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.4.1

NOTE

1.

Only applicable when COLSS is out of service.

With COLSS in service. this parameter is continuously monitored.

2.

Not requi red to be performed unti 1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after MODE 1 with THERMAL POWER> 20% RTP.

Verify DNBR. as indicated on any OPERABLE DNBR channels. is within the limit of the COLR. as applicable.

In accordance with the Surveillance Frequency Control Program SR 3.2.4.2 Verify COLSS margin alarm actuates at a THERMAL POWER level equal to or less than the core power operating limlt based on DNBR.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNI 1.2.3 3.2.4 2 AMENDMENT KO. +/-+9. 188

ASI 3.2.5 3.2 POWER DISTRIBUTION LIMITS 3.2.5 AXIAL SHAPE INDEX (ASI)

LCD 3.2.5 ASI shall be within the limits specified in the COLR.

APPLICABILITY:

MODE 1 with THERMAL POWER> 20% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Core average ASI not with'j n l'j mits.

A.l Restore ASI to withi n 1imits.

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.l Reduce THERMAL POWER to :::; 20% RTP.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.2.5.1 Notes ----------------

Not required to be performed untll 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after MODE 1 with THERMAL POWER> 20% RTP.

Verify ASI is within limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.2. 1 AMENDMENT NO. ++7. 188

3.3.1 RPS Instrumentation - Operating SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1-1 to determine which SR shall be performed for each RPS Function.

SR 3.3.l.1 SURVEILLANCE Perform a CHANNEL CHECK of each RPS instrument channel.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.l. 2

-I~OTE -----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER ~ 70% RTP.

Verify total Reactor Coolant System (RCS) flow rate as indicated by each CPC is less than or equal to the RCS total flow rate.

If necessary. adjust the CPC addressable constant flow coefficients such that each CPC indicated flow is less than or equal to the RCS flow rate.

In accordance with the Surveillance Frequency Control Program SR 3.3.1. 3 Check the CPC System Event Log.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.3.1-3 AMENDMENT NO. ++9.188

3.3.1 RPS Instrumentation - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.l. 4

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

1.

Not required to be performed untll 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER

~ 20% RTP.

2.

The daily calibration may be suspended during PHYSICS TESTS. provided the calibration is performed upon reaching each major test power plateau and prior to proceeding to the next major test power plateau.

Perform calibration (heat balance only) and adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC ~T power and CPC nuclear power calculations agree with the calorimetric.

if the absolute difference is ~ 2% when THERMAL POWER is ~ 80% RTP.

Between 20%

and 80% RTP the maximum difference is -0.5%

to 10%.

In accordance with the Surveillance Frequency Control Program SR 3.3.l. 5

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

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER ~ 70% RTP.

Veri fy tota 1 RCS fl ow rate i ndi cated by each CPC is less than or equal to the RCS flow determined either using the reactor coolant pump differential pressure instrumentation and the ultrasonic flow meter adjusted pump curves or by calorimetric calculations.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.3.1-4 AtIEI~DMENT NO. +/-+9. 188

RPS Instrumentation Operating 3 3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.l. 6

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

Verify linear power subchannel gains of the excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.

In accordance with the Surveillance Frequency Control Program SR 3.3.1. 7

NOTES-

1.

The CPC CHANNEL FUNCTIONAL TEST shall include verification that the correct values of addressable constants are installed in each OPERABLE CPC.

2.

Not requi red to be performed for logarithmic power level channels until 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after reducing logarithmic power below 1E-4% NRTP.

Perform CHANNEL FUNCTIONAL TEST on each channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.l. 8

NOTE Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION of the power range neutron flux channels.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1,2,3 3.3.1-5 AMENDMENT NO. m, 1BB

3.3.1 RPS Instrumentation - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1. 9

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

Neutron detectors are excluded from CHANNEL CALI BRATI ON.

Perform CHANNEL CALIBRATION on each channel, including bypass removal functions.

In accordance with the Surveillance Frequency Contro1 Program SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each CPC channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.1.11 Us i ng the i ncore detectors, veri fy the shape annealing matrix elements to be used by the CPCs.

Once after each refueling prior to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function.

Once withi n 92 days prior to each reactor startup SR 3.3.1.13

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

Neutron detectors are excluded.

Verify RPS RESPOI%E TI~IE is with-j n l-j mits.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.3.1-6 AMENDMENT NO. -+/-+9, 188

RPS Instrumentation - Shutdown 3,3,2 SURVEILLANCE REQUIREMENTS

---NOTE-Refer to Table 3,3.2 1 to determine which SR shall performed for each RPS

function, SURVEILLANCE FREQUENCY SR 3.3.2,1 Perform a CHANNEL CHECK of each RPS instrument channel, In accordance with the Surveillance Frequency Control Program SR 3,3,2,2 Perform a CHANNEL FUNCTIONAL TEST on each

channel, In accordance with the Surveillance Frequency Control Program SR 3,3,2,3 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal function, Once withi n 92 days prior to each reactor startup SR 3,3,2.4

NOTE Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform a CHANNEL CALIBRATION on each channel. including bypass removal function.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.3.2 3 AMENDMENT NO. ++/-+. 188

RPS Instrumentation - Shutdown 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.3.2.5

NOTE

Neutron detectors are excluded.

Verify RPS RESPONSE TIME is within limits.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3.2 AMENDMEI~T NO.

. 188

CEACs 3.3 3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.3.4 Perform a CHANNEL CALIBRATION In accordance with the Surveillance Frequency Control Program SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3.3-4 AMENDMEI~T NO. -l-f-9. 188

RPS Logic and Trip Initiation 3.3.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E.

Required Action and associated Completion me of Condition A.

B. or Dnot met, OR One or more Functions with more than one Manual Trip. Matrix Logic. Initiation Logic. or RTCB channel inoperable for reasons other than Condition A or D, E,l AND E.2 Be in MODE 3, Open all RTCBs, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 6 hours SURVEILLANCE REQUIREMENTS SR 3.3.4.1 SURVEI LLANCE Perform a CHANNEL FUNCTIONAL RPS Logic channel and Manual on each Trip channel.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.3.4.2 Perform a CHANNEL FUNCTIONAL TEST.

including separate verification of the undervoltage and shunt trips. on each RTCB.

In accordance with the Surveillance Frequency Control Program SR 3.3.4,3 Perform

RTCB, a CHANNEL FUNCTIONAL TEST on each In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3.4-3 AMENDMENT NO,

. 188

ESFAS Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform a CHANNEL CHECK of each channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.2 Perform a CHANNEL FUNCTIONAL TEST of each ESFAS channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.3 Perform a CHANNEL CALIBRATION of each ESFAS channel. including bypass removal functions.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.4 Verify RESPONSE TIME is within limits.

In accordance with the Surveillance Frequency Control Program SR 3.3.5.5 Perform a CHANNEL FUNCTIONAL TEST on each automatic bypass removal channel.

Once within 92 days prior to each reactor startup PALO VERDE UNITS 1,2,3 3.3.5-3 AMENDMENT NO.

188

ESFAS Logic and Manual Trip 3.3.6 ACTIONS (continued)

COND Ol~

REQUIRED ACTION COMPLETION TIME F.

Required Action and associated Completion Time of Conditions for Safety Inj on Actuation Signal.

Containment Isolation Actuation Signal. or Recirculation Actuation Signal not

met, F.l AND F,2 Be in MODE 3, Be in MODE 5, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE RE UIREMENTS SURVEILLANCE FREQUENCY SR 3.3,6.1

NOTE ting of Actuation Logic shall include the verification of the proper operation of each initiation relay, Perform a CHANNEL FUNCTIONAL logic channel and Manual

channel, on each ip In accordance with the Surveillance Frequency Control Program SR 3.3.6,2

NOTE-- - - --

Relays exempt from testing during operation shall be tested each 18 months.

Perform a subgroup relay test of Actuation Logic channel. which includes the de energization of each subgroup relay and verification of the OPERABILITY of each subgroup relay, In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3,6-3 AMENDMENT NO, W,188

DG - LOVS 3.3.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.7.2 Perform CHANNEL FUNCTIONAL In accordance with the Surveillance Frequency Control Program SR 3.3.7.3 Perform CHANNEL CALIBRATION with setpoint Allowable Values as follows:

In accordance with the Surveillance

a.

~ 3786 V

~

Control Program Time delay:

~ 28.6 seconds and

~ 35 seconds: and

b.

s of Voltage Function me delay:

~ 10.3 seconds and

~

.6 seconds at 2929.5 V. and

~ 2.0 seconds and ~ 2.4 seconds at 0 V.

Degraded Voltage Function 3697 Vand Frequency PALO VERDE UNITS 1.2.3 3.3,l-3 AIVIENDMENT NO. m. 188

CPIAS 3.3.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

CPIAS Manual Trip.

Actuation Logic. or radiation monitor inoperable during CORE AL TERATIONS or movement of irradiated fuel assemblies within containment.

C.1 Place and maintain containment purge and exhaust valves in closed position.

OR C.2.1 Suspend CORE AL TERATIONS.

Immediately Immediately A~ID C.2.2 Suspend movement of i rradi ated fuel assemblies in containment.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Perform a CHANNEL CHECK on required radiation monitor channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.8.2 Perform a CHANNEL FUNCTIONAL TEST on each requi red radi ati on moni tor channel. and Veri fy the setpo'j nt :s; 2.5 mR/hr.

In accordance with the Surve'j 11 ance Frequency Control Program SR 3.3.8.3

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

Survelllance of Actuation Logic shall include the verification of the proper operation of each actuation relay.

Perform a CHANNEL FUNCTIONAL TEST on required CPIAS Actuation Logic channel.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.3.8-2 AI~ENDI~ENT NO. ill. 188

CPIAS 3.3.8 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.8.4 Perform a CHANNEL CALIBRATION on required radiation monitor channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.8.5 Perform CHANNEL FUNCTIONAL TEST on required CPIAS Manual Trip channel.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3 3.8-3 AMENDI"1ENT NO. W. 188

CREFAS 3.3.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

CREFAS Manual Trip.

Actuation Logic. or radiation monitor inoperable in MODE 5 or 6. or during movement of irradiated fuel assemblies.

C.1 Place one CREFS train in operation.

OR C.2.1 Suspend movement of i rradi ated fuel assemblies.

AND C.2.2 Suspend positive reactivity additions.

AND C.2.3 Suspend CORE ALTERATIONS.

Immediately Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.3.9.1 Perform a CHANNEL CHECK on the required control room radiation monitor channel.

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

PALO VERDE UNITS 1,2.3 3.3.9 2 AMENDMENT NO. W,188

CREFAS 3.3.9 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.9.2 Perform a CHANNEL FUNCTIONAL on required CREFAS radiation monitor channel.

Verify CREFAS high radiation setpoint is

~ 2 x 1 0. 5 flC i Icc.

In accordance with the Surveillance Frequency Control Program SR 3.3.9.3

NOTES --

1.

Surveillance of Actuation Logic shall include the verification of the proper operation of each Actuation relay.

2.

Relays associated with plant equipment that cannot be operated during plant operation are required to be tested during each MODE 5 entry exceeding 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months unless tested within the previous 6 months.

Perform a CHANNEL FUNCTIONAL on required CREFAS Actuation Logic channel.

In accordance with the Surveillance Frequency Control Program SR 3.3.9,4 Perform a CHANNEL CALIBRATION on required CREFAS radiation monitor channel, In accordance with the Surveillance Frequency Control Program SR 3.3,9.5 Perform a CHANNEL FUNCTIONAL on required CREFAS Manual Trip channel.

