Text

Application for Amendment to License Condition C.(1) Maximum Power Level (Units 1 & 3 Only), and Various Technical Specifications to Implement Administrative Changes
	ML093170318
Person / Time
Site:	Palo Verde
Issue date:	10/30/2009
From:	Mims D; Arizona Public Service Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	102-06088-DCM/RJR
	Download: ML093170318 (100)
	v • d • e

10 CFR 50.90 AMU A subsidiaryof Pinnacle West CapitalCorporation Dwight C. Mims Mail Station 7605 Palo Verde Nuclear Vice President Tel. 623-393-5403 P.O. Box 52034 Generating Station Regulatory Affairs and Plant Improvement Fax 623-393-6077 Phoenix, Arizona 85072-2034 102-06088-DCM/RJR October 30, 2009 ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Dear Sirs:

Subject:

Palo Verde Nuclear Generating Station (PVNGS)

Units 1, 2, and 3 Docket Nos. STN 50-528, 50-529, and 50-530 Application for Amendment to License Condition C.(1) Maximum Power Level (Units 1 and 3 only), and Various Technical Specifications to Implement Administrative Changes As permitted by 10 CFR 50.90, Arizona Public Service Company (APS) hereby applies for an amendment to Facility Operating Licenses NPF-41, NPF-51, and NPF-74 to remove requirements no longer applicable due to the completion of power uprate, replacement of steam generators, removal of part-length control rod assemblies, and completion of a core protection calculator upgrade. A minor administrative change to the nomenclature of the containment sump trash racks and screens is also proposed.

The proposed changes are detailed in the enclosure to this letter.

Approval of the proposed amendment is requested within one year from the date of this letter. Once approved, the amendment shall be implemented within 90 days.

In accordance with the PVNGS Quality Assurance Program, the Plant Review Board and the Offsite Safety Review Committee have reviewed and concurred with this proposed amendment. By copy of this letter, this submittal is being forwarded to the Arizona Radiation Regulatory Agency (ARRA) pursuant to 10 CFR 50.91 (b)(1).

No commitments are being made to the NRC by this letter. Should you need further information regarding this amendment request, please contact Russell A. Stroud, Licensing Section Leader, at (623) 393-5111.

A member of the STARS (strategic Teaming and Resource Sharing) Alliance Callaway 0 Comanche Peak 0 Diablo Canyon

Palo Verde 0 San Onofre 0 South Texas 0 Wolf Creek

ATTN: Document Control Desk U.S. Nuclear Regulatory Commission Application for Amendment to License Condition C.(1) Maximum Power Level (Units 1 and 3 only), and Various Technical Specifications to Implement Administrative Changes Page 2 I declare under penalty of perjury that the foregoing is true and correct.

Executed on /0/R7 Sincerely, DCM/RAS/RJRPgat

Enclosure:

Arizona Public Service Company's Evaluation of the Proposed Change cc: E. E. Collins, Jr. NRC Region IV Regional Administrator J. R. Hall NRC NRR Project Manager R. I. Treadway NRC Senior Resident Inspector for PVNGS A. V. Godwin Arizona Radiation Regulatory Agency T. Morales Arizona Radiation Regulatory Agency

ENCLOSURE ARIZONA PUBLIC SERVICE COMPANY'S EVALUATION OF THE PROPOSED CHANGE

1.

SUMMARY

DESCRIPTION

2. DETAILED DESCRIPTION

3. TECHNICAL EVALUATION

4. REGULATORY EVALUATION 4.1 Applicable Regulatory Requirements/Criteria 4.2 No Significant Hazards Consideration Determination 4.3 Conclusions

5. ENVIRONMENTAL CONSIDERATION ATTACHMENTS:

1. Proposed Operating License and Technical Specification Changes (mark-up)

2. Proposed Technical Specification Changes (retyped)

Enclosure 1.0

SUMMARY

DESCRIPTION This evaluation supports the application to amend Operating Licenses NPF-41, NPF-51, and NPF-74 for Palo Verde Nuclear Generating Station (PVNGS) Units 1, 2, and 3, respectively. The proposed changes are administrative and would not result in any change to operating requirements. The proposed administrative changes remove requirements no longer applicable due to the completion of power uprate, replacement of steam generators, removal of part-length control rod assemblies, and completion of a core protection calculator upgrade. A minor administrative change to the nomenclature of the containment sump trash racks and screens is also proposed. These minor administrative changes are proposed for the following License Conditions and Technical Specifications (TS):

" Units 1 and 3 Facility Operating Licenses, License Condition C.(1) "Maximum Power Level"

" Units 1, 2 and 3 Technical Specifications:

o Table of Contents, o 1.1 "Definitions,"

o 3.1.5 "Control Element Assembly (CEA) Alignment,"

o 3.1.8 "Part Length or Part Strength Control Element Assembly (CEA) Insertion Limits,"

o 3.1.10 "Special Test Exceptions (STE) - MODES 1 and 2,"

o 3.1.11 "Special Test Exceptions (STE) - Reactivity Coefficient Testing,"

o 3.2.4 "Departure from Nucleate Boiling Ratio (DNBR),"

o 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating,"

o 3.3.2 "Reactor Protective System (RPS) Instrumentation - Shutdown,"

o 3.3.3 "Control Element Assembly Calculators (CEACs),"

o 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation,"

o 3.4.1 "RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits,"

o 3.5.3 "ECCS - Operating,"

o 3.7.1 "Main Steam Safety Valves (MSSVs),"

o 5.4 "Procedures,"

o 5.5.9 "Steam Generator (SG) Program," and o 5.6.5 "Core Operating Limits Report (COLR)."

2.0 DETAILED DESCRIPTION The following changes are proposed:

A. Units 1 and 3 Operating Licenses, License Condition C. (1) "Maximum Power Level,"

and Units 1,2, and 3, Technical Specifications 1.1 "Definitions," 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating," 3.3.2 "Reactor Protective System (RPS) Instrumentation - Shutdown," 3.3.5 "Engineered Safety Features Actuation System (ESFAS) Instrumentation," 3.4.1 "RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits," and 3.7.1 "Main Steam Page 1

Enclosure Safety Valves (MSSVs)." Remove superseded references to 3876 megawatts thermal (MWt) and information related to this value.

This change is administrative and is necessary to complete the Power Uprate and Steam Generator Replacement Projects. Removal of the references to 3876 MWt and information related to this value corrects the Operating License and the affected TS sections.

B. Technical Specification "Table of Contents," 1.1 "Definitions," 3.1.5 "Control Element Assembly (CEA) Alignment," 3.1.8 "Part Length or Part Strength Control Element Assembly (CEA) Insertion Limits," 3.1.10 "Special Test Exceptions (STE) - MODES 1 and 2," 3.1.11 "Special Test Exceptions (STE) - Reactivity Coefficient Testing,"

3.3.3 "Control Element Assembly Calculators (CEACs)," and 5.6.5 "Core Operating Limits Report (COLR)." Remove references to Part Length Control Element Assemblies (CEA).

This change is administrative. APS has completed removal of all part length CEAs at Palo Verde Units 1, 2, and 3 and this change removes the respective references to part length CEAs from the affected TS sections.

C. Technical Specification 3.2.4 "Departure from Nucleate Boiling Ratio (DNBR)," 3.3.1 "Reactor Protective System (RPS) Instrumentation - Operating," 3.3.3 "Control Element Assembly Calculators (CEACs)," and 5.4 "Procedures." Remove pages from TS identified as "(Before CPC Upgrade)" or "(Before CPCS Upgrade)," and delete the designator "(After CPC Upgrade)" or "(After CPCS Upgrade)," from the affected TS pages. In addition, the indentation of the logical connectors AND and OR in TS 3.2.4, between Required Actions B.1, B.2.1, and B.2.2 is being adjusted to be consistent with the action numbers and with TS 1.2.

These changes are administrative. APS has completed a core protection calculator (CPC) upgrade in all Palo Verde units. This change removes the redundant TS pages identified as "(Before CPC Upgrade) or (Before CPCS Upgrade)" and removes the reference to "(After CPC Upgrade) or (After CPCS Upgrade)" from various TS pages that will be renumbered and remain in place. The adjustment of the indentation of the logical connectors AND and OR in TS 3.2.4 is consistent with the action numbers and with TS 1.2.

D. Technical Specification 3.5.3 "ECCS - Operating," Surveillance Requirement (SR) 3.5.3.8. Change the nomenclature from "trash racks and screens" to "strainers."

This change is administrative. The change from "trash racks and screens" to "strainers" does not change the intent of the Surveillance Requirement 3.5.3.8 to verify, by visual inspection, that 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.

Page 2

Enclosure E. Technical Specification 5.5.9 "Steam Generator (SG) Program." Delete SG Program Item 5.5.9d.2a and delete the statement "Replacement SGs with Alloy 690 TT tubes:" from Item 5.5.9d.2d and renumber item 5.5.9d.2b to 5.5.9d.2.

This change is administrative. The steam generators with Alloy 600 MA tubes have been replaced. Therefore the requirement to inspect SGs with Alloy 600 MA tubes is no longer applicable.

3.0 TECHNICAL EVALUATION

The proposed changes to the Operating License Condition and Technical Specifications are administrative and/or editorial and do not affect how plant equipment is operated or maintained. No changes to the physical plant or analytical methods are described and there are no impacts on the PVNGS Updated Final Safety Analysis Report (UFSAR) accident analysis.

List of Proposed Administrative Changes Proposed Change Justification Technical Specification Sections Remove superseded Completed 3990 MWt power uprate. 1.1,3.3.1, reference to 3876 3.3.2, 3.3.5, megawatts thermal 3.4.1, and (MWt) and information 3.7.1 related to this value.

Delete superseded Completed replacement of PL CEAs with part 1.1,3.1.5, part-length (PL) strength (PS) CEAs in all three PVNGS units. 3.1.8, 3.1.10, control element 3.1.11, 3.3.3, assembly (CEA) 5.6.5 limits, specifications, and references.

Delete superseded Completed core protection calculator (CPC) 3.2.4, 3.3.1, core protection replacement modification in all three PVNGS 3.3.3 and 5.4 calculator (CPC) units.

limits, specifications, and references.

Adjust the indentation The adjustment of the indentation of the logical 3.2.4 of the logical connectors AND and OR in TS 3.2.4 is connectors AND and consistent with the Action numbers B.1, B.2.1, OR in TS 3.2.4, and B.2.2 and with TS 1.2 between Required Actions B.1, B.2.1, and B.2.2.

Page 3

Enclosure Proposed Change Justification Technical Specification Sections Replace containment The new PVNGS containment sump TS SR sump "trash racks and screens/strainers function as trash racks and 3.5.3.8 screens" with screens; however, this administrative change "strainers." would clarify the PVNGS nomenclature to be consistent with the industry nomenclature. (STP ML080360209 03/25/08, DC Cook ML072780605 10/18/07).

Delete Alloy-600 Completed replacement of Alloy-600 steam 5.5.9 steam generator generators in all three units.

limits, specifications, and references.

4.0 REGULATORY EVLAUATION 4.1 Applicable Regulatory Requirements/Criteria The proposed changes to the Operating License Condition and Technical Specifications are administrative and/or editorial and do not affect any regulatory requirements or criteria. These changes do not affect how plant equipment is operated or maintained and there are no changes to the physical plant or analytical methods. As a result, there are no impacts on the PVNGS UFSAR accident analysis.

4.2 No Significant Hazards Consideration Determination Arizona Public Service (APS) has evaluated whether or not a significant hazards consideration is involved with the proposed amendments by focusing on the three standards set forth in 10 CFR 50.92, "Issuance of amendment," as discussed below:

1. Does the proposed change involve a significant increase in the probability or consequences of an accident previously evaluated?

Response: No.

The proposed amendment includes the following changes that are considered to be administrative and/or editorial changes:

A. Remove superseded references to 3876 megawatts thermal (MWt) and related information to this value from Unit 1 and Unit 3 Operating Licenses and Unit 1, 2, and 3 Technical Specifications.

Page 4

Enclosure This change is administrative. The change only removes the references to 3876 MWt and related information to this value and leaves the references to 3990 MWt.

B. Remove references to Part Length Control Element Assemblies.

This change is administrative because it only removes references to part length CEAs which have been replaced by part strength CEAs.

C. Remove outdated pages and other references as a result of the CPC upgrade, and adjust the indentation of the logical connectors AND and OR in TS 3.2.4, between Required Actions B.1, B.2.1, and B.2.2.

This change is administrative because it removes the redundant TS pages identified as "(Before CPC Upgrade) or (Before CPCS Upgrade)" and removes the reference to "(After CPC Upgrade) or (After CPCS Upgrade)" from various TS pages that will be renumbered and remain in place. The CPC upgrade has been completed. The adjustment of the indentation of the logical connectors AND and OR in TS 3.2.4 is consistent with the Action numbers and with TS 1.2.

D. Change "trash racks and screens" to "strainers."

This change is administrative. The change from "trash racks and screens" to "strainers" does not change the intent of the Surveillance Requirement 3.5.3.8 to verify, by visual inspection, that 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.

E. Delete inspection requirements for Steam Generators (SG) with Alloy 600 MA tubes.

This change is administrative because APS has completed the SG replacement project which removed all SGs containing Alloy 600 MA tubes.