In accordance with the Surveillance Frequency Control Program SR 3,3,9.6 Verify that response time of required CREFAS channel is within limits.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN 1.2,3 3.3.9-3 AMENDMENT NO. +/-+/-+, 188

PAM Instrumentation 3.3.10 SURVEILLANCE REQUIREMENTS

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

These SRs apply to each PAM instrumentation Function in Table 3.3.10-1.

SURVEILLANCE FREQUENCY SR 3.3.10.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

In accordance with the Surveillance Frequency Control Program SR 3.3.10.2

NOTE Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.3.10-3 AMENDMENT NO.

. 188

Remote Shutdown System 3.3.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.11.1 Perform CHANNEL CHECK for each required instrumentation channel that is normally energized.

In accordance with the Surveillance Frequency Control Program SR 3.3.11.2 Verify each requi red control ci rcuit and transfer switch is capable of performing the intended function.

In accordance with the Surveillance Frequency Control Program SR 3.3.11 3 NOTE --------------

Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION for each required instrumentation channel.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3.11-2 AMENDMENT NO. W. 188

Boron Dilution Alarm System (BOAS) 3.3.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.12.1

NOTE--------

Not required to be performed until 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months after neutron flux is within the startup range.

Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.3.12.2 NOTE-----

Not required to be performed until hours after neutron flux is within the startup range.

Perform CHANNEL FUNCTIONAL TEST.

In accordance with the Surveillance Frequency Control Program SR 3.3.12.3 NOTE------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.3.12 3 AMENDMENT NO.

, 188

RCS Pressure. Temperature. and Flow DNB Limits 3.4.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

Pressurizer pressure or RCS cold leg temperature not within 1i mits.

C.l Restore parameter(s) to with-j n l-j mi 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months D,

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

D,1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SR 3,4,1.1 SURVEI LLANCE Verify pressurizer pressure

2295 psia.

~ 2130 psia and FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3,4,1. 2 Verify RCS cold leg temperature within limits as shown in Figure 3,4.1-1, In accordance with the Surveillance Frequency Control Program SR 3,4,1.3 NOTE-----------

Required to be met in MODE 1 with all running.

Verify RCS total flow rate

~ 155.8 lbm/hour, In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.1-2 AMENDMENT NO. +++. 1BB

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each RCS loop temperature CTco1d ) shall be ~ 545°F.

APPLICABILITY:

MODE 1, MODE 2 with Keff ~ 1. 0.

ACTIONS CONDITIOI~

REQUIRED ACTION COI~PLETION TIME A.

Tcold

-j n one or more RCS loops not within 1i mit.

A.l Be in MODE 3.

3D minutes SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.2.1 Veri fy RCS Tcold in each 1oop ~ 545°F.

FREQUENCY

NOTE----

Only required if any RCS loop Tcold < 550°F.

In accordance with the Surveillance Frequency Control Program AND Once with-j n 3D minutes prior to reach-j ng criticality PALO VERDE UNITS 1,2,3 3.4.2-1 AI~ENDI"1ENT I~O. W,188

3.4.3 ACTIONS (continued)

COND ON C.

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

Requirements of LCD not met any me in other than MODE 1, 2.

3. or 4.

REQUIRED ACTION C.1 Initiate action to restore parameter{s) to within limits.

AND C.2 Determine RCS is acceptable for continued operation.

RCS PIT Limits COMPLETION TIME Immediately Prior to entering MODE 4 RE~IENTS SURVEILLANCE SR 3.4.3.1 NOTE ------------------

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

Verify RCS pressure. RCS temperature. and RCS heatup and cooldown rates within limits ified in the PTLR.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.3-2 Amendment No. +/-+g.188

RCS Loops - MODES 1 and 2 3 4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops - MODES 1 and 2 LCD 3.4.4 Two RCS loops shall be OPERABLE and in operation.

APPLICABILITY:

MODES 1 and 2, ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not met, A,l Be 'j n I~ODE 3, 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.4 1 AMENDMENT NO, +++. 188

RCS Loops - MODE 3 3.4.5 ACTIONS (continued)

CONDITION C. No RCS loop OPERABLE.

OR No loop 'j n operation.

SURVEILLANCE REQUIREMENTS REQUIRED ACTION COMPLETION TIME Immediately C.1 Suspend all operations involving a reduction of RCS boron concentration.

AND C.2 Initiate action to Immediately restore one RCS loop to OPERABLE status and operation.

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 secondary side water level in each steam generator ~ 25%.

In accordance with the Surveillance Frequency Control Program SR 3.4.5 3 Verify correct breaker alignment and indicated power available to the required pump that is not in operatlon.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.5 2 AMENDMENT NO. +/-+/-+.188

RCS Loops - MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTIOI~

COMPLETION TIME B.

One required SOC train inoperable.

AND Two required RCS loops inoperable.

B.1 Be in MODE 5.

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

No RCS loop or SOC train OPERABLE.

OR No RCS loop or SOC train in operation.

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

Initiate action to restore one loop or train to OPERABLE status and operation.

Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEI LLANCE FREQUENCY SR 3.4.6.1 Verify one RCS loop or SOC train is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.6.2 Verify secondary side water level in required SG(s) is ~ 25%.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1,2,3 3.4.6 2 AMENDMENT NO. ~, 188

RCS Loops MODE 4 3.4.6 SURVEILLANCE REQUIREMENTS (continued)

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

In accordance with the Surveillance Frequency Contro1 Program PALO VERDE UNITS 1.2.3 3.4.6 3 AMENDMENT NO.

. 188

RCS Loops - MODE 5. Loops Filled 3.4.7 SURVEILLANCE REQUIREMENTS SR 3.4.7.1 SURVEILLANCE Verify one SDC train is in operation.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.4.7.2 Verify required SG secondary side water level is ~ 25%.

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

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2.3 3.4.7-3 AMENDMENT NO.

.188

RCS Loops MODE 5. Loops Not Filled 3.4.8 ACTIONS (continued)

COND ION REQUIRED ACTION COMPLETION TIME B.

Required SOC trains inoperable.

OR No SOC train in operation.

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

Immediately B.2 Initiate action to restore one SOC train to OPERABLE status and operation.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one SOC train is in operation.

In accordance with the Surveillance Frequency Control Program SR 3.4.8.2 Verify correct breaker alignment and i ndi cated power avan ab 1e to the requi red SOC pump that is not in operation.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.8-2 AMENDMENT NO. +/-+/-+.188

Pressurizer 3.4.9 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 Be in MODE

3.

4.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 12 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level s 56%

is ~ 27% and In accordance with the Surveillance Frequency Control Program SR 3.4 9 2 Verify capacity of each required group of pressurizer heaters ~ 125 kW.

In accordance with the Surveillance Frequency Control Program PALO UNITS 1. 2,3 3.4.9 2 AMENDMENT NO. W. 188

Pressurizer Safety Valves MODE 4 3.4.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 Verify the required pressurizer safety In accordance valve is OPERABLE in accordance with the with the Inservice Testing Program.

Following Inservice ng, lift settings shall be within Testing Program

+/- 1%.

SR 3.4.11.2

NOTE Only required to be performed when a Shutdown Cooling System suction line relief valve is being used for overpressure protection.

Verify the required Shutdown Cooling System suction line relief valve is aligned to In accordance with the Surveillance Frequency Control Program provide overpressure protection for the RCS.

SR 3.4.11.3 Verify the required Shutdown Cooling System In accordance suction line relief valve is OPERABLE with with the the required setpoint.

Inservice ng Program PALO VERDE UNITS 1,2.3 3.4.11-2 AMENDMENT NO. +/-+/-+.188

Pressurizer Vents 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Pressurizer Vents LCO 3.4.12 Four pressurizer vent paths shall be OPERABLE.

APPLICABILITY:

MODES 1, 2. and 3.

MODE 4 with RCS pressure ~ 385 psia.

ACTIONS COND ON REQUIRED ACTION COMPLETION TIME A.

Two or three required pressurizer vent paths

-j noperab1 e.

A.l Restore required pressurizer vent paths to OPERABLE status.

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

All pressurizer vent paths inoperable.

B.l Restore one pressurizer vent path to OPERABLE status.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months C.

Required Action and associated Completion Time of Condition A.

or B not met.

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

Be in MODE 4 with RCS pressure < 385 psia.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 24 hours PALO VERDE UNITS 1,2,3 3.4.12 1 AMENDMENT NO. W. 188

Pressurizer Vents 3.4.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Perform a complete cycle of each Pressurizer Vent Valve.

In accordance with the Surveillance Frequency Control Program SR 3.4.12.2 Verify flow through each pressurizer vent path.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.4.12-2 AMENDMENT NO. +l-7-, 188

LTOP System 3.4.13 SURVEILLANCE REQUIREMENTS SR 3.4.13.1 SURVEILLANCE Verify RCS Vent ~

open.

16 square inches is FREQUENCY In accordance with the Surveillance Frequency Control Program SR SR 3.4.13.2 3.4.13.3 Verify each Shutdown Cooling System suction line relief valve is aligned to provide overpressure protection for the RCS.

Verify each Shutdown Cooling System suction line reli valve is OPERABLE with the required setpoint.

In accordance with the Surveillance Frequency Control Program In accordance with the Inservice Testing Program.

PALO VERDE UN

1. 2.3 3.4.13 3 AMENDMENT NO. +/-+/-7.188

RCS Operational LEAKAGE 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3,4,14.1

NOTES---------

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 In accordance Perform ReS water inventory balance.

with the Surveillance Frequency Control Program SR 3.4.14.2

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

Verify primary to secondary LEAKAGE is In accordance

$ 150 gallons per day through anyone SG, with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.4.14-2 AMENDMENT NO.

188

ACTIONS (continued)

COND ION REQUIRED ACTION B.

Required Action and B.1 Be in MODE 3.

associated Completion AND Time for Condition A not met.

B.2 Be in MODE 5.

RCS PIV Leakage 3.4.15 CO~IPLETION TI~IE 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.15.1

--NOTES--

1.

Not requi red to be performed in MODES 3 and 4.

2.

Not required to be performed on the RCS PIVs located in the SOC flow path when in the shutdown cooling mode of operation.

3.

RCS PIVs actuated duri ng the performance of this Surveillance are not required to be tested more than once if a repetitive testing loop cannot be avoided.

Verify leakage from each RCS PIV is equivalent to 5 0.5 gpm per nominal inch of valve size up to a maximum of 5 gpm at an RCS pressure ~ 2230 pSia and 5 2270 pSia.

FREQUENCY In accordance with the Surveillance Frequency Control Program AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more.

if leakage testing flas not been performed in the previous 9 months.

except for SDC PIVs AND (continued)

PALO VERDE UNITS 1.2.3 3.4.15-2 AMENDMENT NO. +1+. 188

RCS PIV Leakage 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 (continued)

Withi n 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following valve actuation due to automatic or manual action or flow through the valve.

except for SOC PIVs.

SR 3.4.15.2 Verify SOC System open permissive interlock prevents the valves from being opened with a simulated or actual RCS pressure signal

410 pSia.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.15-3 AI~ENO~IENT NO. W. 188

RCS Leakage Detection Instrumentation 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION

~IE B.

Required containment atmosphere radioactivity monitor inoperable.

B.1.1 OR B.1.2 AND B.2 Analyze grab samples of the containment atmosphere.

Perform SR 3.4.14.1.

Restore required containment atmosphere radioactivity monitor to OPERABLE status.

Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 30 days C.

D.

Required Action and associated Completion Time not met.

All required monitors inoperable.

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

Be in MODE 5.

Enter LCD 3.0.3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Perform CHANNEL CHECK of the required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program SR 3.4.16.2 Perform CHANNEL FUNCTIONAL TEST of the required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UN

1. 2.3 3.4.16 2 AMENDMENT NO.

. 188

RCS Leakage Detection Instrumentation 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3 Perform CHANNEL CALIBRATION of the required containment sump monitor.

In accordance with the Surveillance Frequency Control Program SR 3.4.16.4 Perform CHANNEL CALIBRATION of the required containment atmosphere radioactivity monitor.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.4.16 3 AMENDMENT NO. ++/-+.188

RCS Specific Activity 3.4.17 ACTIONS (continued)

CONDITION REQU IRED ACTI ON COMPLETION TIME B. Required Action and associated Completion Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.

1.

B.1 Be in MODE 3 with

< 500°F.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months C. Gross specifi c C.1 Perform SR 3.4.17.2.

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months act; vity of the reactor coolant not AND with in 1i mit.

C.2 Be in MODE 3 with

< 500°F.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.4.17.1 Verify reactor coolant gross specific acti vity ~ 1001 E tiei 19m.

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

PALO VERDE UNITS 1,2,3 3.4.17-2 AMENDMENT NO. +/-Y,188

RCS Specific Activity 3.4.17 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.17.2 Verify reactor coolant DOSE EQUIVALENT I 131 specific activity s 1. 0 pCi Igm.

-NOTE Only required to be performed in MODE 1.

In accordance with the Surveillance Frequency Control Program A~ID Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after THERMAL POWER change

~ 15% RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period SR 3.4.17.3

-NOTE Not required to be performed until 31 days after a minimum of 2 EFPD and 20 days 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 from a sample taken in MODE 1 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 .

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2,3 3.4.17 3 AMENDI"1ENT NO.

. 188

SITs-Operati ng 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each SIT isolation valve is fully open.

In accordance with the Surveillance Frequency Control Program SR 3.5.1. 2 Verify borated water volume in each S is

~ 28% narrow range and s 72% narrow range.

In accordance with the Surveillance Frequency Control Program SR 3.5.1.3 Verify nitrogen cover pressure in each SIT is ~ 600 psig and s 625 psig.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1,2,3 3.5.1-2 AMEfl:OMENT NO.

,188

SITs -Operati ng 3.5.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.1. 4 Verify boron concentration in each SIT is

~ 2300 ppm and ~ 4400 ppm.

In accordance with the Surveillance Frequency Control Program AND

-NOTE -

Only required to be performed for affected SIT Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

whenever a S is drained to ma-intain the contained borated water 1eve1 withi n the 1imits of SR 3.5.1. 2.

SR 3.5.1. 5 Verify power is removed from each SIT isolation valve operator.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN 1.2.3 3.5.1 AMENDMENT NO. W. 188

SITs Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify each required SIT isolation valve is fully open when pressurizer pressure is

? 430 psia.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.2 Verify borated water volume in each requ ired Sis:

a.

For four OPERABLE SITs. > 39% wide range indication and < 83% wide range indication.

OR

b.

For three OPERABLE SITs. > 60% wide range indication and < 83% wide range indication.

In accordance with the Surveillance Frequency Control Program SR 3.5.2.3 Verify nitrogen required SIT is cover pressure in each

? 260 psig and ~ 625 psig.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2,3 3.5.2-2 AMENDMENT NO. +/-++.188

SITs -Shutdown 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.4 Verify boron concentration in each required SIT is ~ 2300 ppm and ~ 4400 ppm.

In accordance with the Surveillance Frequency Control Program AND

NOTE-----

Only requi red to be performed for affected SIT Once withi n 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

whenever a requ'ired SIT is drained to maintain the contained borated water 1eve 1 withi n the 1i mits of SR 3.5.2.2.

SR 3.5.2.5 Verify power is removed from each required SIT isolation valve operator when pressurizer pressure is ~ 1500 psia.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.5.2-3 AMENDMENT NO. +/-+/-+.188

ECCS Operating 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 Verify each ECCS manual, power operated.

and automatic valve in the flow path. that is not locked. sealed. or otherwise secured in position, is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.2 Verify ECCS piping is full of water.

In accordance wi th the Surveillance Frequency Control Program SR 3.5.3.3 Verify each ECCS pump develops the required differential pressure at the flow test point.

In accordance with the Inservice Testing Program SR 3.5.3.4 Verify each ECCS automatic valve that is not locked. sealed. or otherwise secured in position. in the flow path actuates to the correct position on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.5 Verify each ECCS pump starts automatically on an actual or Simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.5.3.6 Verify each LPSI pump stops on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.53-2 AMENDMENT NO. W. 188

ECCS - Operating 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.7 Verify, for each ECCS throttle valve listed below, each position stop is in the correct posi on.

LPSI System Hot Leg Injection Valve Number Valve Numbers In accordance with the Surveillance Frequency Control Program SI UV 615 SIB-UV 625 SIA-UV 635 SIA-UV 645 SIA-HV 306 SI HV 307 SIC-HV 321 SIO-HV 331 SR 3.5.3.8 Verify, by visual inspection, each ECCS train containment sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.5.3 3 AMENDMENT NO..p..g, 188

RWT 3.5.5 SURVEILLANCE REQUIREMENTS SLiRVEI LLANCE FREQUENCY SR 3.5.5.1 NOTE Only required to be performed when ambient air temperature is < 60°F or > 120°F.

Verify RWT borated water temperature is 260°F and ~ 120°F.

In accordance with the Surveillance Frequency Control Program SR 3.5.5.2 Verify RWT borated water volume is 2 minimum required RWT volume in Figure 3.5.5 1.

In accordance with the Surveillance Frequency Control Program SR 3.5.5.3 Verify RWT boron concentration is 24000 ppm and ~ 4400 ppm.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.5.5-2 AMENDMENT NO. +/-+/-+. 188

TSP 3.5.6 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.6 Trisodium Phosphate (TSP)

LCO 3.5.6 The TSP baskets shall contain ~ 524 ft 3 of active TSP.

APPLI CAB I L ITY :

MODES 1. 2. and 3.

ACTIONS REQUIRED ACTION COMPLETION TIME COND ION A.

TSP not within limits. A.1 Restore TSP to within hours 1 imits.

B.1 Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B.

Required Action and associated Completion A~ID Time not met.

B.2 Be in MODE 4.

12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.6.1 Verify the TSP baskets contain ~ 524 ft 3 of granular anhydrous trisodium phosphate.

In accordance with the Surveillance Frequency Contro'l Program SR 3.5,6.2 Verify that a sample from the TSP baskets provides adequate pH adjustment of borated water.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3,5,6 1 AMENDMENT NO.

. 188

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION ME D.

Required Action and 0.1 in MODE 3.

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

D.2 in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 3.6.2.1 NOTES-

1.

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

2.

Results shall be evaluated against acceptance criteria applicable to SR 3.6.1.1.

Perform required air lock leakage rate In accordance testing in accordance with the Containment with the Leakage Rate ng Program.

Containment Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be In accordance opened at a time.

with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.6. 4 AMEI~DMENT I~O.

, 188

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each required 42 inch purge valve is ed closed except for one purge valve in a penetration flow path while in Condition D of this LCD.

In accordance with the Surveillance Frequency Control Program SR 3.6.3.2 Verify each 8 inch purge valve is closed except when the 8 inch purge valves are open for pressure control. ALARA or air quality considerations for personnel entry.

or for Surveillances that require the valves be open.

In accordance with the Surveillance Frequency Control Program SR 3.6.3.3

NOTE-----

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

Verify each containment isolation manual valve and blind flange that is located outside containment and not locked. sealed or otherwise secured and is required to be closed during accident conditions is osed. except for containment isolation valves that are open under admlnistrative controls.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.6.3-5 AMENDMENT NO. ~, 188

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.4

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

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

Verify each containment isolation manual 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 SR 3.6.3.5 Verify the isolation time of each required automatic power operated containment isolation valve is within limits.

In accordance with the Inservice Testing Program SR 3.6.3.6 Perform leakage rate testing for required containment purge valves with resilient seals.

In accordance with the Surveillance Frequency Control Program AND Within 92 days after opening the valve SR 3.6.3.7 Verify each required 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 PALO VERDE UNITS 1.2.3 3.6.3-6 AI~ENDI~ENT NO. +00. 188

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3 6.4 Containment Pressure LCD 3.6.4 Containment pressure shall be ~ -0.3 psig and ~ +2.5 psig.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION A.

Containment pressure not within limits.

A.l REQUIRED ACTION Restore containment pressure to within 1imi ts.

COMPLETION TIME 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.

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

in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within 1imits.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.6.4 1 AMENDMENT NO 188

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be s 117°F.

APPLICABI LITY:

MODES 1. 2. 3. and 4.

ACTIONS CONDITION REQUIRED ACTION A

Containment average air temperature not with i n 1imit.

B.

Required Action and associated Completion Time not met.

A.1 B.1 AND B.2 Restore containment average air temperature to within 1imit.

Be in MODE 3.

Be in MODE 5.

8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months 6 hours 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.6.5.1 Verify containment average air temperature is within limit.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.6.5 1 AMENDMENT I~O. W. 188

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS SR 3.6.6.1 SURVEILLANCE Verify each containment spray manual, power operated. and automatic valve in the flow path that is not locked. sealed. or otherwise secured in position is in the correct position.

FREQUENCY In accordance wi th the Surveillance Frequency Control Program SR 3.6.6.2 Verify the containment spray piping is full of water to the 113 ft level in the containment spray header.

In accordance with the Survelllance Frequency Control Program SR 3.6.6.3 Verify each containment 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 3.6.6.4 Verify each automatic containment spray valve in the ow 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 Surve-Ill ance Frequency Control Program SR SR 3.6.6.5 3.6.6.6 Verify each containment spray pump starts automatically on an actual or simulated actuation signal.

Verify each spray nozzle is unobstructed.

In accordance with the Surveillance Frequency Control Program In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.6.6 2 AMEI~DMENT NO. W.188

ADVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ADV.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.4-2 AMENDMENT NO. W,188

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1 Verify each AFW manual. power operated. and automatic valve in each water flow path and in both steam supply ow paths to the steam 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

-NOTE Not required to be performed for the turbine driven AFW pump until hours after reaching 532°F in the RCS.

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

In accordance with the Inservice Test Program SR 3.7.5.3

- NOTES

1.

Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after reaching 532°F in the RCS.

2.

I~ot applicable in MODE 4 when steam generator is relied upon for heat removal.

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

In accordance wi th the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1,2,3 3.7.5 3 AMENDMENT NO.

, 188

AFW System 3,7,5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.7.5.4

NOTES I.

Not required to be performed for the turbine driven AFW pump until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after reaching 532°F in the RCS.

2.

Not applicable in MODE 4 when steam generator is relied upon for heat removal.

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

In accordance with the Surveillance Frequency Control Program SR 3.7.5.5 Verify the proper alignment of the required AFW flow paths by verifying ow from the condensate storage tank to steam generator.

Prior to entering MODE 2 whenever unit has been in MODE 5 or 6 for

> 30 days PALO VERDE UNITS 1.2.3 3.7.5-4 AtvlENDMENT NO,

. 188

CST 3.7.6 3.7 PLANT SYSTEMS 3.7.6 Condensate Storage Tank (CST)

LCO 3.7.6 The CST level shall be 2 29.5 ft APPLICABILITY:

MODES 1. 2. and 3.

MODE 4 when steam generator is relied upon for heat removal.

ACTIONS CONDITION REQUIRED ACTION CO~IPLETION TI~IE A.