As discussed above, the proposed amendment involves administrative and/or editorial changes only. The proposed amendment does not impact any accident initiators, analyzed events, or assumed mitigation of accident or transient events.

The proposed changes do not involve the addition or removal of any equipment or any design changes to the facility. The proposed changes do not affect any plant operations, design function, or analysis that verifies the capability of structures, systems, and components (SSCs) to perform a design function. The proposed changes do not change any of the accidents previously evaluated in the UFSAR.

The proposed changes do not affect SSCs, operating procedures, and administrative controls that have the function of preventing or mitigating any of these accidents.

Page 5

Enclosure Therefore, the proposed changes do not represent a significant increase in the probability or consequences of an accident previously evaluated.

2. Does the proposed change create the possibility of a new or different kind of accident from any accident previously evaluated?

Response: No As stated in response to standard 1, the proposed amendment only involves administrative and/or editorial changes. No actual plant equipment or accident analyses will be affected by the proposed changes. The proposed changes will not change the design function or operation of any SSCs. The proposed changes will not result in any new failure mechanisms, malfunctions, or accident initiators not considered in the design and licensing bases. The proposed amendment does not impact any accident initiators, analyzed events, or assumed mitigation of accident or transient events.

Therefore, this proposed change does not create the possibility of an accident of a new or different kind than previously evaluated.

3. Does the proposed change involve a significant reduction in a margin of safety?

Response: No As stated in response to standard 1, the proposed amendment only involves administrative and/or editorial changes. The proposed change does not involve any physical changes to the plant or alter the manner in which plant systems are operated, maintained, modified, tested, or inspected. The proposed change does not alter the manner in which safety limits, limiting safety system settings or limiting conditions for operation are determined. The safety analysis acceptance criteria are not affected by this change. The proposed change will not result in plant operation in a configuration outside the design basis. The proposed change does not adversely affect systems that respond to safely shutdown the plant and to maintain the plant in a safe shutdown condition.

Therefore, the proposed change does not involve a significant reduction in a margin of safety.

4.3 Conclusion Based on the considerations discussed above:

1. There is reasonable assurance that the health and safety of the public will not be endangered by operation in the proposed manner; Page 6

Enclosure

2. Such activities will be conducted in compliance with the Commission's regulations; and,

3. Issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

Therefore, APS concludes that the proposed amendment presents no significant hazards consideration under the standards set forth in 10 CFR 50.92(c) and, accordingly, a finding of "no significant hazards consideration" is justified.

5.0 ENVIRONMENTAL CONSIDERATION

A review has determined that the proposed amendment would not change a requirement with respect to installation or use of a facility component located within the restricted area, as defined in 10 CFR 20, or change an inspection or surveillance requirement. The proposed amendment does not involve (i) a significant hazards consideration, (ii) a significant change in the types or a significant increase in the amounts of any effluents that may be released offsite, or (iii) a significant increase in individual or cumulative occupational radiation exposure. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(9). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.

Page 7

Attachment 1 Proposed Operating License and Technical Specification Changes (mark-up)

UI OL Page 4 Page 3.3.3-8 U3 OL Page 4 Page 3.3.5-4 TS TOC Page i Page 3.4.1-3 Page 1.1-6 Page 3.4.1-4 Page 3.1.5-1 Page 3.5.3-3 Page 3.1.5-3 Page 3.7.1-4 Page 3.1.8-1 Page 5.4-1 Page 3.1.8-2 Page 5.4-2 Page 3.1.10-1 Page 5.5-7 Page 3.1.11-1 Page 5.5-8 Page 3.2.4-1 Page 5.6-3 Page 3.2.4-2 Page 5.6-4 Page 3.2.4-3 Page 5.6-5 Page 3.2.4-4 Page 3.3.1-1 Page 3.3.1-2 Page 3.3.1-3 Page 3.3.1-4 Page 3.3.1-5 Page 3.3.1-6 Page 3.3.1-7 Page 3.3.1-8 Page 3.3.1-9 Page 3.3.1-10 Page 3.3.1-11 Page 3.3.1-12 Page 3.3.1-13 Page 3.3.1-14 Page 3.3.1-15 Page 3.3.1-16 Page 3.3.1-17 Page 3.3.1-18 Page 3.3.1-19 Page 3.3.2-5 Page 3.3.3-1 Page 3.3.3-2 Page 3.3.3-3 Page 3.3.3-4 Page 3.3.3-5 Page 3.3.3-6 Page.3.3.3-7

0L._

(6)(a) Pursuant to an Order of the Nuclear Regulatory Commission dated December 12, 1985, the Public Service Company of New Mexico (PNM) was authorized to transfer a portion of its ownership share in Palo Verde, Unit 1 to certain institutional investors on December 31, 1985, and at the same time has leased back from such purchasers the same interest in the Palo Verde, Unit 1 facility. The term of the lease is to January 15, 2015, subject to a right of renewal. Additional sale and leaseback transactions (for a term expiring on January 15, 2015) of all or a portion of PNM's remaining ownership share in Palo Verde Unit 1 are hereby authorized until June 30, 1987. Any such sale and leaseback transaction is subject to the representations and conditions set forth in the aforementioned applications of October 19, 1985, February 5, 1986, October 16, 1986 and November 26, 1986, and the Commission's Order of December 12, 1985, consenting to such transactions. Specifically, the lessor and anyone else who may acquire an interest under this transaction are prohibited from exercising directly or indirectly any control over the licensees of the Palo Verde Nuclear Generating Station, Unit 1. For purposes of this condition, the limitations in 10 CFR 50.81, "Creditor Regulations," as now in effect and as they may be subsequently amended, are fully applicable to the lessor and any successor in interest to that lessor as long as the license for Palo Verde, Unit 1 remains in effect; this financial transaction shall have no effect on the license for the Palo Verde nuclear facility throughout the term of the license.

(b) Further, the licensees are also required to notify the NRC in writing prior to any change in: (i) the terms or conditions of any lease agreements executed as part of this transaction; (ii) the ANPP Participation Agreement, (iii) the existing property insurance coverage for the Palo Verde nuclear facility, Unit 1 as specified in license counsel's letter of November 26, 1985, and (iv) any action by the lessor or others that may have an adverse effect on the safe operation of the facility.

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

(1) Maximum Power Level Arizona Public Service Company (APS) is authorized to operate the facility at reactor core power levels not in excess of

-. *.*!. ......... F* -g....h ..... tii...... 2 a d*,3990 4A megawatts thermal (100% power) 2 ,br....... a 2,, in accordance with the conditions specified herein.

Amendment No. 4-4-, 4-08, 2-28,Q

U3 iL_

(1) Maximum Power Level Arizona Public Service Company (APS) is authorized to the facility at reactor core power levels not in excess of 4 990 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. 177, 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) Antitrust Conditions This license is subject to the antitrust conditions delineated in Appendix C to this license.

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

Deleted (5) Additional Conditions The Additional Conditions contained in Appendix D, as revised through Amendment No. 171, are hereby incorporated into this license. The licensee shall operate the facility in accordance with the Additional Conditions.

(6) Mitigation Strategy License Condition APS shall develop and maintain strategies for addressing large fires and explosions and that include the following key areas:

(a) Fire fighting response strategy with the following elements:

1. Pre-defined coordinated fire response strategy and guidance.

2. Assessment of mutual aid fire fighting assets.

3. Designated staging areas for equipment and materials.

4. Command and control.

5. Training of response personnel.

Amendment No. 177 Revised by letter dated August 2, 2007

PALO VERDE NUCLEAR GENERATING STATION IMPROVED TECHNICAL SPECIFICATIONS TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions 1.2 Logical Connectors 1.3 Completion Times 1.4 Frequency 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.2 SL Violations 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) -- Reactor Trip Breakers Open 3.1.2 SHUTDOWN MARGIN (SDM) -- Reactor Trip Breakers Closed 3.1.3 Reactivity Balance 3.1.4 Moderator Temperature Coefficient (MTC) 3.1.5 Control Element Assembly (CEA) Alignment 3.1.6 Shutdown CEA Insertion Limits 3.1.7 Regulating CEA Insertion Limits 3.1.8 CPart Strength CEA Insertion Limits 3.1.9 Specia es xception (STE) -- SHUTDOWN MARGIN (SDM) 3.1.10 STE -- MODES 1 and 2 3.1.11 STE -- Reactivity Coefficient Testing 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Linear Heat Rate (LHR) 3.2.2 Planar Radial Peaking Factors (Fxy) 3.2.3 Azimuthal Power Tilt (Tq) 3.2.4 Departure From Nucleate Boiling Ratio (DNBR) 3.2.5 Axial Shape Index (ASI)

PALO VERDE UNITS 1,2.3 i AMENDMENT NO. _4_,44<

Definitions 1.1 1.1 Definitions (continued)

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP)

REACTOR PROTECTIVE The RPS RESPONSE TIME shall be that time interval SYSTEM (RPS) RESPONSE from when the monitored parameter exceeds its RPS TIME trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

SHUTDOWN MARGIN (SDM) SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All full strength CEAs (shutdown and regulating) are fully inserted except for the single CEA of highest reactivity worth, which is assumed to be fully withdrawn. With any full strength CEAs not capable of being fully inserted, the withdrawn reactivity worth of these CEAs must be accounted for in the determination of SDM and

b. There is no change in epart strength CEA position.q-'---

1.1-6 AMENDMENT NO. 4~, 157 UNITS 1,2,3 VERDE UNITS PALO VERDE 1,2,3 1.1-6 AMENDMENT NO. 4-5;, 157

CEA Alignment 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Element Assembly (CEA) Alignment LCO 3.1.5 All full stren th CEAs shall be OPERABLE, and all full strength and aligned to with i part strength CEAs shall be ic es (indicated position) of all I

other CEAs in their respective groups.

APPLICABILITY: MODES 1 and 2.

ACTIONS _

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more CEAs A.1 Reduce THERMAL POWER 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months trippable and in accordance with misaligned from its the limits in the group by > 6.6 inches COLR.

and ! 9.9 inches.

AND OR A.2 Restore CEA 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months One CEA trippable and alignment.

misaligned from its group by > 9.9 inches.

(continued)

PALO VERDE UNITS 1,2,3 3.1.5-1 AMENDMENT NO. 44-1, -1&--

CEA Alignment 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify the indicated ition of each full 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months strength and -Itpart strength CEA is within . h of all other CEAs in its group.

SR 3.1.5.2 Verify that, for each CEA, its OPERABLE CEA 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months position indicator channels indicate within 5.2 inches of each other.

SR 3.1.5.3 Verify full strength CEA freedom of 92 days movement (trippability) by moving each individual full strength CEA that is not fully inserted in the core at least 5 inches.

SR 3.1.5.4 Perform a CHANNEL FUNCTIONAL TEST of each 18 months reed switch position transmitter channel.

SR 3.1.5.5 Verify each full strength CEA drop time 4.0 seconds, Prior to reactor I

criticality.

after each removal of the reactor head PALO VERDE UNITS 1,2,3 3.1.5-3 AMENDMENT NO. 4-1-i, t5r

Part Strength CEA Insertion Limits 3.1.8 II 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PPart Strength Control Element Assembly (CEA) Insertion Liml s LCO 3.1.8 The Epart strength CEA groups shall be limited to the inser ion limits specified in the COLR.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. stren s gart gt h CEA groups A.1 Restore part o strength 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

%-AE -

inserted beyond the groups to within the transient insertion limit.

limit.

OR A.2 Reduce THERMAL POWER 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to less than or equal to that fraction of RTP specified in the COLR.

B.

a art B.1 Restore

2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months strengthCEA groups part streng inserted between the groups to within the long term steady state long term steady state insertion limit and insertion limit.

the transient insertion limit for intervals

Ž 7 effective full power days (EFPD) per 30 EFPD or Ž 14 EFPD per 365 EFPD interval.

(continued)

PALO VERDE UNITS 1,2,3 3.1.8-1 AMENDMENT NO. 4-147, t5L-

PPart Strength CEA Insertion Limits 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Verify part strength CEA 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months group poST*.Tm--I PALO VERDE UNITS 1,2,3 3.1.8-2 AMENDMENT NO. 1-I-,-1

STE - MODES 1 and 2 3.1.10 3.1 REACTIVITY CONTROL SYSTEMS 3.1.10 Special Test Exceptions (STE) - MODES 1 and 2 LCO 3.1.10 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1.4, "Moderator Temperature Coefficient (MTC)";

LCO 3.1.5. "Control Element Assembly (CEA) Alignment";

LCO 3.1.6, "Shutdown Control Element Assembly (CEA)

Insertion Limits":

LCO 3.1.7, "Regulating Control Element Assembly (CEA)

Insertion Limits":

LCO 3.1.8, 9 Part Strength CEA Insertion LCO 3.2.2, "Planar Radial Peaking Factors (Fxy)";

LCO 3.2.3, "AZIMUTHAL POWER TILT (Tq)":

LCO 3.2.5. "AXIAL SHAPE INDEX (ASI)": and LCO 3.3.3, "Control Element Assembly Calculators (CEACs)"

may be suspended, provided:

a. THERMAL POWER is restricted to the test power plateau, which shall not exceed 85% RTP: and

b. Shutdown reactivity equivalent to at least the highest estimated CEA worth (of those CEAs actually withdrawn) is available for trip insertion.