1eve1 not withi n 1i mit.

A.1 AND A.2 Verify OPERABILITY of backup water supply.

Restore 1evel to withi n 1imit 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter 7 days B.

Required Action and associated Completion me not met.

B.1 AND Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B.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 FREQUENCY SR 3.7.6.1 Verify CST level is 2 29.5 ft.

In accordance with the Surveillance Frequency Control Program PALO UNITS 1.2.3 3.7.6 1 AMENDMENT NO. W.188

System 3.7.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.7.1 NOTE-------------------

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

Verify EW manual. power operated. and automatic valve in the flow path servicing safety ated equipment. that is not locked.

ed. or otherwise secured in position. is in the correct position.

In accordance with the Surveillance Frequency Control Program SR 3.7.7.2 Verify EW 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 Surveillance Frequency Control Program SR 3.7.7.3 Verify each EW pump starts automati ca lly on an actual or simulated actuation signal.

In accordance wi th the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.7.7-2 AMENDMENT NO.

188

ESPS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1

Notes Isolation of ESPS flow to individual components does not render ESPS inoperable.

Verify each manual and 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 3.7.8.2 Verify each ESPS pump starts automatically on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN

1. 2,3 3.7.8-2 AMENDMENT NO. W.188

UHS 3.7.9 3.7 PLANT SYSTEMS 3.7.9 Ultimate Heat Sink (UHS)

LCO 3.7.9 The UHS shall be OPERABLE.

APPLICABILITY:

MODES 1, 2, 3. and 4.

ACTIONS CONDITION REQU IRED ACTI ON COMPLETION ME A.

UHS inoperable.

A.l Be in MODE 3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify the usable water depth of each essential spray pond is ~ 12 feet.

In accordance with the Surveillance Frequency Control Program SR 3.7.9.2 Verify water temperature of each essential spray pond is ~ 89°F.

In accordance with the Surveillance Frequency Control Program PALO VERDE UN 1.2.3 3.7.9 1 AMENDMENT NO. ++7.188

EC 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Essential Chilled Water (EC) System LCD 3.7.10 Two EC trains shall OPERABLE.

APPLICABILITY:

MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One EC train inoperable.

A.1 Restore EC train to OPERABLE status.

hours B.

Required Action and associated Completion Time not met.

B.1 AND B.2 in MODE 3.

Be in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Verify each EC System manual, power operated, and automatic valve in the flow path, that is not locked, sealed. or otherwise secured in position, is in the correct position, In accordance with the Surveillance Frequency Control Program SR 3.7.10.2 Verify the proper actuation of each EC System component on an actual or simulated actuation signal, In accordance with the Surveillance Frequency Control Program PALO VERDE UN 1.2,3 3.7 10 1 AMENDMENT NO. ++7, 188

3.7.ll SURVEILLANCE REQUIREMENTS SR 3.7.ll.1 SURVEILLANCE Operate each CREFS train for

~ 15 minutes.

FREQUENCY In accordance with the Surveillance Frequency Control Program SR 3.7.ll. 2 Perform requiredCREFS lter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.11.3 Verify each CREFS train actuates on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3 7.ll. 4 Perform required CRE unfil air inleakage testing in accordance with the Control Room Envelope Habitability Program.

In accordance with the Control Room Envelope Habitabil ity Program.

PALO UNITS 1. 2.3 3.7.11 3 AMENDMENT NO. +/-++, 188

CREATCS 3.7.12 ACTIONS (continued)

COI~DITION REQUIRED ACTION COMPLETION TIME E.

Two CREATCS trains inoperable in MODE 5 or 6. or during movement of irradiated assemblies.

F.

Two CREATCS trains inoperable in MODE 1.

2. 3. or 4.

E.1 AND E.2 F.1 Suspend CORE AL TERATIONS.

Suspend movement of irradiated fuel assemblies.

Enter LCO 3.0.3.

Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.12.1 Veri fy each CREATCS tra"j n has capability remove the assumed heat load.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO UNITS 1. 2.3 3.7.12-2 AMENDMENT NO. +/-+/-+.188

ESF PREACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Engineered Safety Feature (ESF) Pump Room Exhaust Air Cleanup System (PREACS)

LCO 3.7.13 Two ESF PREACS trai ns shall be OPERABLE.

APPLICABILITY' MODES 1. 2. 3. and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

One PREACS train inoperable.

B.

Required Action and as ated Completion me not met.

A.1 B.1 AND B.2 Restore PREACS train to OPERABLE status.

n MODE 3.

Be in MODE 5.

7 days 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.13.1 Operate each ESF PREACS train for

~ 15 minutes FREQUENCY In accordance with the Surveillance Frequency Control Program (continued)

PALO UN

1. 2.3 3.7.13 1 AMENDMENT NO.

188

ESF PREACS 3.7.13 SURVEILLANCE REQUIREMENTS (continued)

SURVE I LLAI~CE FREQUENCY SR 3.7.13.2 Perform required ESF PREACS filter testing in accordance with the Ventilation Filter Testing Program (VFTP).

In accordance with the VFTP SR 3.7.13.3 Verify each F PREACS train actuates on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.7.13.4 Verify one PREACS train can maintain a measurable negative pressure relative to atmospheric pressure during operation at a flowrate of 6000 cfm +/-10%.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.13 2 AMENDMENT NO.

,188

Fuel Storage Pool Water Level 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Fuel Storage Pool Water Level LCO 3.7.14 The fuel storage pool water level shall be ~ 23 over the top of irradiated fuel assemblies seated in the storage racks.

APPLICABILITY:

During movement of irradiated fuel assemblies in the fuel storage pool.

ACTIONS CO~ICITION REQUIRED ACTION COMPLETION TIME A.

Fuel storage pool water level not within l-imit.

A.l

NOTE -----

LCO 3.0.3 is not applicable.

Suspend movement of i rradi ated fuel assemblies in fuel storage pool.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.14.1 Verify the fuel storage pool water level is

~ 23 ft above the top of irradiated fuel assemblies seated in the storage racks.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.7.14-1 AMENDMENT NO.

,188

Fuel Storage Pool Boron Concentration 3.7.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.7.15.1 Verify the fuel storage pool boron concentration is within limit.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.7.15-2 AME~IDMENT NO. W. 188

Secondary Specific Activity 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Secondary Specific Activity LCO 3.7.16 The specific activity of the secondary coolant shall be S 0.10 ~Ci/gm DOSE EQUIVALENT 1-131.

APPLICABILITY:

MODES 1. 2. 3. and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Specific activity not within limit.

A.1 AI~D A.2 Be in MODE 3.

Be in MODE 5.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours SURVEILLANCE REQUIREMENTS SURVEI LLANCE SR 3.7.16.1 Verify the specific activity of the secondary coolant is within limit.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.7.16-1 AMENDMENT NO. ill. 188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS FREQUENCY SURVEILLANCE SR 3.8.1.1 Verify correct breaker alignment and In accordance indicated power availability for each with the required offsite circuit.

Surve"i 11 ance Frequency Control Program SR 3.8.1. 2

~-~-~--

NOTES ------

1.

Performance of SR 3.8.1.7 satisfies this SR.

2.

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

3.

Amodified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer.

When modified start procedures are not used. the time.

voltage. and frequency tolerances of SR 3.8.1.7 must be met.

4.

The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error Verify each DG starts from standby In accordance condition and achieves steady state with the voltage 2 4000 V and ~ 4377.2 V. and Surveillance frequency 2 59.7 Hz and ~ 60.7 Hz.

Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.8.1-6 AMENDMENT NO. ~. 188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. 3 NOTES -

I.

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

2.

Momentary transients outside the load range do not invalidate this

3.

This Surveillance shall be conducted on only one DG at a time.

4.

This SR shall be preceded by and immediately follow without shutdown a successful performance of SR 3.8.1.2 or SR 3.8.1.7.

Verify each DG is synchronized and loaded, and operates for 2 60 minutes at a load 2 4950 kW and s 5500 kW.

In accordance with the Surveillance Frequency Control Program SR 3.8.1. 4 Verify each day tank contains 2 550 gal of fuel oil (minimum level of 2.75 feet).

In accordance wi th the Surveillance Frequency Control Program SR 3,8.1. 5 Check for and remove accumulated water from each day tank.

In accordance with the Surveillance Frequency Control Program SR 3.8,1. 6 Verify the fuel oil transfer system operates to automatically transfer fuel oil from the storage tank to the day tank, In accordance wi th the Survelllance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.8.1-7 AMENDMENT NO. ill, 188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

FREQUENCY SURVEILLANCE SR 3.8.l. 7

NOTE----

1.

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

2.

The steady voltage and frequency limits are analyzed values and have not been adjusted for instrument error.

Verify each DG starts from standby In accordance condition and achieves with the

a.

In ~ 10 seconds. voltage 2 3740 Vand Surveillance frequency 2 58.8 Hz; and Frequency

b.

Steady state voltage 2 4000 V and Control Program

~ 4377.2 V. and frequency 2 59.7 and ~ 60. 7 Hz.

SR 3.8.l. 8

NOTE --

This Surveillance shall not normally be performed in MODE 1 or 2.

However. this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify manual transfer of AC power sources In accordance from the normal ite circuit to each with the alternate offsi circuit.

Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.8.1-8 AMENDMENT NO. +/-e6.188

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1. 9

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

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4. However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each DG rejects a load greater than or equal to i associated single largest post-aCCident load, and:

a.

Following load rejection, the frequency is ~ 64.5 Hz:

In accordance with the Surveillance Frequency Control Program

b.

Within 3 seconds following load rejection, the voltage is ~ 3740 V and ~ 4580 V; and

c.

Within 3 seconds following load rej on, the frequency is

~ 58.8 and ~ 61.2 Hz.

SR 3.8.1.10

--NOTE--------

If performed with the DG synchronized with offsite power. it shall be performed at a power factor of ~ 0.89.

However. if grid conditions do not permit, the power factor limit is not required to be met.

Under this condition the power factor shall be maintained as ose to the limit as practicable.

Verify each DG does not trip. and voltage is maintained ~ 6200 Vduring and following a load rejection of ~ 4950 kW and

5500 kW.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.8.1-9 AMEI~DMENT NO. W.188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLAI~CE SR 3.8.1.11

NOTE

1.

All DG starts may preceded by an engine prelube period.

2.

This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4.

However. portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3.

Momentary voltage and frequency transients induced by load changes do not invalidate this test.

4.

The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.

Verify on an actual or simul loss of offsite power signal:

a.

De-energization of emergency buses:

b.

Load shedding from emergency buses:

c.

DG auto-starts and:

1.

energizes permanently connected loads in s 10 seconds.

2.

energizes auto-connected emergency loads through automatic load sequencer.

3.

maintains steady state voltage

~ 4000 V and s 4377.2 V.

4.

maintains steady state frequency

~ 59.7 Hz and s 60.7 Hz. and

5.

supplies permanently connected and auto-connected emergency loads for ~ 5 minutes.

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

PALO VERDE UNITS 1.2.3 3.8.1-10 AMENDMENT NO. ~. 188

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.8.1.12 SURVEILLANCE NOTES--------

1.

All DG starts may be preceded by an engine prelube period.

2.

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4.

However. portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

3.

The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.

Verify on an actual or simulated Engineered Safety Feature (

) actuation signal (without a loss of offsite power) each DG auto-starts and:

a.

In s 10 seconds. achieves voltage

~ 3740 V and frequency ~ 58.8 Hz:

b.

Achieves steady state voltage ~ 4000 and s 4377.2 V and frequency ~ 59.7 Hz and s 60.7 Hz:

c.

Operates for ~ 5 minutes on standby (running unloaded);

d.

Permanently connected loads remain energized from the offsite power system: and

e.

Emergency loads are energized (auto connected through the automatic load sequencer) from the offsi power system.

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

PALO VERDE UNITS 1.2.3 3.8.1 11 AMENDMENT NO. ~, 188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.l.13 Verify each DG automatic trip is bypassed on actual or simulated loss of voltage signal on the emergency bus concurrent with an actual or simulated ESF actuation signal except:

a.

Engi ne overs peed ;

b.

Generator differential current;

c.

Engine low lube oil pressure; and

d.

Manual emergency stop trip.

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

PALO UN 1.2.3 3.8.1-12 A~IENDMENT NO. ~. 188

3.8.1 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVE ILLAI~CE SR 3.8.1.14

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

1.

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

2.

If performed with the DG synchronized with offsite power. it shall be performed at a power factor of ~ 0.89.

However. if grid conditions do not permit. the power factor limit is not required to be met.

Under this condition the power factor shall be maintained as close to the limit as practicable.

3.

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

4.

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

Verify each DG operates for ~ 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s:

a.

For ~ 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months 1oaded ~ 4950 kW and

~ 5500 kW; and

b.

For the remai ni ng hours

(~ 2) of the test loaded ~ 5775 kW and ~ 6050 kW.

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

PALO VERDE UNITS 1.2.3 3.8.1-13 AMENDMENT NO. w.. 188

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.15

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

1.

This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG. loaded 2 4950 kW and

~ 5500 kW. has operated 2 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or until temperatures have stabilized.

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

2.

All DG starts may be preceded by an engine prelube period.

3, The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.

Verify each DG starts and achieves

a.

In ~ 10 seconds, voltage 2 3740 Vand frequency 2 58.8 Hz: and

b.

Steady state voltage 2 4000 V and

~ 4377.2 V. and frequency 2 59.7 Hz and ~ 60.7 Hz, In accordance with the Survelllance Frequency Control Program SR 3.8.1.16 NOTE- ---------------

This Surveillance shall not normally be performed in MODE 1, 2, 3, or 4,

However, this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced, Verify each DG:

a, Synchroni zes with offsite power source while loaded with emergency loads upon a Simulated restoration of offsite power:

In accordance with the Surveillance Frequency Control Program

b.

Transfers loads to offsi te power source: and c,

Returns to ready-to-load operation.

(cont'j nued)

PALO VERDE UNITS 1,2.3 3.8.1-14 AMENDMENT NO,

, 188

AC Sources Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3 8.1.17 NOTE This Surveillance shall not normally be performed in MODE I, 2, 3, or 4.

However.

portions of the Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is ma'j ntai ned or enhanced.

Verify. with a DG operating in test mode and connected its bus. an actual or simulated actuation signal overrides the test mode by:

a,

b.

Returning DG to operation; and Automatically load from offsi ready-to-load izing the emergency power.

In accordance with the Surveillance Frequency Control Program SR 3.8.1.18 NOTE This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4. However.

this Surveillance may be performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify interval between each sequenced load block is within +/- 1 second of design interval for each automatic load sequencer.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3 8.1 AMENDMENT NO. +/-&e. 188

AC Sources Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.1.19 NOTES-----------------

1.

2.

3.

All DG starts may be preceded by an engine prelube period.

This Surveillance shall not normally be performed in MODE 1. 2. 3. or 4.

However. portions of the Surveillance may performed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

The steady state voltage and frequency limi are analyzed values and have not been adjusted for instrument error.

Verify on an actual or simulated loss of offsite power signal in conjunction with an actual or simulated ESF actuation signal:

a.

De-energization of emergency buses:

b.

Load shedding from emergency buses:

c.

DG auto-starts from standby condition and:

1.

energizes permanently connected loads in ~ 10 seconds.

2 energizes auto-connected emergency loads through load sequencer.

3.

achieves steady state voltage

~ 4000 V and ~ 4377.2 V.

4.

achieves steady state frequency

~ 59.7 Hz and ~ 60.7 Hz. and

5.

supplies permanently connected and auto connected emergency loads for ~ 5 minutes.

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

AMENDMENT NO. +ee.188 PALO VERDE UNITS 1.2.3

3.8.1 AC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.1.20

NOTES-1, All DG starts may be preceded by an engine prelube period,

2.

The steady state voltage and frequency limits are analyzed values and have not been adjusted for instrument error.

Verify. when started simultaneously. each DG achieves

a.

In:::; 10 seconds, voltage ~ 3740 V and frequency ~ 58.8 Hz: and

b.

Steady state voltage ~

V and

4377.2 V. and frequency ~ 59.7 Hz and: ::; 60.7 Hz.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3,8,1-17 AMENDMENT NO

~. 188

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains

~ 80% indicated fuel level.

In accordance with the Surveillance Frequency Control Program SR 3.8.3.2 Verify lubricating oil inventory is

~ 2.5 inches visible in the sightglass.

In accordance with the Surveillance Frequency I Control Program SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are tested in accordance with, and maintained within the limits of.

the Dies Fuel Oil Testing Program.

In accordance with the Di Fuel Oil Testing Program SR 3.8.3.4 Verify each DG starting air receiver pressure is ~ 230 psig.

In accordance with the Surveillance Frequency Control Program SR 3.8.3.5 Check for and remove accumulated water from each fuel oil storage tank.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.8.3-3 AMENDMENT NO. AA.188

DC Sources - Operating 3.8.4 SURVEILLANCE REqUIREMENTS SURVEILLANCE FREqUENCY SR 3.8.4.1 Verify battery terminal voltage is ~

on float charge.

V In accordance with the Surveillance Frequency Control Program SR 3.8.4.2 Verify no visible corrosion at battery terminals and connectors.

OR Verify battery connection resistance is

~ 150E-6 ohms for inter-cell connections.

~ 150E-6 ohms for inter rack connections.

~ 150E-6 ohms for inter tier connections.

and ~ 150E-6 ohms for terminal connections.

In accordance with the Surveillance Frequency Control Program SR 3.8.4.3 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 SR 3.8.4.4 Remove visible terminal corrosion and verify battery cell to cell and terminal connections are clean. and are coated with anti-corrosion material.

In accordance with the Surveillance Frequency Control Program SR 3.8.4.5 Verify battery connection resistance is

~ 150E-6 ohms for inter-cell connections.

~ 150E-6 ohms for inter-rack connections.

~ 150E-6 ohms for inter tier connections.

and ~ 150E-6 ohms for terminal connections.

In accordance with the Surveillance Frequency Control Program (continued)

PALO VERDE UNITS 1.2.3 3.8.4-2 AMENDMENT NO.

. 188

3.8.4 DC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.6

NOTE This Surveillance shall not normally be performed in MODE 1, 2, 3. or 4 on the charger credited for OPERABILITY.

However, portions of the Surveillance may be rformed to reestablish OPERABILITY provided an assessment determines the safety of the plant is maintained or enhanced.

Verify each battery charger supplies

~ 400 amps for Batteries A and Band

~ 300 amps for Batteries C and D

~ 1 V for ~ 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

In accordance with the Surveillance Frequency Control Program SR 3.8.4.7

NOTES-I.

The battery performance di scharge test or the modified performance discharge test in SR 3.8,4.8 may be performed in lieu of the service test in SR 3.8.4.7.

2.

This Surveillance shall not be performed in MODE 1, 2, 3, or 4.

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

In accordance with the Survelllance Frequency Control Program (continued)

PALO VERDE UNITS 1,2,3 3.8.4-3 AMENDMENT NO. +/-ee,188

3.8.4 DC Sources - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE SR 3.8.4.8

NOTE ---- ------

This Surveillance shall not be performed in MODE 1. 2, 3. or 4.

Verify battery capacity is ~ 80% of the manufacturer's rating when subjected to a performance discharge test or a modified performance discharge test.

FREQUENCY In accordance with the Surveillance Frequency Control Program 12 months when battery shows degradation or has reached 85%

of the expected 1i with capacity

< 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected li with capacity

~ 100% of manufacturer's rating PALO VERDE UNITS 1.2.3 3.8.4-4 A~IENDMENT NO.

188

Battery Cell Parameters 3.8.6 ACTIONS (continued)

COI~DITION REQUIRED ACTION COrvIPLETIOI~ TIME B.

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

OR One or more batteries with average electrolyte temperature of the representative cells

< 60°F.

OR One or more batteries with one or more battery cell parameters not within Category C limits.

B.1 Declare associated battery inoperable.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.6.1 Verify battery cell parameters meet Table 3.8.6-1 Category A limits.

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

PALO VERDE UNITS 1.2.3 3.8.6-2 AMENDMENT NO. W, 188

Battery Cell Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.2 Verify battery cell parameters meet Table 3.8.6 1 Category B limits.

In accordance with the Surveillance Frequency Control Program AND Once withi n 7 days after battery discharge

< 105 V AND Once within 7 days after battery overcharge

> 150 V SR 3.8.6.3 Verify average electrolyte temperature of representative cells is 260°F.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.8.6 3 AMENDMENT NO. W.188

Inverters - Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

Required Action and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months B.1 Be in MODE 3.

associated Compl Time not met.

on AND B.2 Be in MODE 5.

36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.7.1 Veri fy correct 'i nverter voltage. frequency.

and alignment to required AC vital instrument buses.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.8.7-2 AMENDMENT NO. +++. 188

Inverters Shutdown 3,8.8 ACTIONS COND ION REQUIRED ACTION COMPLETION TIME A, (conti nued)

A,2 4 Initiate action to restore required inverters to OPERABLE

status, Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8,8.1 Verify correct inverter voltage. frequency, and alignments to required AC vital instrument buses.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNI 1.2.3 3.8.8-2 AMENDMENT NO, W.188

Distribution Systems - Operating 3.8.9 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.

One DC electrical power distribution subsystems inoperable.

C.1 Restore DC electrical power distribution subsystem to OPERABLE status.

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of fail ure to meet LCO D.

Required Action and associated Completion Time not met.

E.

Two or more inoperable distribution subsystems that result in a loss of safety function.

0.1 AND 0.2 E.1 Be in MODE 3.

Be in MODE 5.

Enter LCD 3.0.3.

6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months 36 hours Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.9.1 Verify correct breaker alignments and voltage to required AC. DC. and AC vital instrument bus electrical power distribution subsystems.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.8.9-2 AMENDI~ENT NO.

. 188

Distribution Systems - Shutdown 3.8.10 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

(continued)

A.2.4 Initiate actions to restore required AC, DC, and AC vital instrument bus electrical power distribution subsystems to OPERABLE status.

AND Immediately A.2.5 Declare associated required shutdown cooling subsystem(s) inoperable and not in operation.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.8.10.1 Verify correct breaker alignments and voltage to required AC, DC, and AC vital instrument bus electrical power distribution subsystems.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.8.10-2 AMENDMENT NO. ++/-+,188

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.

A.l AND A.2 AND A,3 Suspend CORE ALTERATIONS.

Suspend positive reactivity additions, Initiate action to restore boron concentration to withi n 1imit, Immediately Immediately Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.1.1 Verify boron concentration is within the limit specified in the COLR, In accordance with the Surveillance Frequency Contra1 Program PALO VERDE UNITS 1,2,3 3.9.1 1 AMENDMENT NO, W, 1BB

Nuclear Instrumentation 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE I

FREQUENCY SR 3.9.2.1 Perform CHANNEL CHECK.