APPLICABILITY: MODES 1 and 2 during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Test power plateau A.1 Reduce THERMAL POWER 15 minutes exceeded. to less than or equal to the test power plateau.

B. Required Action and B.1 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion TESTS.

Time not met.

PALO VERDE UNITS 1,2,3 3.1.10-1 AMENDMENT NO. 4-52 45&

STE - Reactivity Coefficient Testing 3.1.11 3.1 REACTIVITY CONTROL SYSTEMS 3.1,11 Special Test Exceptions (STE) - Reactivity Coefficient Testing LCO 3.1.11 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1.7, "Regulating Control Element Assembly (CEA)

Insertion Limits";

LCO 3.1.8, '4,Part Strength Control Element Assembly (EA)Insertion Limits:" and LCO 3.4.1. "RCS Pressure, Temperature and Flow limits" (LCO 3.4.1.b. RCS Cold Leg Temperature only) may be suspended, provided LHR and DNBR do not exceed the limits in the COLR.

APPLICABILITY: MODE 1 with Thermal Power > 20% RTP during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LHR or DNBR outside A.1 Reduce THERMAL POWER 15 minutes the limits specified to restore LHR and in the COLR. DNBR to within limits.

B.- Required Action and B.1 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion TESTS.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.11.1 Verify LHR and DNBR do not exceed limits by Continuously performing SR 3.2.1.1 and SR 3.2.4.1.

PALO VERDE UNITS 1,2,3 3.1.11-1 AMENDMENT NO. l-1,-

DNBR (Before CPC Upgrade) 3.2.4 I

3.2 POWER DISTRI BUTION LIMITS 3.2.4 Departure From Nucleate Boiling Ratio (DNBR)

LCO 3.2.4 The DNBR shall be maintained by one of t e following methods:

a. Maintaining Core Operating Limi Supervisory System (COLSS) calculated core power ess than or equal to COLSS calculated core power erating limit based on DNBR (when COLSS is in servyce, and either one or both Control Element Assembly lculators (CEACs) are OPERABLE):

b. Maintaining COLSS cal lated core power less than or equal to COLSS calcul ted core power operating limit based on DNBR decr sed by the allowance specified in the COLR (when CO S is in service and neither CEAC is OPERABLE):

c. Operating wit n the region of acceptable operation specified in he COLR using any OPERABLE Core Protection Calculator PC) channel (when COLSS is out of service and either one or both CEACs are OPERABLE); or

d. Operati within the region of acceptable operation specified in the COLR using any OPERABLE CPC channel (whe COLSS is out of service and neither CEAC is OPE BLE).

APPLICABILITY: MOD 1 with THERMAL POWER > 20% RTP. (Before CPC Upgrade) I ACTIONS CONDIT/N REQUIRED ACTION COMPLETION TIME A. COLSS c culated core A.1 Restore the DNBR to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power ot within within limit.

limi (continued)

PALO VERDE UNITS 1.3 .2. 3.2.4-1 AMENDMENT NO. 150

DNBR (Before CPC Upgrade) 3.2.4 I

ACTIONS (continued)

CONDITION REQUIRED ACTION COM _EN TIME B. DNBR outside the B.1 Determine trend in DNBR. #Once per region of acceptable AND 15 minutes operation when COLSS is out of service. B.2.1 With an adverse trend, restore D 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to within limit OR B.2.2 With no a erse 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months trend, r tore DNBR to wit *n limit.

C. Required Action and C.1 Re ce THERMAL POWER 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion t _*20% RTP.

Time not met.

SURVEILLANCE REQUIREMENTS SURVE/ FREQUENCY SR 3.2.4.1 - - - - - - - - --NOTE- -- - - - - - - - -

1. Onl applicable when COLSS is out of s vice. With COLSS in service, this rameter 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 with THERMAL POWER > 20% RTP.

Verify DNBR, as indicated on any OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNBR channels, is within the limit of the COLR, as applicable.

SR 3. .4.2 Verify COLSS margin alarm actuates at a 31 days THERMAL POWER level equal to or less than the core power operating limit based on DNBR.

PALO VERDE UNITS 1,2,3 3.2.4-2 AMENDMENT NO. 4-14, 150

DNBR 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Departure From Nucleate Boiling Ratio (DNBR)

LCO 3.2.4 The DNBR shall be maintained by one of the following methods:

a. Core Operating Limit Supervisory System (COLSS) In Service:

1. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR when at least one Control-Element Assembly Calculator (CEAC) is OPERABLE in each OPERABLE Core Protection Calculator (CPC) channel; or

2. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR decreased by the allowance specified in the COLR when the CEAC requirements of LCO 3.2.4.a.1 are not met.

b. COLSS Out of Service:

1. Operating within the region of acceptable operation specified in the COLR usi.ng any OPERABLE Core Protection Calculator (CPC) channel when at least one Control Element Assembly Calculator (CEAC) is OPERABLE in each OPERABLE CPC channel; or

2. Operating within the region of acceptable operation specified in the COLR using any OPERABLE CPC channel (with both CEACs inoperable)-when the CEAC requirements of LCO 3.2.4.b.1 are not met.

APPLICABILITY: MODE 1 with THERMAL POWER > 20% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. COLSS calculated core A.1 Restore the DNBR to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power not within within limit.

limit.

(continued)

PALO VERDE UNITS 1,2.3 3.2.4/-, AMENDMENT NO.- i5-1

DNBR ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. DNBR outside the B.1 Determine trend in DNBR. Once per region of acceptable 15 minutes operation when COLSS is out of service. B.2.l* ith an adverse trend, restore DNBR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to within limit.

B.2.2 With no adverse 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months trend, restore DNBR to within limit.

C. Required Action and C.1 Reduce THERMAL POWER 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion to

20% RTP.

Time not met.

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 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 with THERMAL POWER > 20% RTP.

Verify DNBR, as indicated on any OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNBR channels, is within the limit of the COLR, as applicable.

SR 3.2.4.2 Verify COLSS margin alarm actuates at a 31 days THERMAL POWER level equal to or less than the core power operating limit based on DNBR.

PALO VERDE UNITS 1.2.3 3.2.4-/ AMENDMENT NO.-16e--

Z-

RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Protective System (RPS) Instrumentation - Operating LCO 3.3.1 Four RPS trip and by pass removal channels for e4 Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1. (Before CPC Up.ade)

/

ACTIONS /

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

Separate Condition entry is allowed for each RPS Func ion.

,CONDITION REQUIRED ACT N COMPLETION TIME A. One or more Functions A.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one automatic RPS bypass r trip.

trip channel inoperable. AND A.2 Re tore channel to Prior to ERABLE status. entering MODE 2 following next MODE 5 entry B. One or more Functions with two automatic RPS trip channels B Place one channel in bypass and the other in trip.

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

inoperable.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-1 AMENDMENT NO. 41-49. 165

RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 ACTIONS (continued)

/

CONDITION REQUIRED ACTION COMPLEYION TIME C. One or more Functions C.1 Disable bypass 1 h6ur with one automatic channel.

bypass removal channel inoperable. OR C.2.1 Place affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass r trip.

AND C.2.2 Restore byp s Prior to removal ch nel and entering MODE 2 associate automatic following next trip cha el to MODE 5 entry OPERABL status.

D. One or more Functions D.1 Di le bypass 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two automatic c nnels. I bypass removal channels inoperable. OR 0.2 Place one affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass and place the other in trip.

E. One or more core Perform CHANNEL 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months protection calcula FUNCTIONAL TEST on (CPC) channels witl affected CPC.

cabinet high temperature alar/

I (conti nued) el--

PALO VERDE UNITS 1,2,3 3.3.1-2 AMENDMENT NO. 4EA, 165

RPS Instrumentation - Operating (Before CPC Upgrade) I 3.3.1 ACTIONS (continued) A CONDITION REQUIRED ACTION COMPLETI TIME F. One or more CPC F.1 Perform CHANNEL 24 h rs channels with three or FUNCTIONAL TEST on more autorestarts affected CPC.

during a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months period.

A G. Required Action and G.1 Be in MODE iours associated Completion Time not met.

SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform a CHANNEL ECK of each RPS 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months instrument channe (continued)

Q4'-

PALO VERDE UNITS 1,2.3 3.3.1-3 AMENDMENT NO. 4ý, 150

RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 I SURVEILLANCE REQUIREMENTS (continued) v SURVEILLANCE SR 3.3.1.2 ---------------- NOTE--------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after THERMAL POWER Ž 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 ea CPC indicated flow is less than or equ to the RCS flow rate.

/

SR 3.3.1.3 Check the CPC autorestart count. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

Q)

PALO VERDE UNITS 1,2,3 3.3.1-4 AMENDMENT NO. 44-7-, 150

RPS Instrumentation - Operating (Before CPC Upgrade) I 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 ---------------- 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 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 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months adjust the linear power level signals ad the CPC addressable constant multipliets to make the CPC AT power and CPC nuclear power calculations agree with the calorim ric, if the absolute difference is > 2%/hen THERMAL POWER is >80% RTP. Betw en 20%

and 80% RTP the maximum differenye is -0.5%

to 10%.

SR 3.3.1.5 - --------------- NOTE-------------

,,---_,--_-_--_-__T after THERMAL POWER Žt %..RTP.

Not required to be perf med until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months Verify total RCS f ow rate indicated by 31 days each CPC is less han or equal to the RCS flow determined ither using the reactor coolant pump di ferential pressure instrumentati n and the ultrasonic flow meter adjust d pump curves or by calorimetri cA u1ations.

J J

(continued)

/

PALO VERDE UNITS 1,2,3 3.3.1-5 AMENDMENT NO. 4;, 150

RPS Instrumentation - Operating (Before CPC Upgrade)

SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUEN SR 3.3.1.6 ---------------- 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 POWER > 15% RTP.

Verify linear power subchannel gains of the 31ys excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.

SR 3.3.1.7 ---------------- NOTES---------------

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

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

Perform CHANNEL FUNCTIONAL TEST on each 92 days channel....

SR 3.3.1.8 ------------------ NOTE----------------

Neutron detectors ar 'excluded from the CHANNEL CALIBRATIO Perform CHANNEL IBRATION of the power 92 days range neutron lux channels.

_ / N(continued)

PALO VERDE UNITS 1,2,3 3.3.1-6 AMENDMENT NO. 4-44, 4-1-9, 150

RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 SURVEILLANCE REQUIREMENTS (continued) (

SURVEILLANCE FREQUENCY SR 3.3.1.9 ------------------- NOTE---------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each 18 mont channel, including bypass removal functions.

SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each 1 months SR 3.3.1.11 Using the incore detectors, verify the Once after each shape annealing matrix elements to be ed refueling prior by the CPCs. to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function. 92 days prior to each reactor startup SR 3.3.1.13 ------------------ NQTE---------------

Neutron detectors ar, excluded.

Verify RPS RESP SE TIME is within limits. 18 months on a STAGGERED TEST BASIS PALO VERDE UNITS 1,2.3 3.3.1-7 AMENDMENT NO. 44;, 150

RPS Instrumentation - Operating (Before CPC Upgr e)

.3.1 Table 3.3.1-1 (page 1 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALL(ABLE VALUE

1. Variable Over Power 1.2 SR 3.3.1.1 Ceilin/! 111.0% RTP SR 3.3.1.4 Band 9.9% RTP SR 3.3.1.6 Incr'/Rate s 11.0%/min RTP SR 3.3.1.7 Decr/. Rate > 5%/sec RTP SR 3.3.1.8 SR 3.3.1.9 SR 3.3.1.13

2. Logarithmic Power Level - High(a) 2 SR 3.3.1.1 ! 0.011% NRTP SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.1 SR 3.3.1.

SR 3.3. .I

3. Pressurizer Pressure - High 1,2

2388 psia SR 3.3 1.7 SR 3.3.1.9 SR 3/3.1.13

/

4. Pressurizer Pressure - Low 1.2 'S 3.3.1.1 2 1821 psia 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13

5. Containment Pressure - High 1.2 SR 3.3.1.1 5 3.2 psig SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

6. Steam Generator #1 Pressure - Low 1 SR 3.3.1.9 3876 MWt RTP: 2 890 psia SR 3.3.1.7 3990 MWt RTP: z 955 psiall" SR 3.3.1.9 SR 3.3.1.13

7. Steam Generator #2 Pressure - Low -,e Y.2 SR 3.3.1.1 3876 MWt RTP: 2 890 psia SR 3.3.1.7 3990 MWt RTP: Ž 955 psia'"

SR 3.3.1.9 SR 3.3.1.13

(L* - (continued)

(a) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is !5*E4% NRTP.

(aa). 1. If the as-found channel ietpointZ is conservative with respect to the Allowable Value but outside its predetermined as-found ac ptance criteria band, then the channel shall be evaluated to verify that it is functioning as requir before returning the channel to service. If the as-found instrument channel setpoint is not conserv ive with respect to the Allowable value. the channel shall be declared i noperabl e.

2. The instrument ch fnel setpeint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setp 'nt. or within the as left tolerance of a setpoint that is more conservative than the UFSAR Tr ip Se/P oint; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodol y used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance crit ia band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE U TS 1.2,3 3.3.1-8 AMENDMENT NO. 4i-54, 157

RPS Instrumentation - Operating (Before CPC Upgrade) f3.

Table 3.3.1-1 (page 2 of 3) J Reactor Protective System Instrumentation /

APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWAB VALUE I

8. Steam Generator #1 Level - Low 1,2 SR3.3.1.1 43.7%

SR3.3.1.7 SR 3.3.1.9 SR3.3.1.13

9. Steam Generator #2 Level - Low 1,2 SR 3.3.1.1 t 43.7%

SR SR 3.3.1.7 3.3.1.9 / /

SR 3.3.1.13

10. Steam Generator 1

1 Level - High 1.2 SR < 91.5%

SR SR SR

11. Steam Generator #2 Level - High 1,2 SR 91.5%

SR SR SR

12. Reactor Coolant Flow, Steam 1,2 SR 3.3.1.1 Ramp: ! 0.115 psid/sec.

Generator #1-Low SR 3.3.1.7 Floor: : 12.49 psid SR 3.3.1.9 Step: ! 17.2 psid SR 3.3.1.13

13. Reactor Coolant Flow. Steam 1.2 SR 3.3.1.1 Ramp: ! 0.115 psid/sec.

Generator #2-Low SR 3.3.1.7 Floor: 2 12.49 psid SR 3.3.1.9 step: : 17.2 psid SR 3.3.1.13 (continued)

PALO VERDE 1.2,3 3.3.1-9 AMENDMENT NO. 426, 150

RPS Instrumentation - Operating (Before CPC Upgrade) 3.3.1 Table 3.3.1-1 (page 3 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE /

FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VAJE

14. Local Power Density - High(b) 1,2 SR 3.3.1.1

21.0 kWlf SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.11 SR 3.3.1.12 SR 3.3.1.13

15. Departure From Nuc] pte Boiling 1,2 SR ->1.34 Ratio (DNBR) - Low SR SR SR SR SR SR SR SR SR SR (b) Trip may be bypassed when logarithmic power is shall be automatically removed when logarithmic power is Z IE-4% NRTP.

PALO VERDE UNITS 3.3.1-10 AMENDMENT NO. ;5, 158

RPS Instrumentation - Operating r 3.3 INSTRUMENTATION 3.3.1 Reactor Protective System (RPS) Instrumentation - Operating LCO 3.3.1 Four RPS trip and bypass removal channels for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1.A 1 ACTIONS

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

Separate Condition entry is allowed for each RPS Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one automatic RPS bypass or trip.

trip channel inoperable. AND A.2 Restore channel to Prior to OPERABLE status. entering MODE 2 following next MODE 5 entry B. One or more Functions B.1 Place one channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two automatic RPS bypass and the other 127*

trip channels in trip.

inoperable.

(continued)

PALO VERDE UNITS 1,2,3 PALO ERDEUNIT 1,23 AMEDMEN.NO.1-,1 AMENDMENT NO. 4-54, MIr

RPS Instrumentation - Operatingn ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Disable bypass 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one automatic channel.

bypass removal channel inoperable. OR C.2.1 Place affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass or trip.

AND C.2.2 Restore bypass Prior to removal channel and entering MODE 2 associated automatic following next trip channel to MODE 5 entry OPERABLE status.

D. One or more Functions with two automatic bypass removal channels inoperable.

D.1 Disable bypass channels.

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

OR D.2 Place one affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass and place the other in trip.

E. Required Action and E.1 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

(continued)

PALO VERDE UNITS 1,2,3 3. 3. 1-12 AMENDMENT NO. 4-F4, 1

RPS Instrumentation - Operatingn SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months instrument channel.

SR 3.3.1.2 NOTE--------------

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

Verify total Reactor Coolant System (RCS) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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.

SR 3.3.1.3 Check the CPC System Event Log. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

PALO VERDE UNITS 1.2.3 3.3.1-/ AMENDMENT NO.-I&G-3

RPS Instrumentation - OperatingQ SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 ---------------- 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 THERMAL POWER

Ž 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 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC AT power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is 2 2% when THERMAL POWER is Ž 80% RTP. Between 20%

and 80% RTP the maximum difference is -0.5%

to 10%.

SR 3.3.1.5 ---------------- 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.

Verify total RCS flow rate indicated by 31 days 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.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-/4 AMENDMENT NO. I3' H

RPS Instrumentation - Operatin '-- 3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.6 ---------------- 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 POWER > 15% RTP.

Verify linear power subchannel gains of the 31 days excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.

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 required 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 92 days channel.

SR 3.3.1.8 ---------------- NOTE --------------

Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION of the power 92 days range neutron flux channels.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-/5 AMENDMENT NO-IýWý

RPS Instrumentation - Operating SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.9 ---------------- NOTE---------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each 18 months channel, including bypass removal functions.

SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each 18 months CPC channel.

SR 3.3.1.11 Using the incore detectors, verify the Once after each shape annealing matrix elements to be used refueling prior by the CPCs. to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function. 92 days prior to each reactor startup SR 3.3.1.13 ---------------- NOTE --------------

Neutron detectors are excluded.

Verify RPS RESPONSE TIME is within limits. 18 months on a STAGGERED TEST BASIS PALO VERDE UNITS 1,2,3 3. 3. 1-A AMENDMENT NO.

RPS Instrumentation - Operating- ft-q . CDC Table 3.3.1-1 (page 1 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Variable Over Power 1.2 SR 3.31.1 Ceiling : 111.0% RTP SR 3.3.1.4 Band r 9.9% RTP SR 3.3.1.6 Incr. Rate : 11.0%/min RTP SR 3.3.1.7 Decr. Rate > 5%/sec RTP SR 3.3.1.8 SR 3.3.1.9 SR 3.3.1.13

2. Logarithmic Power Level - High(a) 2 SR 3.3.1.1 0.011% NRTP SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13

3. Pressurizer Pressure - High 1,2 SR 3.3.1.1

2388 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

4. Pressurizer Pressure - Low 1,2 SR 3.3.1.1 ? 1821 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13

5. Containment Pressure - High 1,2 SR 3.3.1.1

3.2 psig SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

6. Steam Generator #1 Pressure - Low 1.2 SR 3.3.1.1 SR 3.3.1.7 9190MWt RTP: Ž 955 psia(')

SR 3.3.1.9

.SR 3.3.1.13

7. Steam Generator #2 Pressure - Low 1,2 SR 3.3.1.1 SR 3.3.1.7 8 SR 3.3.1.9 3990 IlWt RTP: 2!9 psi a( ý SR 3.3.1.13 (conti nued)

(a) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be-automatically removed when logarithmic power is

1E-4% NRTP.

(aa) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint. or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3, 3.3. 1,4ý AMENDMENT NO. 4&G,

RPS Instrumentation - Operating e___

Table 3.3.1-1 (page 2 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

8. Steam Generator #1 Level - Low 1,2 SR 3.3.1.1 Ž 43.7%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

9. Steam Generator #2 Level - Low 1,2 SR 3.3.1.1 ' 43.7%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

10. Steam Generator #1 Level - High 1,2 SR 3.3.1.1 : 91.5%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

11. Steam Generator #2 Level - High 1.2 SR 3.3.1.1 ! 91.5%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

12. Reactor Coolant Flow, Steam 1.2 SR 3.3.1.1 Ramp: ! 0.115 psid/sec.

Generator #1-Low SR 3.3.1.7 Floor: Ž 12.49 psid SR 3.3.1.9 Step: ! 17.2 psid SR 3.3.1.13

13. Reactor Coolant Flow. Steam 1,2 SR 3.3.1.1 Ramp: ! 0.115 psid/sec.

Generator #2-Low SR 3.3.1.7 Floor: t 12.49 psid SR 3.3.1.9 Step: : 17.2 psid SR 3.3.1.13 (continued) ill---

PALO VERDE UNITS 1,2,3 3.3.1/8 AMENDMENT NO. 4&9-6

RPS Instrumentation - Operating Table 3.3.1-1 (page 3 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

14. Local Power Density - High(b) 1,2 SR 3.3.1.1

21.0 kW/ft SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3,3'1.7 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.11 SR 3.3.1.12 SR 3.3.1.13

15. Departure From Nuci gte Boiling 1,2 SR 3.3.1.1 1.34 Ratio (DNBR) - Low SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.11 SR 3.3.1.12 SR 3.3.1.13 (b) Trip may be bypassed when logarithmic power is < 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is Z 1E-4% NRTP.

PALO VERDE UNITS 1,2.3 3.3.1-/9 AMENDMENT NO. 4-59, 16&

q

RPS Instrumentation - Shutdown 3.3.2 Table 3.3.2-1 Reactor Protective System Instrumentation - Shutdown APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALVE

1. Logarithmic Power Level-High(d) 3 (a), 4 (a), 5 (a) SR 3.3.2.1 5 0.011% NRTP'c)

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.4 SR 3.3.2.5

2. Steam Generator #1 Pressure-Low(b) 3 (a) SR 3.3.2.1 SR 3.3.2.2 SR 3.3.2.4 3990 MWt RTPl: 955 ps*a* i SR 3.3.2.5

3. Steam Generator #2 Pressure-Low(b) 3 (a) SR 3.3.2.1 SR 3.3.2.2 3990MWt RTP: 955 psia SR 3.3.2.4 SR 3.3.2.5 (a) With any Reactor Trip Circuit Breakers (RTCBs) closed and any control element assembly capable of being withdrawn.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained 5 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The setpoint must be reduced to 5 1E-4% NRTP when less than 4 RCPs are running.

(d) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is : 1E-4% NRTP.

(e) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band. then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint. or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITTS 1 ND9.3 PALO VERDE UN Tý 3.3.2-5 AMENDMENT NO. 1g ~

CEACs (Before CPC Upgrade) 3.3.3 I 3.3 INSTRUMENTATION 3.3.3 Control Element Assembly Calculators (CEACs)

LCO 3.3.3 Two CEACs shall be OPERABLE.

APPLICABILITY: MODES 1 and 2. (Before CPC Upgrade)

I ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

/

A. One CEAC inoperable. A.1 Perform SR 3.1.5.1. 0'nce per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND A.2 Restore CEAC to 7 days OPERABLE status

/

//

/

B. Required Action and B.1 Verify thp/ departure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion from nucleate boiling Time of Condition A ratio r quirement of not met. LCO 3.-.4, "Departure from ucleate Boiling OR Rati (DNBR)," is me Both CEACs inoperable.

AND (continued)

PALO VERDE UNITS 1,2,3 3.3.3-1 AMENDMENT NO. 44-;ý. 150

CEACs (Before CPC Upgrade) 3.3.3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2 Verify all full ,/

strength and part /

length or part strength control element assembly

/

(CEA) groups are

/

fully withdrawn and maintained fully withdrawn, except during Surveillance /

testing pursuant to/ 4 hour4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months s/

SR 3.1.5.3 or for control, when CEA, group #5 may be /

inserted to a maximum of 127.5 inches withdrawn.

AND B.3 Verify the "RSPT/CEAC 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Inoperable" addressable constant in each core protection calculator (CPC) is set to i rdicate that both C£ACs are inoperable.

/

/C9erify the Control 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Element Drive

--I echanism Control System is placed in "STANDBY MODE" and maintained in "STANDBY MODE."

except during CEA motion permitted by Required Action B.2 AND B.5 Perform SR 3.1.5.1. Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND (continued)

PALO VERDE UNITS 1,2.3 3.3.3-2 AMENDMENT NO. 4W, 152

CEACs (Before CPC Upgrade) 3.3.3 I ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.6 Disable the Reactor 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Power Cutback System (RPCS)

C. Receipt of a CPC C.1 Perform CHANNEL 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months s/

channel B or C cabinet FUNCTIONAL TEST on high temperature affected CEAC(s).

alarm.

/

D. One or two CEACs with D.. Perform CHANNEL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months three 'or more auto FUNCTIONAL TEST on restarts during a affected CEAC.

12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months period.

E. Required Action and E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B.

C, or D not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL C 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.3.2 Check the CEAC uto restart count. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.3.3 Perform aHANNEL FUNCTIONAL TEST. 92 days (continued)

PALO VERDE UNITS 1.2.3 3.3.3-3 AMENDMENT NO. 114, 150

CEACs (Before CPC Upgrade) 3.3.3 I SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.3.4 Perform a CHANNEL CALIBRATION. 18 months SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. 18 months SR 3.3.3.6 Verify the isolation characteristics of 18 months each CEAC isolation amplifier.

//

PALO VERDE UNITS 1,2.3 3.3.3-4 AMENDMENT NO. 4-14, 150

CEACs 3.3 INSTRUMENTATION 3.3.3 Control Element Assembly Calculators (CEACs)

LCO 3.3.3 Two CEACs shall be OPERABLE in each CPC. channel APPLICABILITY: MODES l and 2.

ACTIONS

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

Separate condition entry is allowed for each CPC channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One CEAC inoperable in A.1 Declare the affected Immediately one or more CPC CPC channel(s) channels, inoperable.