In accordance with the Surveillance Frequency Control Program SR 3.9.2.2 NOTE Neutron detectors are excluded from CHANNEL CALI BRATI ON.

Perform CHANNEL CALIBRATION.

In accordance wi th the Surveillance Frequency Control Program PALO VERDE UNI 1.2.3 3 9.2-2 AMENDMENT NO. t+/-+.188

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 containment purge and exhaust valve actuates to the isolation position on an actual or simulated actuation signal.

In accordance with the Surveillance Frequency Control Program SR 3.9.3.3 Verify the capabllity to close the equipment hatch. if open In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.9.3-2 AMENDMENT NO. +/-4J.188

SDC and Coolant Circulation -High Water 3.9.4 ACTIONS CONOI ON 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 SR 3.9.4.1 Verify one SOC loop is operable and in operation.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.4-2 AMENDMENT NO. ++7,188

SOC and Coolant Circulation Low Water Level 3.9.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.

No SOC loop OPERABLE or in operation.

B.l AND B.2 AND B.3 Suspend operations involving a reduction in reactor coolant boron concentration.

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

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

Immediately Immediately 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 required SOC loops are OPERABLE and one SOC 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 SOC pump that is not in operation.

In accordance with the Surveillance Frequency Control Program PALO VERDE UNI 1.2.3 AMENDMENT NO.

.188

Refueling Water Level-Fuel Assemblies 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Refueling Water Level Fuel Assemblies LCO 3.9.6 Refueling water level shall be maintained ~ 23 ft above the top of the reactor vessel flange.

APPLICABILITY:

During movement of fuel assemblies within containment when either the fuel assemblies being moved or the fuel assemblies seated within the reactor vessel are i rradi ated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TI~IE A.

Refueling water level not within limit.

A.l Suspend movement of fuel assemblies within containment.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.6.1 Verify refueling water level is ~ 23 ft above the top of reactor vessel flange.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1,2,3 3.9.6-1 AMENDMENT NO. +/-+/-+.188

Refueling Water Level-CEAs 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Water Level-CEAs LCO 3.9.7 Refueling water level shall be maintained ~ 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.

APPLICABILITY:

During movement of CEAs within the reactor vessel. when the fuel assemblies seated within the reactor vessel are irradiated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A.

Refueling water level not within limit.

A.l Suspend movement of CEAs within the reactor vessel.

Immediately SURVEILLANCE REQUIREMENTS SURVEILLANCE SR 3.9.7.1 Verify refueling water level is ~ 23 ft above the top of irradiated fuel assemblies seated within the reactor vessel.

FREQUENCY In accordance with the Surveillance Frequency Control Program PALO VERDE UNITS 1.2.3 3.9 7-1 AMENDMENT NO. +/-+/-+. 188

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.17 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented ensure that CRE Habitability is maintained such that. with an OPERABLE Control Room sential ltration System (CREFS), CRE occupants can control the reactor safely under normal conditions and maintain it in a safe condition following a radiological event. hazardous chemical release. or a smoke challenge.

The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem whole body or its equivalent to any part the body for the duration of the accident.

The program shall include the following elements:

a.

The definition of the CRE and the CRE boundary.

b.

Requirements for maintaining the CRE boundary in its design condition including configuration control and preventive maintenance.

c.

Requirements for (i) determining the unfiltered air inleakage past the CRE boundary in accordance with the testing methods and the Frequencies specified in Sections C.l and C.2 of Regulatory Guide l.197. "Determining Control Room Envelope Integrity at Nuclear Power Reactors," Revision D. May 2003.

and (ii) assessing CRE habitability at the Frequencies specified in Sections C.l and C.2 of Regulatory Guide 1.197.

Revision O.

d.

Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operation of one train of the CREFS. operating at the flow rate requ'ired by the VFTP, at a Frequency of 18 months on a STAGGERED TEST B.ASIS.

The resul shall be trended and used as part of the periodic assessment of the CRE boundary.

e.

The quantitative limits on unfiltered air inleakage into the shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c.

The unflltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences.

f.

The provisions of SR 3.0.2 are applicable to the Frequencies for assessing CRE habitability. determining CRE unfiltered inleakage. and measuring CRE pressure and assessing the CRE boundary as required by paragraphs c and d, respectively.

(continued)

PALO VERDE UNITS 1,2.3 5.5-17 AMENDMENT NO..J:++/-.188

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.18 Surveillance Frequency Control Program This program provides controls for Surveillance Frequencies.

The program shall ensure that Surveillance Requirements specified in.

the Technical Specifications are performed intervals sufficient to assure the associated miting 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 of the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Ri sk Informed Method for Control of Survei 11 ance 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.

PALO VERDE UNITS 1,2.3 5.5-18 AMENDMENT NO. 188

UNITED STATES NUCLEAR REGULATORY COMMISSION WASHINGTON, D.C. 20555*0001 SAFETY EVALUATION BY THE OFFICE OF NUCLEAR REACTOR REGULATION RELATED TO AMENDMENT NOS. 188, 188. AND 188 TO RENEWED FACILITY OPERATING LICENSE NOS. NPF-41, NPF-51, AND NPF-74 ARIZONA PUBLIC SERVICE COMPANY, ET AL.

PALO VERDE NUCLEAR GENERATING STATION. UNITS 1.2, AND 3 DOCKET NOS. STN 50-528. STN 50-529, AND STN 50-530

1.0 INTRODUCTION

By letter dated March 31. 2011 (Reference 1), as supplemented by letter dated August 12, 2011 (Reference 2), Arizona Public Service Company (the licensee) proposed changes to the technical specifications (TSs) for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2 and 3. The supplemental letter dated August 12, 2011, provided additional information that clarified the application. did not change the scope of the application as originally noticed. and did not change the U.S. Nuclear Regulatory Commission (NRC) staff's original proposed no significant hazards consideration determination as published in the Federal Register on June 14, 2011 (76 FR 34765).

The amendments would revise the TSs by relocating specific surveillance frequencies to a licensee-controlled program in accordance with Nuclear Energy Institute (NEI) 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5b, Risk-Informed Method for Control of Surveillance Frequencies" (Reference 3). The requested change is the adoption of NRC-approved Technical Specification Task Force (TSTF-425). Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b" (Reference 4). When implemented. TSTF-425 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:

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");

- 2 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% RTP [rated thermal power]"); 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 TS Section 5 as TS 5.5.18, "Surveillance Frequency Control Program." 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. Some surveillance requirements Bases do not contain a discussion of the frequency. In these cases, the Bases describing the current frequency were added to maintain consistency with the Bases for similar surveillances. These instances are noted in the markup along with the source of the text. The proposed licensee changes to the Administrative Controls of the TS to incorporate the SFCP include a specific reference to NEI 04-10, Revision 1 (Reference 3), as the basis for making any changes to the surveillance frequencies once they are relocated out of the TSs.

In a letter dated September 19, 2007 (Reference 5), the Nuclear Regulatory Commission (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. The staff also approved the safety evaluation providing the basis for NRC acceptance of NEI 04-10.

2.0 REGULATORY EVALUATION

In the "Final Policy Statement: Technical Specifications for Nuclear Power Plants," published in the Federal Register on July 22,1993 (58 FR 39132), the NRC addressed the use of Probabilistic Safety Analysis (PSA, currently referred to as Probabilistic Risk Assessment or PRA) in the Standard Technical Specifications (STS). In discussing the use of PSA in Nuclear Power Plant Technical Specifications, the Commission wrote, 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....

- 3 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. 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 "Final Policy Statement: Use of Probabilistic Risk Assessment in Nuclear Regulatory Activities," published in the Federal Register on August 16,1995 (60 FR 42622). The Commission, in discussing the deterministic and probabilistic approach to regulation and the Commission's extension and enhancement of traditional regulation, wrote, 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.

The Commission further stated that:

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.

The Commission provided its new policy, stating:

Although PRA methods and information have thus far been used successfully in nuclear regulatory activities, there have been concerns that PRA methods are 1 This bracketed text is in the Federal Register.

-4 not consistently applied throughout the agency, that sufficient agency PRAlstatistics expertise is not available, and that the Commission is not deriving full benefit from the large agency and industry investment in the developed risk assessment methods. 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.

Implementation of the policy statement will improve the regulatory process in three areas: Foremost, thro~gh safety decision making enhanced by the use of PRA insights; through more efficient use of agency resources; and through a reduction in unnecessary burdens on licensees.

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 guides, license commitments, and staff practices. Where appropriate, PRA should be used to support the proposal for additional regulatory requirements in accordance with

[Title 10 of the Code of Federal Regulations (1 0 CFR)] 50.109 (Backfit Rule). Appropriate procedures for including PRA in the process for changing regulatory requirements 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.

- 5 In 10 CFR 50.36, 'Technical specifications," the NRC established its regulatory requirements related to the content of 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.

The regulations in 10 CFR 50.36(c)(3}, "Surveillance requirements," state that, 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 SFCP 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, including qualitative considerations, results of risk analyses, sensitivity studies and any bounding analyses, and recommended monitoring of structures, systems, and components (SSCs), and 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 Program.

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

The licensee's SFCP ensures 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" (the Maintenance Rule), and Appendix B, "Quality Assurance Criteria for Nuclear Power Plants and Fuel Reprocessing Plants," to 10 CFR Part 50 (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 requires monitoring the performance of SSCs for which surveillance frequencies are decreased to assure reduced testing does not adversely impact the SSCs. These requirements, and the monitoring required by NEI 04-10, ensure that surveillance frequencies are sufficient to assure that the requirements of 10 CFR 50.36 are satisfied and that any performance deficiencies will be identified and appropriate corrective actions taken.

-6 NRC Regulatory Guide (RG) 1.174, Revision 1, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant-Specific Changes to the Licensing Basis,"

November 2002 (Reference 6), describes a risk-informed approach, acceptable to the NRC, for assessing the nature and impact of proposed permanent licensing-basis changes by considering engineering issues and applying risk insights. This regulatory guide also provides risk acceptance guidelines for evaluating the results of such evaluations.

NRC RG 1.177, "An Approach for Plant-Specific, Risk-Informed Decisionmaking: Technical Specifications," August 1998 (Reference 7), describes an acceptable risk-informed approach specifically for assessing proposed permanent TS changes.

NRC RG 1.200, Revision 1, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," January 2007 (Reference 8), describes an acceptable approach for determining whether the quality of the PRA, in total or the parts that are used to support an application, is sufficient to provide confidence in the results, such that the PRA can be used in regulatory decision making for light-water reactors.

3.0 TECHNICAL EVALUATION

3.1 Proposed Changes The licensee's adoption of TSTF-425, Revision 3, for PVNGS Units 1, 2, and 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 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, Revision 2 (Reference 8). In accordance with NEI 04--10, 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, Revision 1 (Reference 6), and RG 1.177 (Reference 7) in support of changes to surveillance test intervals.

The licensee proposed to adopt TSTF-425, Revision 3, with two optional changes and variations. First, the definition of STAGGERED TEST BASIS is being retained because it is referenced in a part of the TSs that is not included in this amendment. Second, the licensee is adopting the changes to optional insert #2 as discussed in an NRC letter to the TSTF dated April 14.2010, regarding the TS Bases (Reference 9).