OR A.2.1 Perform SR 3.1.5.1 Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND A.2.2 Restore CEAC to 7 days OPERABLE status.

B. Required Action and B.1 Declare the affected Immediately associated Completion CPC channel(s)

Time of Condition A inoperable.

not met.

OR OR Both CEACs inoperable in one or more CPC channels. (continued)

PALO VERDE UNITS 1,2,3 3. 3. 3 -.Re I AMENDMENT NO. tn'

CEACs ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) B.2.1 Verify the departure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from nucleate boiling ratio requirement of LCO 3.2.4, "Departure from Nucleate Boiling Ratio (DNBR)." is met.

AND B.2.2 Verify all full strengthýpalrff"*

<ý and strength control element assembly (CEA) groups are fully withdrawn and maintained fully withdrawn, except during Surveillance testing pursuant to SR 3.1.5.3 or for control, when CEA group #5 may be inserted to a maximum of 127.5 inches withdrawn.

AND B.2.3 Verify the "RSPT/CEAC 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Inoperable" addressable constant in each affected core protection calculator (CPC) is set to indicate that both CEACs are inoperable.

AND (continued)

PALO VERDE UNITS 1.2.3 AMENDMENT NO. 4-, 16-

CEACs ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B.2.4 Verify the Control 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Element Drive Mechanism Control System is placed in "STANDBY MODE" and maintained in "STANDBY MODE,"

except during CEA motion permitted by Required Action 8.2.2.

AND B.2.5 Perform SR 3.1.5.1. Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND B.2.6 Disable the Reactor 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Power Cutback System (RPCS)

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not met.

PALO VERDE UNITS 1,2,3 3.3.3-73 AMENDMENT NO. Isie-

CEACs SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.3.4 Perform a CHANNEL CALIBRATION. 18 months SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. 18 months PALO VERDE UNITS 1,2,3 3. 3. 3-/ý AMENDMENT NO. 48T-**

ESFAS Instrumentation 3.3.5 Table 3.3.5-1 (page I of 1)

Engineered Safety Features Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLOWABLE VALUE

1. Safety Injection Actuation Signal

a. Containment Pressure - Highb 1.2,3 3.2 psig

b. Pressurizer Pressure - Lowta) 3 1821 psia

2. Containment Spray Actuation Signal

a. Containment Pressure - High High 1.2.3 ! 8.9 psig

3. Containment Isolation Actuation Signal

a. Containment Pressure - High 1,2,3 : 3.2 psig

b. Pressurizer Pressure - Low(a) 2 1821 psia

4. Main Steam Isolation Signal(c)

a. Steam Generator #1 Pressure-Low(b) 1,2,3 P5

b. Steam Generator #2 Pressure-Low(b)

c. Steam Generator #1 Level-High

d. Steam Generator #2 Level-High

"-3990 iWt RTPý 955 5 sia

'-8990 MWt RTP: Ž 955 psia"'

! 91.5%

I

e. Containment Pressure-High ! 3.2 psig

5. Recirculation Actuation Signal

a. Refueling Water Storage Tank Level-Low 1,2.3 > 6.9 and S 7.9%

6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)

a. Steam Generator #1 Level-Low 1,2.3

25.3%

b. SG Pressure Difference-High 5 192 psid

7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)

a. Steam Generator #2 Level-Low 1,2.3 Ž 25.3%

b. SG Pressure Difference-High 5 192 psid (a) The setpoint may be decreased to a minimum value of 100 psia. as pressurizer pressure is reduced.

provided the margin between pressurizer pressure and the setpoint is maintained 5 400 psia or _ 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is

Ž 485°F. Trips may be bypassed when pressurizer pressure is < 400 psia. Bypass shall be automatically removed when pressurizer pressure is : 500 psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained 5 200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low. Steam Generator Level-High and Containment Pressure - High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed.

(d) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point: otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint, 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PA OVERDE UNITIS 1 AND 2 MNMN O 1= 5 PALO VERDE UNIT/ 3.3.5-4 AMENDMENT NO. 449, t, Z, 4.ft3

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 Figure 3.4.1-1, (Page I of 2)

Reactor Coolant Cold Leg Temperature vs. Core Power Leve 3876 MWt RTP

//

/ I 575 575 IL 570 570 565 565 560 560 555 555 550 550 545 - 545 540 - 540 I,L0 1 1 1/

10 20 3 1

40 50 1 1 60 70 1 1 80 90 1 -- ý 10 )

CORE POWER Bý %OF RArED THERMAL POWER (3876 MM) 0 PALO VERDE UNITS 1 AND 3 AMENDMENT NO. 4-;4, 157 PALO VERDE UNIT 2 3.4.1-3 AMENDMENT NO. 44-, 157

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 Figure 3.4.1-1. 6 Reactor Coolant Cold Leg Temperature vs. Core Power Level 3-9-9-- NA 575 575 iL M

Ur 570 565 570 565 560 560

{54 555 555 550 550 545 -

540 - 540

! ! I I I I II I I I I I I I I 10 20 30 40 50 60 70 80 90 100 CORE POWER LEVEL, % OF RATED THERMAL POWER (3990 MWI)

PALO VLKU UNITS I At)

PALO VERDE UNIT. JZ, 3 .4. 1-9' AMENDMENT NO, 4.4,

ECCS - Operating 3.5.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.3.7 Verify, for each ECCS throttle valve listed 18 months below, each position stop is in the correct position.

LPSI System Hot Leg Injection Valve Number Valve Numbers SIB-UV 615 SIC-HV 321 SIB-UV 625 SID-HV 331 SIA-UV 635 SIA-UV 645 SIA-HV 306 SIB-HV 307 SR 3.5.3.8 Verify, by visual inspection, each ECCS 18 months train containment sump suction inlet is not restricted by..ýis and the suction inlet

....... -14#4car.-- show no evidence of suctural or Abnormal a- corrosion.

PALO VERDE UNITS 1,2,3 3.5.3-3 AMENDMENT NO. 11;L

MSSVs 3.7.1 Table 3.7.1-1 (page 1 of 1)

Variable Overpower Trip Setpoint versus OPERABLE Main Steam Safety Valves MINIMUM NUMBER NUMBER OF MAXIMUM POWER MAXIMUM ALLOWABLE OF MSSVs PER INOPERABLE (% RTP) VARIABLE OVERPOWER TRIP STEAM GENERATOR MSSVs PER or HIGHEST MODE SETPOINT"8 )

REQUIRED STEAM (% RTP)

OPERABLE GENERATOR 399t-Mwt a 390 -Mt 10 0 100.0 100.0 111.0 111.0 9 108.7 99.0.0 98.7 8.8.07 89.7 91 68.0.277 6 4 6 . 56. 7. 65.7 5 5 *, OE3 [ / A\NA 4 6 ODE3 MODE3 NA NA 3 7 MODE 3 MODE3 NA NA 2 8 MODE 3 MODE 3 NA NA (a) The VOPT setpoint is not required to be reset in MODE 3.

PALO VERDE UNITS 1, 2 AND 3 3.7.1-4 AMENDMENT NO.

Procedures (Before CPCS Upgrade) 5.4 I

5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and, maintained covering the following activities:

a. The applicable procedures recommended in Reguldtory Guide 1.33, Revision 2, Appendix A, February.1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33:

c. Quality assurance for effluent and environmental monitoring:

d. Fire Protection Program implementation: and

e. All programs specified in Sp ificationi 5.5.

f. Modification of core prot tion calculator (CPC) addressable constants. These proced es shall include provisions to ensure that sufficient argin is maintained in CPC type I addressable constants o avoid excessive operator interaction with CPC during reactor operation.

Modifications to e CPC software (including changes of algorithms and f el cycle specific data) shall be performed in accordance th the most recent version of "CPC Protection Al orithm Software Change Procedure,"

CEN-39(A)-P. which has been determined to be applicable to the facili . Additions or deletions to CPC addressable constan or changes to addressable constant software limit valu all ,not be implemented without prior NRC approval.

PALO VERDE UNITS 1,2,3 5.4-1 AMENDMENT NO. 4-2-9. 150

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation; and

e. 'All programs specified in Specification 5.5.

f. Modification of core protection calculator (CPC) addressable constants. These procedures shall include provisions to ensure that sufficient margin is maintained in CPC type I addressable constants to avoid excessive operator interaction with CPCs during reactor operation.

Modifications to the CPC software (including changes of algorithms and fuel cycle specific data) shall be performed in accordance with the most recent version of the Software Program Manual for Common Q Systems", CE-CES-195. which has been determined to be applicable to the facility. Additions or deletions to CPC addressable constants or changes to addressable constant software limit values shall not be implemented without prior NRC approval.

PALO VERDE UNITS 1,2,3 5.4-2/i AMENDMENT NO. 16-

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program (continued) shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.5 gpm per SG and 1 gpm through both SGs.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.14, "RCS Operational LEAKAGE."

c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. Inad ition to meeting the requirements of d.1, d. and d.3 below, the inspection scope, inspection methods, an inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG re, lacement.

(conti nued)

PALO VERDE UNITS 1,2,3 5.5-7 AMENDMENT NO. 4-2-4, 161

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program

=

(continued) 2)(

the tubes afsquentia1 periods o7144, 108,Inspect j_______ 100% of 72, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

(continued)

PALO VERDE UNITS 1,2.3 5.5-8 AMENDMENT NO. 4.2-4 +6+/--

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1. Shutdown Margin - Reactor Trip Breakers Open for Specification 3.1.1.

2. Shutdown Margin - Reactor Trip Breakers Closed for Specification 3.1.2.

3. Moderator Temperature Coefficient BOL and EOL limits for Specification 3.1.4.

4. Boron Dilution Alarm System for Specification 3.3.12.

5. CEA Alignment for Specification 3.1.5.

6. Regulating CEA Insertion Limits for Specification 3.1.7.

7. -Part Strength CEA Insertion Limits for Sp e-cl- -i-ca-tero3. 1 .8.

8. Linear Heat Rate for Specification 3.2.1.

9. Azimuthal Power Tilt - Tq for Specification 3.2.3.

10. DNBR for Specification 3.2.4.

11. Axial Shape Index for Specification 3.2.5.

12. Boron Concentration (Mode 6) for Specification 3.9.1.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

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

The COLR will contain the complete identification for each of the Technical Specification referenced topical reports used to prepare the COLR (i.e., report number, title, revision, date, and any supplements).

(continued)

PALO VERDE UNITS 1.2,3 5.6-3 AMENDMENT NO. 4--, i5ý

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR) (continued)

1. "CE Method for Control Element Assembly Ejection Analysis," CENPD-0190-A, (Methodology for Specification 3.1.7, Regulating CEA Insertion Limits).

2. "The ROCS and DIT Computer Codes for Nuclear Design,"

CENPD-266-P-A, [Methodology for Specifications 3.1.1, Shutdown Margin - Reactor Trip Breakers Open; 3.1.2, Shutdown Margin - Reactor Trip Breakers Closed: 3.1.4, Moderator Temperature Coefficient BOL and EOL limits; 3.1.7, Regulating CEA Insertion Limits and 3.9.1, Boron Concentration (Mode 6)].

3. "Safety Evaluation Report related to the Final Design of the Standard Nuclear Steam Supply Reference Systems CESSAR System 80, Docket No. STN 50-470, "NUREG-0852 (November 1981), Supplements No. 1 (March 1983), No. 2 (September 1983). No. 3 (December 1987) [Methodology for Specifications 3.1.2, Shutdown Margin - Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient BOL and EOL limits; 3.3.12, Boron Dilution Alarm System: 3.1.5, CEA Alig ent: 3.1.7, Regulating CEA Insertion Limits; 3.1.8, Part Strength CEA Insertion Limits and 3.2.3, Azimuthal Power Tilt - Tq].

4. "Modified Statistical Combination of Uncertainties,"

CEN-356(V)-P-A and "System 80TM Inlet Flow Distribution,"

Supplement 1-P to Enclosure 1-P to LD-82-054, (Methodology for Specification 3.2.4. DNBR and 3.2.5 Axial Shape Index).

5. "Calculative Methods for the CE Large Break LOCA Evaluation Model," CENPD-132, (Methodology for Specification 3.2.1, Linear Heat Rate).

6. "Calculative Methods for the CE Small Break LOCA Evaluation Model," CENPD-137-P, (Methodology for Specification 3.2.1, Linear Heat Rate).

(continued)

PALO VERDE UNITS 1,2.3 5.6-4 AMENDMENT NO. , .-.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 Core Operating Limits Report (COLR) (continued)

7. Letter: O.D. Parr (NRC) to F. M. Stern (CE). dated June 13, 1975 (NRC Staff Review of the Combustion Engineering 5..5.b.6. ECCS Evaluation Model). NRC approval for:

B. Letter: K. Kniel (NRC) to A. E. Scherer (CE), dated September 27, 1977 (Evaluation of Topical Reports CENPD-133, Supplement 3-P and CENPD-137. Supplement 1-P). NRC approval for 5.6.5.b.6.

9. "Fuel Rod Maximum Allowable Pressure," CEN-372-P-A, (Methodology for Specification 3.2.1, Linear Heat Rate).