- 7 In References 1 and 2, the licensee proposed to remove the following surveillance frequencies and relocate them to the licensee-controlled program2:

3.1.1.1 3.1.2.1 3.1.2.2 3.1.2.3 3.1.3.1*

3.1.5.1 3.1.5.2 3.1.5.3 3.1.5.4 3.1.6.1 3.1.7.1 3.1.7.2 3.1.7.3 3.1.8.1 3.1.9.1 3.1.9.3 3.1.10.1 3.1.10.2 3.2.1.1 3.2.1.2 3.2.2.1*

3.2.3.1 3.2.3.2 3.2.3.3 3.2.4.1 3.2.4.2 3.2.5.1 3.3.1.1 3.3.1.2 3.3.1.3 3.3.1.4 3.3.1.5 3.3.1.6 3.3.1.7 3.3.1.8 3.3.1.9 3.3.1.10 3.3.1.13 3.3.2.1 3.3.2.2 3.3.2.4 3.3.2.5 3.3.3.1 3.3.3.3 3.3.3.4 3.3.3.5 3.3.4.1 3.3.4.2 3.3.4.3 3.3.5.1 3.3.5.2 3.3.5.3 3.3.5.4 3.3.6.1 3.3.6.2 3.3.7.1 3.3.7.2 3.3.7.3 3.3.8.1 3.3.8.2 3.3.8.3 3.3.8.4 3.3.8.5 3.3.9.1 3.3.9.2 3.3.9.3 3.3.9.4 3.3.9.5 3.3.9.6 3.3.10.1 3.3.10.2 3.3.11.1 3.3.11.2 3.3.11.3 3.3.12.1 3.3.12.2 3.3.12.3 3.4.1.1 3.4.1.2 3.4.1.3 3.4.2.1 3.4.3.1 3.4.4.1 3.4.5.1 3.4.5.2 3.4.5.3 3.4.6.1 3.4.6.2 3.4.6.3 3.4.7.1 3.4.7.2 3.4.7.3 3.4.8.1 3.4.8.2 3.4.9.1 3.4.9.2 3.4.11.2 3.4.12.1 3.4.12.2 3.4.13.1 3.4.13.2 3.4.14.1 3.4.14.2 3.4.15.1*

3.4.15.2 3.4.16.1 3.4.16.2 3.4.16.3 3.4.16.4 3.4.17.1 3.4.17.2*

3.4.17.3 3.5.1.1 3.5.1.2 3.5.1.3 3.5.1.4*

3.5.1.5 3.5.2.1 3.5.2.2 3.5.2.3 3.5.2.4*

3.5.2.5 3.5.3.1 3.5.3.2 3.5.3.4 3.5.3.5 3.5.3.6 3.5.3.7 3.5.3.8 3.5.5.1 3.5.5.2 3.5.5.3 3.5.6.1 3.5.6.2 3.6.2.2 3.6.3.1 3.6.3.2 3.6.3.3 3.6.3.6 3.6.3.7 3.6.4.1 3.6.5.1 3.6.6.1 3.6.6.2 3.6.6.4 3.6.6.5 3.6.6.6 3.7.4.1 3.7.5.1 3.7.5.3 3.7.5.4 3.7.6.1 3.7.7.1 3.7.7.2 3.7.7.3 3.7.8.1 3.7.8.2 3.7.9.1 3.7.9.2 3.7.10.1 3.7.10.2 3.7.11.1 3.7.11.3 3.7.12.1 3.7.13.1 3.7.13.3 3.7.13.4 3.7.14.1 3.7.15.1 3.7.16.1 3.8.1.1 3.8.1.2 3.8.1.3 3.8.1.4 3.8.1.5 3.8.1.6 3.8.1.7 3.8.1.8 3.8.1.9 3.8.1.10 3.8.1.11 3.8.1.12 3.8.1.13 3.8.1.14 3.8.1.15 3.8.1.16 3.8.1.17 3.8.1.18 3.8.1.19 3.8.1.20 3.8.3.1 3.8.3.2 3.8.3.4 3.8.3.5 3.8.4.1 3.8.4.2 3.8.4.3 3.8.4.4 3.8.4.5 3.8.4.6 3.8.4.7 3.8.4.8*

3.8.6.1 3.8.6.2*

3.8.6.3 3.8.7.1 3.8.8.1 3.8.9.1 3.8.10.1 3.9.1.1 3.9.2.1 3.9.2.2 3.9.3.1 3.9.3.2 3.9.3.3 3.9.4.1 3.9.5.1 3.9.5.2 3.9.6.1 3.9.7.1 5.5.17 In addition, the licensee proposed to modify the Administrative Controls section of the TSs by adding new TS 5.5.18, which would state, 5.5.18 Surveillance Frequency 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.

Those marked with an asterisk (*) are to be removed and replaced in part.

2

- 8

b.

Changes to the Frequencies listed in the Surveillance Frequency Control Program shall be made in accordance with NEI 04-10, "Risk-Informed 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.

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

3.2.1 The Proposed Change Meets Current Regulations The regulations in 10 CFR 50.36(c)(3) require that TSs will include surveillance requirements.

NEI 04-10 provides guidance for relocating the surveillance frequencies from the TSs to a licensee-controlled program by providing an NRC-approved methodology for control of the surveillance frequencies. The surveillances themselves would remain in the TSs, as required by 10 CFR 50.36(c)(3).

This change is consistent with other NRC-approved TS changes in which the surveillance frequencies are relocated to licensee-controlled documents, such as surveillances performed in accordance with the In-service Testing Program or the Primary Containment Leakage Rate Testing Program. Thus, this proposed change meets the first key safety principle of RG 1.177 by complying with current regulations.

3.2.2 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.

- 9 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 for any changes to surveillance frequencies within the SFCP. NEI 04-10 uses both the core damage frequency (CD F) 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 an 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.

3.2.3 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 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 described in the plant licensing basis (including the Updated Final Safety Analysis Report and bases to TS), 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.

3.2.4 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 evaluating the risk impact of proposed changes to surveillance frequencies. This requires the identification of the risk contribution from impacted surveillances, determination of the risk impact from the change to the proposed surveillance

-10 frequency, and performance of sensitivity and uncertainty evaluations. TSTF-425, Revision 3, requires application of NEI 04-10 in the SFCP. NEI 04-10 satisfies the intent of RG 1.177 requirements for evaluating the change in risk, and for assuring that such changes are small.

3.2.4.1 Quality of the PRA The quality of the PVNGS Units 1, 2, and 3 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, Revision 2, to address the technical adequacy of the PVNGS Units 1, 2, and 3 PRA. RG 1.200, Revision 2, is NRC's developed regulatory guidance, which endorses with comments and qualifications the use of the American Society of Mechanical Engineers (ASME) RA-Sa-2009, "Addenda to ASME RA-S-2008 Standard for Level1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications" (Reference 10), NEI 00-02, Revision 1, "PRA Peer Review Process Guidelines," May 2006 (Reference 11), and NEI 05-04, Revision 2, "Process for Performing Follow-on PRA Peer Reviews Using the ASME PRA Standard," August 2006 (Reference 12). The licensee has performed an assessment of the PRA models used to support the SFCP using the guidance 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-Sa-2009 was applied as the standard, and any identified deficiencies to those requirements are assessed further to determine any impacts to proposed decreases to surveillance frequencies, including by the use of sensitivity studies where appropriate.

The Combustion Engineering Owners Group (CEOG) conducted a peer review of the Internal Events PRA model in 1999. The licensee performed a self-assessment on the model in 2010 to assess gaps between the CEOG peer review results and the ASME RA-S-2008 Standard. In addition, Westinghouse performed a peer review of the Internal Flood PRA model in 2010. The licensee provided the capability category II Supporting Requirements (SRs) in its submittal which were determined through its gap analysis not to be met (Le. open gap items). The submittal also included peer review facts and observations (F&Os) for the Internal Events PRA model and their evaluations. The licensee considered the Internal Flood findings of not meeting capability category II as resolved.

The NRC staff reviewed the licensee's evaluation of the submitted open gap SRs. These open gap items were provided in Table 2, "RG 1.200 Category II Supporting Requirements Not Met Evaluation," and linked to peer review F&Os in Table 1, "Open CEOG Internal Event PRA Peer Review F&Os," both of which were provided in the licensee's letter dated March 31, 2011. The NRC staff assessed these open gap items to ensure the deficiency in not meeting capability category II may be addressed and dis positioned for each surveillance frequency evaluation per the NEI 04-10 methodology. The NRC staff's assessment is provided below.

SR IE-A8 capability category II is to "interview plant personnel (e.g., operations, maintenance, engineering, safety analysis) to determine if potential initiating events have been overlooked." The peer review was not able to conclude that interviews were documented or conducted. The licensee noted in its evaluation

- 11 that plant-specific initiators were identified with engineering and operator input, and that plant experience is reviewed to periodically update initiating event frequencies. Thus, the licensee has provided information which shows that interviews were conducted for identifying initiating events; however, the licensee will update documentation for each system. This open gap item can be addressed for surveillance frequency evaluations since NEI 04-10 guidance requires an evaluation of whether or not a system, structure, or component failure can contribute to an initiating event.

SR SY-A4 capability category II is to "perform plant walkdowns and interviews with knowledgeable plant personnel (e.g., engineering, plant operations, etc.) to confirm that the systems analysis correctly reflects the as-built, as-operated plant." The peer review found that "walkdowns and interviews were either not conducted or not documented." By letter dated August 12,2011 (Reference 2),

in response to the NRC staff's request for additional information dated July 7, 2011 (Reference 13), on the licensee's evaluation, the licensee noted that walkdowns of the PRA modeled systems were performed in 2010 and 2011 for the Internal Flooding PRA development and the Internal Fire PRA upgrade, as well as other walkdowns in previous years. In addition, flow diversion analyses were performed for PRA modeled systems to address F&O SY-03. The licensee's engineers have also reviewed components in the PRA model. In addition, the licensee noted that changes to procedures, drawings, and other relevant documents are tracked and reviewed. The NRC staff concludes that these activities support more than capability category I for SY -A4 since the recent walkdowns, analyses, and reviews clearly involve Internal Event PRA modeling; however, the licensee noted in its evaluation that documentation for each system is to be updated. NEI 04-10 guidance addresses this open gap item since it ensures that the as-built, as-operated plant will be considered for surveillance frequency evaluations using the Internal Events PRA model through its endorsement of applicable regulatory guides.

SR SY-C1 is to "document the systems analysis in a manner that facilitates PRA applications, upgrades, and peer review." The licensee evaluated the peer review comments on this SR, including F&Os SY-03, SY-05, and DE-10. The peer review noted that "system studies have not been updated for several revisions of the modeL" In Reference 2, in response to the NRC staff's request for additional information (Reference 13) on the impact of this on the PRA model, the licensee explained that "the PRA is no longer based on the initial system notebooks, but rather on 'Risk Spectrum Memos,' documented in the Risk Spectrum PRA model," and that "the modeling assumptions and references in the system notebooks have been replaced with these Risk Spectrum Memos."

The peer review had found that the memos are maintained current; however, it concluded the SR was not met. The licensee is working to improve documentation for this SR by developing system notebooks from the memos.

For surveillance frequency evaluations which require the Internal Event PRA model documentation, this open gap item can be addressed using NEI 04-10 since it provides guidance on the information needed for the application.

- 12 SR SY-C2 is related to systems documentation. The licensee's analysis of the open documentation concluded that there was no significant impact for this application. In addition, updates are being done for the system documentation, as noted previously. This gap item can be addressed using NEI 04-10 guidance on documentation for surveillance frequency evaluations.

Based on the licensee's assessment using the applicable PRA standard and RG 1.200, the NRC staff concludes that the level of PRA quality, combined with the proposed evaluation and disposition of gaps, 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.

3.2.4.2 Scope of the PRA The licensee is required to evaluate each proposed change to a relocated surveillance frequency using the guidance contained in NEI 04-10 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.