10. Letter: A. C. Thadani (NRC) to A. E. Scherer (CE),

dated April 10, 1990, ("Acceptance for Reference CE Topical Report CEN-372-P"). NRC approval for 5.6.5.b.9.

11. "Arizona Public Service Company PWR Reactor Physics Methodology. Using CASMO-4/SIMULATE-3," [Methodology for Specifications 3.1.1, Shutdown Margin - Reactor Trip Breakers Open: 3.1.2. Shutdown Margin - Reactor Trip Breakers Closed: 3.1.4, Moderator Temperature Coefficient; 3.1.7, Regulating CEA Insertion Limits and 3.9.1, Boron Concentration (Mode 6)].

12. "Technical Manual for the CENTS Code," CE-NPD 282-P-A, Volumes 1-3, [Methodology for Specifications 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient; 3.1.5. CEA Ajignment; 3.1.7, Regulating CEA Insertion Limits; 3.1.8,.

Pa Part Strength CEA Insertion Limits and3 .2.3, qzTlmuthý Power Tilt- Tq].

13. CENPD-404-P-A, "Implementation of ZIRLO TM Cladding Material in CE Nuclear Power Fuel Assembly Designs.

14. CENPD-188-A, "HERMITE, A Multi-Dimensional Space-Time Kinetics Code for PWR Transients." [Methodology for Specifications 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed: 3.1.4, Moderator Temperature Coefficient: 3.2.1, Linear Heat Rate: 3.2.3, Azimuthal Power Tilt: 3.2.4., DNBR; and 3.2.5, Axial Shape Index.]

15. CENPD-161-P-A, "TORC Code, A Computer Code for Determining the Thermal Margin of a Reactor Core."

[Methodology for Specifications 3.1.1, Shutdown Margin-Reactor Trip Breakers Open: 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed: 3.1.4, Moderator Temperature Coefficient: 3.2.1, Linear Heat (continued)

PALO VERDE UNITS 1.2,3 5.6-5 AMENDMENT NO. ;--52.1-,-4-,

Attachment 2 Proposed Technical Specification Changes (retyped)

TS TOC Page i Page 1.1-6 Page 3.1.5-1 Page 3.1.5-3 Page 3.1.8-1 Page 3.1.8-2 Page 3.1.10-1 Page 3.1.11-1 Page 3.2.4-1 Page 3.2.4-2 Page 3.3.1-1 Page 3.3.1-2 Page 3.3.1-3 Page 3.3.1-4 Page 3.3.1-5 Page 3.3.1-6 Page 3.3.1-7 Page 3.3.1-8 Page 3.3.1-9 Page 3.3.2-5 Page 3.3.3-1 Page 3.3.3-2 Page 3.3.3-3 Page 3.3.3-4 Page 3.3.5-4 Page 3.4.1-3 Page 3.5.3-3 Page 3.7.1-4 Page 5.4-1 Page 5.5-7 Page 5.5-8 Page 5.6-3 Page 5.6-4 Page 5.6-5

PALO VERDE NUCLEAR GENERATING STATION IMPROVED TECHNICAL SPECIFICATIONS TABLE OF CONTENTS 1.0 USE AND APPLICATION 1.1 Definitions 1.2 Logical Connectors 1.3 Completion Times 1.4 Frequency 2.0 SAFETY LIMITS (SLs) 2.1 SLs 2.2 SL Violations 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY 3.1 REACTIVITY CONTROL SYSTEMS 3.1.1 SHUTDOWN MARGIN (SDM) -- Reactor Trip Breakers Open 3.1.2 SHUTDOWN MARGIN (SDM) -- Reactor Trip Breakers Closed 3.1.3 Reactivity Balance 3.1.4 Moderator Temperature Coefficient (MTC) 3.1.5 Control Element Assembly (CEA) Alignment 3.1.6 Shutdown CEA Insertion Limits 3.1.7 Regulating CEA Insertion Limits 3.1.8 Part Strength CEA Insertion Limits 3.1.9 Special Test Exception (STE) -- SHUTDOWN MARGIN (SDM) 3.1.10 STE -- MODES 1 and 2 3.1.11 STE -- Reactivity Coefficient Testing 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Linear Heat Rate (LHR) 3.2.2 Planar Radial Peaking Factors (Fxy) 3.2.3 Azimuthal Power Tilt (Tq) 3.2.4 Departure From Nucleate Boiling Ratio (DNBR) 3.2.5 Axial Shape Index (ASI) 1,2,3 i AMENDMENT NO. 15.2, PALO VERDE UNITS UNITS 1,2,3 j AMENDMENT NO. 4-ý;,

Definitions 1.1 1.1 Definitions (continued)

RATED THERMAL POWER RTP shall be a total reactor core heat transfer (RTP) rate to the reactor coolant of 3990 MWt.

REACTOR PROTECTIVE The RPS RESPONSE TIME shall be that time interval SYSTEM (RPS) RESPONSE from when the monitored parameter exceeds its RPS TIME trip setpoint at the channel sensor until electrical power to the CEAs drive mechanism is interrupted. The response time may be measured by means of any series of sequential, overlapping, or total steps so that the entire response time is measured. In lieu of measurement, response time may be verified for selected components provided that the components and methodology for verification have been previously reviewed and approved by the NRC.

SHUTDOWN MARGIN (SDM) SDM shall be the instantaneous amount of reactivity by which the reactor is subcritical or would be subcritical from its present condition assuming:

a. All full strength CEAs (shutdown and regulating) are fully inserted except for the single CEA of highest reactivity worth, which is assumed to be fully withdrawn. With any full strength CEAs not capable of being fully inserted, the withdrawn reactivity worth of these CEAs must be accounted for in the determination of SDM and

b. There is no change in part strength CEA position.

PALO VERDE UNITS 1,2,3 1.1-6 AMENDMENT NO. 415-ý,

CEA Alignment 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Control Element Assembly (CEA) Alignment LCO 3.1.5 All full strength CEAs shall be OPERABLE, and all full strength and part strength CEAs shall be aligned to within 6.6 inches (indicated position) of all other CEAs in their respective groups.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more CEAs A.1 Reduce THERMAL POWER 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months trippable and in accordance with misaligned from its the limits in the group by > 6.6 inches COLR.

and

9.9 inches.

AND OR OR A.2 Restore CEA 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months One CEA trippable and alignment.

misaligned from its group by > 9.9 inches.

(continued)

PALO VERDE UNITS 1,2,3 3.1.5-1 AMENDMENT NO. 4-521,

CEA Alignment 3.1.5 SURVEILLANCE REQUIREMENTS ._-..__

SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify the indicated position of each full 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months strength and part strength CEA is within 6.6 inches of all other CEAs in its group.

SR 3.1.5.2 Verify that, for each CEA, its OPERABLE CEA 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months position indicator channels indicate within 5.2 inches of each other.

SR 3.1.5.3 Verify full strength CEA freedom of 92 days movement (trippability) by moving each individual full strength CEA that is not fully inserted in the core at least 5 inches.

SR 3.1.5.4 Perform a CHANNEL FUNCTIONAL TEST of each 18 months reed switch position transmitter channel.

SR 3.1.5.5 Verify each full strength CEA drop time Prior to 4.0 seconds. reactor criticality, after each removal of the reactor head PALO VERDE UNITS 1,2,3 3.1.5-3 AMENDMENT NO. 4-52-,

Part Strength CEA Insertion Limits 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 Part Strength Control Element Assembly (CEA) Insertion Limits LCO 3.1.8 The part strength CEA groups shall be limited to the insertion limits specified in the COLR.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Part strength CEA A.1 Restore part strength 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months groups inserted beyond CEA groups to within the transient the limit.

insertion limit.

OR A.2 Reduce THERMAL POWER 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to less than or equal to that fraction of RTP specified in the COLR.

B. Part strength CEA B.1 Restore part strength 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months groups inserted CEA groups to within between the long term the long term steady

.steady state insertion state insertion limit.

limit and the transient insertion limit for intervals

Ž 7 effective full power days (EFPD) per 30 EFPD or Ž 14 EFPD per 365 EFPD interval.

(continued)

PALO VERDE UNITS 1,2,3 3.1.8-1 AMENDMENT NO. 4-52,

Part Strength CEA Insertion Limits 3.1.8 ACTIONS (continued) .

CONDITION REQUIRED-ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Verify part strength CEA group position. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months PALO VERDE UNITS 1,2,3 3.1.8-2 AMENDMENT NO. 4-52-,

STE - MODES 1 and 2 3.1.10 3.1 REACTIVITY CONTROL SYSTEMS 3.1.10 Special Test Exceptions (STE) - MODES 1 and 2 LCO 3.1.10 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1.4, "Moderator Temperature Coefficient (MTC)";

LCO 3.1.5, "Control Element Assembly (CEA) Alignment":

LCO 3.1.6, "Shutdown Control Element Assembly (CEA)

Insertion Limits";

LCO 3.1.7, "Regulating Control Element Assembly (CEA)

Insertion Limits";

LCO 3.1.8, "Part Strength CEA Insertion Limits";

LCO 3.2.2, "Planar Radial Peaking Factors (Fxy)";

LCO 3.2.3, "AZIMUTHAL POWER TILT (Tq)";

LCO 3.2.5, "AXIAL SHAPE INDEX (ASI)"; and LCO 3.3.3, "Control Element Assembly Calculators (CEACs)"

may be suspended, provided:

a. THERMAL POWER is restricted to the test power plateau, which shall not exceed 85% RTP: and

b. Shutdown reactivity equivalent to at least the highest estimated CEA worth (of those CEAs actually withdrawn) is available for trip insertion.

APPLICABILITY: MODES 1 and 2 during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Test power plateau A.1 Reduce THERMAL POWER 15 minutes exceeded. to less than or equal to the test power plateau.

B. Required Action and B.1 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion TESTS.

Time not met.

PALO VERDE UNITS 1,2,3 3.1.10-1 AMENDMENT NO. 441ý9

STE - Reactivity Coefficient Testing 3.1.11 3.1 REACTIVITY CONTROL SYSTEMS 3.1.11 Special Test Exceptions (STE) - Reactivity Coefficient Testing LCO 3.1.11 During performance of PHYSICS TESTS, the requirements of:

LCO 3.1. 7, "Regulating Control Element Assembly (CEA)

Insertion Limits";

LCO 3.1. 8, "Part Strength Control Element Assembly (CEA)

Insertion Limits;" and LCO 3.4.1, "RCS Pressure, Temperature and Flow limits" (LCO 3.4.1.b, RCS Cold Leg Temperature only) may be suspended, provided LHR and DNBR do not exceed the limits in the COLR.

APPLICABILITY: MODE 1 with Thermal Power > 20% RTP during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LHR or DNBR outside A.1 Reduce THERMAL POWER 15 minutes the limits specified to restore LHR and in the COLR. DNBR to within limits.

B. Required Action and B.1 Suspend PHYSICS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion TESTS.

Time not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.11.1 Verify LHR and DNBR do not exceed limits by Continuously performing SR 3.2.1.1 and SR 3.2.4.1.

PALO VERDE UNITS 1,2,3 3.1.11-1 AMENDMENT NO.

DNBR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 Departure From Nucleate Boiling Ratio (DNBR)

LCO 3.2.4 The DNBR shall be maintained by one of the following methods:

a. Core Operating Limit Supervisory System (COLSS) In Service:

1. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR when at least one Control Element Assembly Calculator (CEAC) is OPERABLE in each OPERABLE Core Protection Calculator (CPC) channel; or

2. Maintaining COLSS calculated core power less than or equal to COLSS calculated core power operating limit based on DNBR decreased by the allowance specified in the COLR when the CEAC requirements of LCO 3.2.4.a.1 are not met.

b. COLSS Out of Service:

1. Operating within the region of acceptable operation specified in the COLR using any OPERABLE Core Protection Calculator (CPC) channel when at least one Control Element Assembly Calculator (CEAC) is OPERABLE in each OPERABLE CPC channel; or

2. Operating within the region'of acceptable operation specified in the COLR using any OPERABLE CPC channel (with both CEACs inoperable) when the CEAC requirements of LCO 3.2.4.b.1 are not met.

APPLICABILITY: MODE 1 with THERMAL POWER > 20% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. COLSS calculated core A.1 Restore the DNBR to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months power not within within limit.

limit.

(conti nued)

PALO VERDE UNITS 1,2,3 3.2.4-1 AMENDMENT NO. 44G,

DNBR 3.2.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. DNBR outside the B.1 Determine trend in DNBR. Once per region of acceptable AND 15 minutes operation when COLSS is out of service. B.2.1 With an adverse trend, restore DNBR 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to within limit.

OR B.2.2 With no adverse 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months trend, restore DNBR to within limit.

C. Required Action and C.1 Reduce THERMAL POWER 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion to

20% RTP.

Time not met.

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 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 with THERMAL POWER > 20% RTP.

Verify DNBR, as indicated on any OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months DNBR channels, is within the limit of the COLR, as applicable.

SR 3.2.4.2 Verify COLSS margin alarm actuates at a 31 days THERMAL POWER level equal to or less than the core power operating limit. based on DNBR.

PALO VERDE UNITS 1,2,3 3.2.4-2 AMENDMENT NO. 4-59,

RPS Instrumentation - Operating 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Protective System (RPS) Instrumentation - Operating LCO 3.3.1 Four RPS trip and bypass removal channels for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to table 3.3.1-1.

ACTIONS

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

Separate Condition entry is allowed for each RPS Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions A.1 Place channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one automatic RPS bypass or trip.

trip channel inoperable. AND A.2 Restore channel to Prior to OPERABLE status. entering MODE 2 following next MODE 5 entry B. One or more Functions B.1 Place one channel in 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two automatic RPS bypass and the other trip channels in trip.

inoperable.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-1 AMENDMENT NO. 4-6-5,

RPS Instrumentation - Operating 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Disable bypass 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with one automatic channel.

bypass removal channel inoperable. OR C.2.1 Place affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass or trip.

AND C.2.2 Restore bypass Prior to removal channel and entering MODE 2 associated automatic following next trip channel to MODE 5 entry.

OPERABLE status.

D. One or more Functions D.1 Disable bypass 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months with two automatic channels.

bypass removal channels inoperable.

OR D.2 Placeone affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months automatic trip channel in bypass and place the other in trip.

E. Required Action and E.1 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-2 AMENDMENT NO. 445.

RPS Instrumentation - Operating 3.3.1 SURVEILLANCE REQUIREMENTS

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

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

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform a CHANNEL CHECK of each RPS 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months instrument channel.

SR 3.3.1.2 -----------------NOTE--------------

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

Verify total Reactor Coolant System (RCS) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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.

SR 3.3.1.3 Check the CPC System Event Log. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

PALO VERDE UNITS 1,2,3 3.3.1-3 AMENDMENT NO. 4-&G,

RPS Instrumentation - Operating 3.3.1 SURVEILLANCE REQUIREMENTS (contihued)

SURVEILLANCE FREQUENCY SR 3.3.1.4 ----------------- 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 THERMAL POWER

Ž 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 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months adjust the linear power level signals and the CPC addressable constant multipliers to make the CPC AT power and CPC nuclear power calculations agree with the calorimetric, if the absolute difference is Ž 2%when THERMAL POWER is . 80% RTP. Between 20%

and 80% RTP the maximum difference is -0.5%

to 10%.

SR 3.3.1.5 ----------------- 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 Ž 70% RTP.

Verify total RCS flow rate indicated.by 31 days 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.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-4 AMENDMENT NO.

RPS Instrumentation - Operating 3.3.1 SURVEILLANCE REQUIREMENTS (contihded)

SURVEILLANCE FREQUENCY SR 3.3.1.6 ----------------- 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 POWER Ž 15% RTP.

Verify linear power subchannel gains of the 31 days excore detectors are consistent with the values used to establish the shape annealing matrix elements in the CPCs.

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 required 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 92 days channel.

SR 3.3.1.8 -----------------NOTE---------------

Neutron detectors are excluded from the CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION of the power 92 days range neutron flux channels.

(continued)

PALO VERDE UNITS 1,2,3 3.3.1-5 AMENDMENT NO. -144,

RPS Instrumentation - Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued).

SURVEILLANCE FREQUENCY SR 3.3.1.9 ----------------- NOTE--------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION on each 18 months channel, including bypass removal functions.

SR 3.3.1.10 Perform a CHANNEL FUNCTIONAL TEST on each 18 months CPC channel.

SR 3.3.1.11 Using the incore detectors, verify the Once after each shape annealing matrix elements to be used refueling prior by the CPCs. to exceeding 70% RTP SR 3.3.1.12 Perform a CHANNEL FUNCTIONAL TEST on each Once within automatic bypass removal function. 92 days prior to each reactor startup SR 3.3.1.13 ----------------- NOTE--------------

Neutron detectors are excluded.

Verify RPS RESPONSE TIME is within limits. 18 months on a STAGGERED TEST BASIS PALO VERDE UNITS 1,2,3 3.3.1-6 AMENDMENT NO. 4-54,

RPS Instrumentation Operating 3.3.1 Table 3.3.1-1 (page 1 of 3)

Reactor Protective System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

1. Variable Over Power 1,2 SR 3.3,1.1 Ceiling

111.0% RTP SR 3.3,1.4 Band

9.9% RTP SR 3.3.1.6 Incr. Rate

11.0%/min RTP SR 3.3.1.7 Decr, Rate > 5%/sec RTP SR 3.3.1.8 SR 3.3.1.9 SR.3.3.1.13 2, Logarithmic Power Level - High(a) 2 SR 3.3.1.1 ! 0.011% NRTP SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 33.1.13

3. Pressurizer Pressure - High 1,2 SR 3.3.1.1 ! 2388 psia SR 3,3.1.7 SR 3.3.1.9 SR 3.3.1.13

4. Pressurizer Pressure - Low 1,2 SR 3.3.1,1 B121 psia SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.12 SR 3.3.1.13

5. Containment Pressure - High 1,2 SR 3.3.1.1

3.2 psig SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

6. Steam Generator #1 Pressure Low 1,2 SR 3.3,1.1 3990 MWt RTP: Ž 955 psia(

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

7. Steam Generator #2 Pressure Low 1.2 SR 3.3.1.1 3990 MWt RTP: ( 955 psiane)

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13 (continued)

(a) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is

1E-4% NRTP.

(aa) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service, If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint. 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNITS 1,2,3 3.3.1-7 AMENDMENT NO. 415-ý,

RPS Instrumentation - Operating 3.3.1 Table 3.3.1-i ýp6g6.2 of 3)

Reactor Protective System ihstrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

8. Steam Generator #1 Level - Low 1,2 SR 3.3.1.1 > 43.7%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

9. Steam Generator #2 Level - Low 1,2 SR 3.3.1.1 > 43.7%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

10. Steam Generator #1 Level - High 1,2 SR 3.3.1.1 < 91.5%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

11. Steam Generator #2 Level - High 1.2 SR 3.3.1.1 < 91.5%

SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.13

12. Reactor Coolant Flow, Steam 1.2 SR 3.3.1.1 Ramp: ! 0.115 psid/sec.

Generator #1-Low SR 3.3.1.7 Floor: Ž 12.49 psid SR 3.3.1.9 Step: S 17.2 psid SR 3.3.1.13

13. Reactor Coolant Flow, Steam 1,2 SR 3.3.1.1 Ramp:

0.115 psid/sec.

Generator #2-Low SR 3.3.1.7 Floor: Ž 12.49 psid SR 3.3.1.9 Step:

17.2 psid SR 3.3.1.13 (continued)

PALO VERDE UNITS 1,2,3 3.3.1-8 AMENDMENT NO. 4-54,

RPS Instrumentation Operating 3.3.1 Table 3.3:1-1 (page.3 of 3)

Reactor Protective Sýstem Ihstrumentation APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALUE

14. Local Power Density - High(b) 1,2 SR 3.3.1.1 < 21.0 kW/ft SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.,1.11 SR 3.3.1.12 SR 3,3.1.13

15. Departure From Nucleate Boiling 1.2 SR 3.3.1.1 > 1.34 Ratio (DNBR) - Low(b) SR 3.3.1.2 SR 3,3.1.3 SR 3.3.1.4 SR 3.3.1.5 SR 3.3.1.7 SR 3.3.1.9 SR 3.3.1.10 SR 3.3.1.11 SR 3.3.1.12 SR 3.3.1.13 (b) Trip may be bypassed when logarithmic power is < IE-4% NRTP. Bypass shall be automatically removed when logarithmic power is Ž 1E-4% NRTP.

PALO VERDE UNITS 1,2,3 3.3.1-9 AMENDMENT NO. W

RPS Instrumentation - Shutdown 3.3.2 Table 3.3.2-1 Reactor Protective System Instrumentation - Shutdown APPLICABLE MODES OR OTHER SPECIFIED SURVEILLANCE FUNCTION CONDITIONS REQUIREMENTS ALLOWABLE VALVE

1. Logarithmic Power Level-High(d) 3 (a), 4 (a), 5 (a) SR 3.3.2.1 00,011% NRTP(c)

SR 3.3.2.2 SR 3.3.2.3 SR 3.3.2.4 SR 3.3.2.5

2. Steam Generator #1 Pressure-Low(b) 3 (a) SR 3.3.2.1 3990 MWt RTP: Ž 955 psia e)

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2.5

3. Steam Generator #2 Pressure-Low(b) 3(a) SR 3.3.2.1 3990 MWt RTP: Ž 955 psia~e)

SR 3.3.2.2 SR 3.3.2.4 SR 3.3.2,5 (a) With any Reactor Trip Circuit Breakers (RTCBs) closed and any control element assembly capable of being withdrawn.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The setpoint must be reduced to

1E-4% NRTP when less than 4 RCPs are running.

(d) Trip may be bypassed when logarithmic power is > 1E-4% NRTP. Bypass shall be automatically removed when logarithmic power is

IE-4% NRTP.

(e) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint, 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNIT 1,2,3 3.3.2-5 AMENDMENT NO. ;4-4.

CEACs 3.3.3 3.3 INSTRUMENTATION 3.3.3 Control Element Assembly Calculators (CEACs)

LCO 3.3.3 Two CEACs shall be OPERABLE in each CPC channel APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate condition entry is allowed for each CPC channel.

CONDITION REQUIRED ACTION COMPLETION TIME A. One CEAC inoperable in A.1 Declare the affected Immediately one or more CPC CPC channel(s) channels. inoperable.

OR A.2.1 Perform SR 3.1.5.1 Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND A.2.2 Restore CEAC to 7 days OPERABLE status.

B. Required Action and B.1 Declare the affected Immediately associated Completion CPC channel(s)

Time of Condition A inoperable.

not met.

OR OR Both CEACs inoperable in one or more CPC (continued) channels.

PALO VERDE UNITS 1,2,3 3.3.3-1 AMENDMENT NO. 4-54,

CEACs 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B (continued) B.2.1 Verify the departure 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from nucleate boiling ratio requirement of LCO 3.2.4, "Departure from Nucleate Boiling Ratio (DNBR)," is met.

AND B.2.2 Verify all full strength and part strength control element assembly (CEA) groups are fully withdrawn and maintained fully withdrawn, except during Surveillance testing pursuant to SR 3.1.5.3 or for control, when CEA group #5 may be inserted to a maximum of 127.5 inches withdrawn.

AND B.2.3 Verify the "RSPT/CEAC 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Inoperable" addressable constant in each affected core protection calculator (CPC) is set to indicate that both CEACs are inoperable.

AND (continued)

PALO VERDE UNITS 1,2,3 3.3.3-2 AMENDMENT NO. 4-5-ý,

CEACs 3.3.3 ACTIONS (continued) I.:- : .. 1.....

CONDITION REQUIRED ACTION COMPLETION TIME B.2.4 Verify the Control 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Element Drive Mechanism Control System is placed in "STANDBY MODE" and maintained in "STANDBY MODE,"

except during CEA motion permitted by Required Action B.2.2.

AND B.2.5 Perform SR 3.1.5.1. Once per 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months AND B.2.6 Disable the Reactor 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Power Cutback System (RPCS)

C. Required Action and C.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition B not met.

PALO VERDE UNITS 1,2,3 3.3.3-3 AMENDMENT NO. 4-&G,

CEACs 3.3.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform a CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.3.2 Deleted SR 3.3.3.3 Perform a CHANNEL FUNCTIONAL TEST. 92 days SR 3.3.3.4 Perform a CHANNEL CALIBRATION. 18 months SR 3.3.3.5 Perform a CHANNEL FUNCTIONAL TEST. 18 months PALO VERDE UNITS 1,2,3 3.3.3-4 AMENDMENT NO.

ESFAS Instrumentation 3.3,5 Table 3:3.5:1 (p00 ,1of 1)

Engineered Safety Features"Actuatidn System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED FUNCTION CONDITIONS ALLOWABLE VALUE

1. Safety Injection Actuation Signal

a. Containment Pressure - High 1.2.3

3.2 psig

b. Pressurizer Pressure - Low(a) > 1821 psia

2. Containment Spray Actuation Signal

a. Containment Pressure - High High 1,2,3 B.9 psig 8

3. Containment Isolation Actuation Signal

a. Containment Pressure - High 1,2,3 s 3.2 psig

b. Pressurizer Pressure - Low(a) Ž 1821 psia

4. Main-Steam Isolation Signal(c)

a. Steam Generator #1 Pressure-Low(b) .1,2,3 3990 MWt RTP: Ž 955 psi a('d

b. Steam Generator #2 Pressure-Low(b) 3990 MWt RTP: Ž 955 psiac

c. Steam Generator #1 Level-High ! 91.5%

d. Steam Generator #2 Level-High < 91.5%

e. Containment Pressure-High < 3.2 psig

5. Recirculation Actuation Signal

a. Refueling Water Storage Tank Level-Low 1,2,3 > 6.9 and

7.9%

6. Auxiliary Feedwater Actuation Signal SG #1 (AFAS-1)

a. Steam Generator #1 Level-Low 1,2,3 Ž 25.3%

b. SG Pressure Difference-High

192 psid

7. Auxiliary Feedwater Actuation Signal SG #2 (AFAS-2)

a. Steam Generator #2 Level-Low 1,2,3 Ž 25.3%

b. SG Pressure Difference-High

192 psid (a) The setpoint may be decreased to a minimum value of 100 psia, as pressurizer pressure is reduced, provided the margin between pressurizer pressure and the setpoint is maintained

400 psia or Ž 140 psia greater than the saturation pressure of the RCS cold leg when the RCS cold leg temperature is

Ž 485°F. Trips may be bypassed when pressurizer pressure is < 400 psia. Bypass shall be automatically removed when pressurizer pressure is Ž 500 psia. The setpoint shall be automatically increased to the normal setpoint as pressurizer pressure is increased.