As previously noted, PVNGS has an Internal Events PRA model and an Internal Flooding PRA model. PVNGS noted in the submittal that "PVNGS will follow the NEI 04-10 glJidance to assess the fire and seismic risk associated with surveillance test intervals." The licensee has utilized the Fire Induced Vulnerability Evaluation and the Seismic Margins Analysis, both of which are endorsed in NEI 04-10. By letter dated August 12, 2011 (Reference 2), in response to the NRC staff's request for additional information dated July 7,2011 (Reference 13), the licensee clarified that NEI 04-10 guidance will also be applied to other external events hazards analyses, and to shutdown analyses. The licensee also noted that its Internal Fire PRA model is being upgraded.

The NRC staff concludes that 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.

3.2.4.3 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 the 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.

- 13 The licensee will perform quantitative evaluations of the impact of selected testing strategy (Le.,

staggered testing or sequential testing) consistently with the guidance of NUREG/CR-6141, "Handbook of Methods for Risk-Based Analyses of Technical Specifications," December 1994 (Reference 14), and NUREG/CR-5497, "Common-Cause Failure Parameter Estimations,"

October 1998 (Reference 15), as discussed in NEI 04-10.

Based on the above, the NRC staff concludes that, through the application of NEI 04-10, the PVNGS 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.

3.2.4.4 Assumptions for Time-Related Failure Contributions The failure probabilities of SSCs modeled in the PVNGS PRA include a standby time-related contribution and a cyclic demand-related contribution. NEI 04-10 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 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, but are conservatively not required to be quantitatively assessed. The NRC staff concludes that, through the application of NEI 04-10, 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.

3.2.4.5 Sensitivity and Uncertainty Analyses NEI 04-10 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. 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. The NRC staff concludes that, through the application of NEI 04-10, the licensee has appropriately considered the possible impact of PRA model uncertainty and

- 14 sensitivity to key assumptions and model limitations, and is consistent with Regulatory Position 2.3.5 of RG 1.177.

3.2.4.6 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 in accordance with the TS SFCP. Each individual change to surveillance frequency must show a risk impact below 1 E-6 per year for change to CDF, and below 1 E-7 per year for change to 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 1 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 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 staff further notes that the licensee includes a provision to exclude the contribution to cumulative risk from individual changes to surveillance frequencies associated with insignificant risk increases (less than 5E-8 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 change is based on all of these 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 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 NRC staff concludes that the 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.

- 15 3.2.5 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 in the SFCP. NEI 04-10 requires performance monitoring of SSCs whose surveillance frequencies have 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 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.

3.3 Addition of Surveillance Frequency Control Program to Administrative Controls The licensee has included the SFCP and specific requirements into the Administrative Controls, TS Section 5.5.18, Surveillance Frequency Control Program, as follows:

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 that the associated Limiting Conditions for Operation are met.

a.

The Surveillance Frequency Control Program shall contain a list of Frequencies of the 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-Informed 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.

The NRC staff concludes that the licensee's proposed program is consistent with the model application of TSTF-425, Revision 3, and, therefore, is acceptable.

3.4 Optional Variations and Changes from TSTF-425, Revision 3 The licensee is adopting TSTF-425, Revision 3, with two optional changes and variations. First, the definition of STAGGERED TEST BASIS is being retained because it is referenced in a part of the TSs that is not included in this amendment. This is an administrative change and is, therefore, acceptable.

- 16 Second, the licensee is adopting the change to optional insert #2 discussed in an NRC letter to the TSTF dated April 14,2010 (Reference 9). As the licensee stated in its letter dated March 31, 2011 (Reference 1), the changes are as follows:

1.

The existing Bases information describing the basis for the Surveillance Frequency will be relocated to the licensee-controlled Surveillance Frequency Control Program.

2.

The TSTF-425 TS Bases, INSERT #2, should be added to the end of the existing TS Bases and changed to read as follows:

The Surveillance Frequency is controlled under the Surveillance Frequency Control Program.

These changes were supported by the NRC staff in its letter to the TSTF dated April 14, 2010 (Reference 9), and are, therefore, acceptable.

3.5 Summary and Conclusions The NRC staff has reviewed the licensee's proposed relocation of some 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 5.5.18 reference NEI 04-10, 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 TS to a licensee-controlled document, provided those frequencies are changed in accordance with NEI 04-10 which is specified in the Administrative Controls of the TSs.

The licensee's proposed adoption of TSTF-425, Revision 3, and risk-informed methodology of NEI 04-10, as referenced in the Administrative Controls of the TSs, satisfies the key principles of risk-informed decision making applied to changes to 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.

The NRC staff concludes that with the proposed relocation of surveillance frequencies to a licensee-controlled document and administratively controlled in accordance with the TS SFCP,

- 17 the licensee continues to meet the regulatory requirement of 10 CFR 50.36 and, specifically, 10 CFR 50.36(c)(3), surveillance requirements.

4.0 STATE CONSULTATION

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

5.0 ENVIRONMENTAL CONSIDERATION

The amendments change an inspection or surveillance requirement as defined in 10 CFR Part 20. 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 June 14, 2011 (76 FR 34765).

Accordingly, the amendments meet the eligibility criteria for categorical exclusion set forth in 10 CFR 51.22(c)(9). Pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the issuance of the amendments.

6.0 CONCLUSION

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

7.0 REFERENCES

1.

Mims, D. C., Arizona Public Service Company, letter to U.S. Nuclear Regulatory Commission, "Application for Technical Specification change Regarding Risk-Informed Justification for the Relocation of Specific Surveillance Frequency Requirements to a Licensee-Controlled Program," dated March 31,2011 (Agencywide Documents Access and Management System (ADAMS) Accession No. ML11103A053).

2.

Mims, D. C., Arizona Public Service Company, letter to U.S. Nuclear Regulatory Commission, "Response to Request for Additional Information (RAI) on License Amendment Request to Relocate Surveillance Frequencies to a Licensee-Controlled Program (TAC NOs. ME6010, ME6011, and ME6012)," dated August 12,2011 (ADAMS Accession No. ML11235A515).

3.

Nuclear Energy Institute, NEI 04-10, Revision 1, "Risk-Informed Technical Specifications Initiative 5B, Risk-Informed Method for Control of Surveillance Frequencies," April 2007 (ADAMS Accession No. ML071360456).

- 18

4.

Technical Specifications Task Force (TSTF) Improved Standard Technical Specifications Change Traveler TSTF-425, Revision 3, "Relocate Surveillance Frequencies to Licensee Control-RITSTF Initiative 5b," dated March 18,2009 (ADAMS Accession No. ML090850642).

5.

Nieh, H. K., U.S. Nuclear Regulatory Commission, letter to B. Bradley, Nuclear Energy Institute, "Final Safety Evaluation for Nuclear Energy Institute (NEI) Topical Report (TR) 04-10, Revision 1, "Risk-informed Technical Specification Initiative 5b, "Risk-Informed Method for Control of Surveillance Frequencies (TAC No. MD6111 )," dated September 19, 2007 (ADAMS Accession No. ML072570267).

6.

U.S. Nuclear Regulatory Commission, Regulatory Guide 1.174, Revision 1, "An Approach for Using Probabilistic Risk Assessment in Risk-Informed Decisions on Plant Specific Changes to the Licensing Basis," November 2002 (ADAMS Accession No. ML023240437).

7.

U.S. Nuclear Regulatory Commission, Regulatory Guide 1.177, "An Approach for Plant Specific, Risk-Informed Decisionmaking: Technical Specifications," August 1998 (ADAMS Accession No. ML003740176).

8.

U.S. Nuclear Regulatory Commission, Regulatory Guide 1.200, Revision 1, "An Approach for Determining the Technical Adequacy of Probabilistic Risk Assessment Results for Risk-Informed Activities," Revision 2, March 2009 (ADAMS Accession No. ML090410014).

9.

Bowman, E. E., U.S. Nuclear Regulatory Commission, letter to Technical Specifications Task Force, "Notification of Issue with NRC-Approved Technical Specifications Task Force (TSTF) Traveler TSTF-425, Revision 3, 'Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5b," dated April 14, 2010 (ADAMS Accession No. ML100990099).

10.

American Society of Mechanical Engineers (ASIVIE) RA-Sa-2009, "Addenda to ASME RA-S-2008 Standard for Level1/Large Early Release Frequency Probabilistic Risk Assessment for Nuclear Power Plant Applications."

11.

Nuclear Energy Institute, NEI 00-02, Revision 1, "Probabilistic Risk Assessment (PRA)

Peer Review Process Guidance," May 2006 (ADAMS Accession No. ML061510621).

12.

Nuclear Energy Institute, Revision 0, NEI 05-04, "Process for Performing Follow-On PRA Peer Reviews Using the ASME PRA Standard," August 2006.

13.

Gibson, L. K., U.S. Nuclear Regulatory Commission, electronic mail to Russell Stroud, Arizona Public Service Company, "Draft Request for Additional Information - Request to Relocate Surveillance Frequencies in Accordance with NEI 04-10 (TAC Nos. ME6010, ME6011, and ME6012)," dated July 7, 2011 (ADAMS Accession No. ML111880937).

-19

14.

U.S. Nuclear Regulatory Commission, "Handbook of Methods for Risk-Based Analyses of Technical Specifications," NUREG/CR-6141, December 1994 (non-publicly available).

15.

U.S. Nuclear Regulatory Commission, "Common-Cause Failure Parameter Estimations,"

NUREG/CR-5497, October 1998 (non-publicly available).

Principal Contributor: Daniel O'Neal, NRRIDRAIAPLA Date: December 15, 2011

R. Edington

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

Docket Nos. STN 50-528, STN 50-529, and STN 50-530

Enclosures:

1. Amendment No. 188 to NPF-41

2. Amendment No. 188 to NPF-51

3. Amendment No. 188 to NPF-74

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

PUBLIC LPLIV r/f RidsAcrsAcnw_MailCTR Resource RidsNrrDorlDpr Resource RidsNrrDorlLpl4 Resource RidsNrrDraApla Resource RidsNrrDssStsb Resource RidsNrrLAJBurkhardt Resource RidsNrrPMPaloVerde Resource RidsOgcRp Resource RidsRgn4MailCenter Resource DO'Neal, NRRlDRAIAPLA Sincerely, IRA!

Lauren K. Gibson, Project Manager Plant Licensing Branch IV Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation

b SE memo dated NRRlDORULPL4/PM LGibson NRRlDORULPL4/LA JBurkhardt NRR/DRAIAPLAlBC DHarrison'*

NRR/DSS/STSB/BC Elliott 10/25/11 10/21/11 9/9111 1/7/11 OGC NRR/DORULPL4/B NRR/DORULPL4/PM RHarper rkley LGibson 11/21/11 12/14/11 12/15/11 OFFICIAL AGENCY RECORD

v t e Letter Sequence Approval
TAC:ME6010, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME6011, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed) TAC:ME6012, Relocate Surveillance Frequencies to Licensee Control - RITSTF Initiative 5B (Approved, Closed)
Initiation Request, Request, Request Acceptance Administration Questions 7 July 2011 7 July 2011 Answers 12 August 2011 Results Approval Other:
MONTHYEAR2011-03-31 [Table View]

ML112620293

Text

SUBJECT:

Dear Mr. Edington:

Enclosures:

Attachment:

Attachment:

Attachment:

1.0 INTRODUCTION

2.0 REGULATORY EVALUATION

3.0 TECHNICAL EVALUATION

4.0 STATE CONSULTATION

5.0 ENVIRONMENTAL CONSIDERATION

6.0 CONCLUSION

7.0 REFERENCES

Enclosures:

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