(b) The setpoint may be decreased as steam pressure is reduced, provided the margin between steam pressure and the setpoint is maintained

200 psig. The setpoint shall be automatically increased to the normal setpoint as steam pressure is increased.

(c) The Main Steam Isolation Signal (MSIS) Function (Steam Generator Pressure - Low, Steam Generator Level-High and Containment Pressure - High signals) is not required to be OPERABLE when all associated valves isolated by the MSIS Function are closed.

(d) 1. If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predetermined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning as required before returning the channel to service. If the as-found instrument channel setpoint is not conservative with respect to the Allowable Value, the channel shall be declared inoperable.

2. The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the UFSAR Trip Setpoint, or within the as left tolerance of a setpoint that is more conservative than the UFSAR Trip Set Point; otherwise the channel shall be declared inoperable. The UFSAR Trip Setpoint and the methodology used to determine 1) the UFSAR Trip Setpoint, 2) the predetermined as found acceptance criteria band, and 3) the as-left setpoint tolerance band are specified in the UFSAR.

PALO VERDE UNIT 1,2,3 3.3.5-4 AMENDMENT NO,

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 Figure 3.4.1-1 Reactor Coolant Cold Leg Temperature vs. Core Power Level 575 575 U.

0 570 570 565 565 560 560 UJ I-555 555 550 550 545 _ -- 545 540 -

z7 I I I I I I I I I 0 10 20 30 40 50 60 70 80 90 100 CORE POWER LEVEL, % OF RATED THERMAL POWER (3990 MWt)

PALO VERDE UNIT 1,2,3 3.4.1-3 AMENDMENT NO. 4-54.

ECCS - Operating 315.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY

+

SR 3.5.3.7 Verify, for each ECCS throttle valve listed 18 months below, each position stop is in the correct position.

LPSI System Hot Leg Injection Valve Number Valve Numbers SIB-UV 615 SIC-HV 321 SIB-UV 625 SID-HV 331 SIA-UV 635 SIA-UV 645 SIA-HV 306 SIB-HV 307 SR 3.5.3.8 Verify, by visual inspection, each ECCS 18 months train containment sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.

PALO VERDE UNITS 1,2,3 3.5.3-3 AMENDMENT NO. ;4-ý,

MSSVs 3.7.1 Table 317>1 (e 1 of 1)

Variable Overpower Trip Setpoint versus OPERABLE Main Steam Safety Valves MINIMUM NUMBER NUMBER OF MAXIMUM POWER MAXIMUM ALLOWABLE OF MSSVs PER INOPERABLE (% RTP) VARIABLE OVERPOWER TRIP STEAM GENERATOR MSSVs PER or HIGHEST MODE SETPOINT(a)

REQUIRED STEAM (% RTP)

OPERABLE GENERATOR 10 0 100.0 111.0 9 1 90.0 99.7 8 2 .80.0 89.7 7 3 68.0 77.7 6 4 56.0 65.7 5 5 MODE 3 NA 4 6 MODE 3 NA 3 7 MODE 3 NA 2 8 MODE 3 NA (a) The VOPT setpoint is not required to be reset in MODE 3.

PALO VERDE UNITS 1,2,3 3.7.1-4 AMENDMENT NO.

Procedures 5.4 5.0 ADMINISTRATIVE CONTROLS 5.4 Procedures 5.4.1 Written procedures shall be established, implemented, and maintained covering the following activities:

a. The applicable procedures recommended in Regulatory Guide 1.33, Revision 2, Appendix A, February 1978;

b. The emergency operating procedures required to implement the requirements of NUREG-0737 and to NUREG-0737, Supplement 1, as stated in Generic Letter 82-33;

c. Quality assurance for effluent and environmental monitoring;

d. Fire Protection Program implementation: and

e. All programs specified in Specification 5.5,

f. Modification of core protection calculator (CPC) addressable constants. These procedures shall include provisions to ensure that sufficient margin is maintained in CPC type I addressable constants to avoid excessive operator interaction with CPCs during reactor operation.

Modifications to the CPC software (including changes of algorithms and fuel cycle specific data) shall be performed in accordance with the most recent version of the Software Program Manual for Common Q Systems", CE-CES-195, which has been determined to be applicable to the facility. Additions or deletions to CPC addressable constants or changes to addressable constant software limit values shall not be implemented without prior NRC approval.

PALO VERDE UNITS 1,2,3 5.4-1 AMENDMENT NO.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program (continued) shall not exceed the leakage rate assumed in the accident analysis in terms of total leakage rate for all SGs and leakage rate for an individual SG. Leakage is not to exceed 0.5 gpm per SG and 1 gpm through both SGs.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.14, "RCS Operational LEAKAGE."

c. Provisions for SG tube repair criteria. Tubes found by inservice inspection to contain flaws with a depth equal to or exceeding 40% of the nominal tube wall thickness shall be plugged.

d. Provisions for SG tube inspections. Periodic SG tube inspections shall be performed. The number and portions of the tubes inspected and methods of inspection shall be performed with the objective of detecting flaws of any type (e.g., volumetric flaws, axial and circumferential cracks) that may be present along the length of the tube, from the tube-to-tubesheet weld at the tube inlet to the tube-to-tubesheet weld at the tube outlet, and that may satisfy the applicable tube repair criteria. The tube-to-tubesheet weld is not part of the tube. In addition to meeting the requirements of d.1, d.2, and d.3 below, the inspection scope, inspection methods, and inspection intervals shall be such as to ensure that SG tube integrity is maintained until the next SG inspection. An assessment of degradation shall be performed to determine the type and location of flaws to which the tubes may be susceptible and, based on this assessment, to determine which inspection methods need to be employed and at what locations.

1. Inspect 100% of the tubes in each SG during the first refueling outage following SG replacement.

2. Inspect 100% of the tubes at sequential periods of 144, 108, 72, and, thereafter, 60 effective full power months.

The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outage nearest the end of the period. No SG shall operate for more than 72 effective full power months or three refueling outages (whichever is less) without being inspected.

(continued)

PALO VERDE UNITS 1,2,3 5.5-7 AMENDMENT NO.

Programs and Manuals 5.5 5.5 Programs and Manuals (contlinu6dj 5.5.9 Steam Generator (SG) Program (continued)

3. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indication shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as from examination of a pulled tube, diagnostic non-destructive testing, or engineering evaluation indicates that a crack-like indication is not associated with a crack(s), then the indication need not be treated as a crack.

e. Provisions for monitoring operational primary to secondary LEAKAGE.

(continued)

PALO VERDE UNITS 1,2,3 5.5-8 AMENDMENT NO. 444,

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 CORE OPERATING LIMITS REPORT (COLR)

a. Core operating limits shall be established prior to each reload cycle, or prior to any remaining portion of a reload cycle, and shall be documented in the COLR for the following:

1. Shutdown Margin - Reactor Trip Breakers Open for Specification 3.1.1.

2. Shutdown Margin - Reactor Trip Breakers Closed for Specification 3.1.2.

3. Moderator Temperature Coefficient BOL and EOL limits for Specification 3.1.4.

4. Boron Dilution Alarm System for Specification 3.3.12.

5. CEA Alignment for Specification 3.1.5.

6. Regulating CEA Insertion Limits for Specification 3.1.7.

7. Part Strength CEA Insertion Limits for Specification 3.1.8.

8. Linear Heat Rate for Specification 3.2.1.

9. Azimuthal Power Tilt - Tq for Specification 3.2.3.

10. DNBR for Specification 3.2.4.

11. Axial Shape Index for Specification 3.2.5.

12. Boron Concentration (Mode 6) for Specification 3.9.1.

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC, specifically those described in the following documents:

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

The COLR will contain the complete identification for each of the Technical Specification referenced topical reports used to prepare the COLR (i.e., report number, title, revision, date, and any supplements).

(continued)

PALO VERDE UNITS 1,2,3 5.6-3 AMENDMENT NO. 4-52,

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR) (continued)

1. "CE Method for Control Element Assembly Ejection Analysis," CENPD-0190-A, (Methodology for Specification 3.1.7, Regulating CEA Insertion Limits).

2. "The ROCS and DIT Computer Codes for Nuclear Design,"

CENPD-266-P-A, [Methodology for Specifications 3.1.1, Shutdown Margin - Reactor Trip Breakers Open; 3.1.2, Shutdown Margin - Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient BOL and EOL limits:

3.1.7, Regulating CEA Insertion Limits and 3.9.1, Boron Concentration (Mode 6)].

3. "Safety Evaluation Report related to the Final Design of the Standard Nuclear Steam Supply Reference Systems CESSAR System 80, Docket No. STN 50-470, "NUREG-0852 (November 1981), Supplements No. 1 (March 1983), No. 2 (September 1983), No. 3 (December 1987) [Methodology for Specifications 3.1.2, Shutdown Margin - Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient BOL and EOL limits; 3.3.12, Boron Dilution Alarm System; 3.1.5, CEA Alignment; 3.1.7, Regulating CEA Insertion Limits; 3.1.8, Part Strength CEA Insertion Limits and 3.2.3, Azimuthal Power Tilt - Tq].

4. "Modified Statistical Combination of Uncertainties,"

CEN-356(V)-P-A and "System 80'm Inlet Flow Distribution,"

Supplement I-P to Enclosure 1-P to LD-82-054, (Methodology for Specification 3.2.4, DNBR and 3.2.5 Axial Shape Index).

5. "Calculative Methods for the CE Large Break LOCA Evaluation Model," CENPD-132, (Methodology for Specification 3.2.1, Linear Heat Rate).

6. "Calculative Methods for the CE Small Break LOCA Evaluation Model," CENPD-137-P, (Methodology for Specification 3.2.1, Linear Heat Rate).

(continued)

PALO VERDE UNITS 1,2,3 5.6-4 AMENDMENT NO. 4-52,

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.5 Core Operating Limits Report (COLR) (continued)

7. Letter: O.D. Parr (NRC) to F. M. Stern (CE), dated June 13, 1975 (NRC Staff Review of the Combustion Engineering ECCS Evaluation Model). NRC approval for:

. .5.b.6..

8. Letter: K. Kniel (NRC) to A. E. Scherer (CE), dated September 27, 1977 (Evaluation of Topical Reports CENPD-133, Supplement 3-P and CENPD-137, Supplement l-P). NRC approval for 5.6.5.b.6.

9. "Fuel Rod Maximum Allowable Pressure," CEN-372-P-A, (Methodology for Specification 3.2.1, Linear Heat Rate).

10. Letter: A. C. Thadani (NRC) to A. E. Scherer (CE),

dated April 10, 1990, ("Acceptance for Reference CE Topical Report CEN-372-P"). NRC approval for 5.6.5.b.9.

11. "Arizona Public Service Company PWR Reactor Physics Methodology Using CASMO-4/STMULATE-3," [Methodology for Specifications 3.1.1, Shutdown Margin - Reactor Trip Breakers Open; 3.1.2, Shutdown Margin - Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient; 3.1.7, RegulatingCEA Insertion Limits and 3.9.1, Boron Concentration (Mode 6)].

12. "Technical Manual for the CENTS Code," CE-NPD 282-P-A, Volumes 1-3, [Methodology for Specifications 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient: 3.1.5, CEA Alignment; 3.1.7, Regulating CEA Insertion Limits; 3.1.8, Part Strength CEA Insertion Limits and 3.2.3, Azimuthal Power Tilt- Tq] .

13. CENPD-404-P-A, "Implementation of ZIRLOTM Cladding Material in CE Nuc ear Power Fuel Assembly Designs.

14. CENPD-188-A, "HERMITE, A Multi-Dimensional Space-Time Kinetics Code for PWR Transients." [Methodology for Specifications 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient; 3.2.1, Linear Heat Rate; 3.2.3, Azimuthal Power Tilt; 3.2.4, DNBR; and 3.2.5, Axial Shape Index.]

15. CENPD-161-P-A, "TORC Code, A Computer Code for Determining the Thermal Margin of a Reactor Core."

[Methodology for Specifications 3.1.1, Shutdown Margin-Reactor Trip Breakers Open; 3.1.2, Shutdown Margin-Reactor Trip Breakers Closed; 3.1.4, Moderator Temperature Coefficient; 3.2.1, Linear Heat (continued)

PALO VERDE UNITS 1,2,3 5.6-5 AMENDMENT NO. 74,

ML093170318

Text

Dear Sirs:

Subject:

Enclosure:

SUMMARY

SUMMARY

3.0 TECHNICAL EVALUATION

5.0 ENVIRONMENTAL CONSIDERATION

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