Text

License Amendment Request (LAR)09-001, Administrative Revision to Operating Licenses and Technical Specifications
	ML090510210
Person / Time
Site:	Comanche Peak
Issue date:	02/11/2009
From:	Madden F; Luminant Power
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	CP-200900262, LAR-09-001, TXX-09029
	Download: ML090510210 (422)
	v • d • e

Mike Blevins Luminant Power Executive Vice President P.O. Box 1002

& Chief Nuclear Officer 6322 North FM 56 mikeblevins@luminant.com Glen Rose, TX 76043 Luminant T 254 897 5209 C 817 559 9085 F 254 897 6652 CP-200900262

Ref: 10 CFR 55.90 TXX-09029 February 11, 2009 U. S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555

SUBJECT:

COMANCHE PEAK STEAM ELECTRIC STATION (CPSES) DOCKET NOS. 50-445 AND 50-446, LICENSE AMENDMENT REQUEST (LAR)09-001, ADMINISTRATIVE REVISION TO OPERATING LICENSES AND TECHNICAL SPECIFICATIONS

Dear Sir or Madam:

Pursuant to 10CFR50.90, Luminant Generation Company LLC (Luminant Power) hereby requests an amendment to the CPSES Unit 1 Operating License (NPF-87) and CPSES Unit 2 Operating License (NPF-

89) by incorporating the attached changes into the CPSES Unit 1 and 2 Operating Licenses (OLs) and Technical Specifications (TSs). This change request applies to both Units.

The proposed change revises the CPSES Unit 1 and 2 Operating Licenses (OL) and Technical Specifications (TS) to change the plant name from Comanche Peak Steam Electric Station (CPSES) to Comanche Peak Nuclear Power Plant (CPNPP), removes the Table of Contents (TOC) from the TSs and places it under licensee control, deletes TS.3.2.1.1, TS 3.2.3.1, TS 5.5.9.1, TS 5.6.10, and several footnotes from Tables 3.3.1-1 and 3.3.2-1 and TS 3.4.10 since these TS and footnotes are no longer applicable to Unit 1 or Unit 2 operation, renumbers TS 3.2.1.2 to TS 3.2.1 and TS 3.2.3.2 to TS 3.2.3 and TS 5.5.9.2 to TS 5.5.9, deletes several topical reports from the list of approved analytical methods used to determine core operating limits in TS 5.6.5, and corrects various minor editorial errors in the Technical Specifications.

Due to the numerous changes proposed, this license amendment request proposes to reprint and reissue the entire CPSES Unit 1 and Unit 2 Technical Specifications.

Attachment 1 provides a detailed description of the proposed changes, a technical analysis of the proposed changes, Luminant Power's determination that the proposed changes do not involve a significant hazard consideration, a regulatory analysis of the proposed changes and an environmental evaluation. Attachment 2 provides the affected Unit 1 and Unit 2 Operating License pages marked-up to reflect the proposed changes. Attachment 3 provides the affected Technical Specification (TS) pages marked-up to reflect the proposed changes. Attachment 4 provides retyped Unit 1 and Unit 2 Operating License pages which incorporate the requested changes. Attachment 5 provides retyped Technical Specification pages which incorporate the requested changes.

Luminant Power requests approval of the proposed License Amendment by July 31, 2009, to be implemented within 120 days of the issuance of the license amendment. The approval date was administratively selected to allow for NRC review but the plant does not require this amendment to allow continued safe full power operations.

A member of the STARS (Strategic Teaming and Resource Sharing) Alliance D Callaway - Comanche Peak . Diablo Canyon - Palo Verde

San Onofre

South Texas Project - Wolf Creek A

U. S. Nuclear Regulatory Commission TXX-09029 Page 2 02/11/2009 In accordance with 10CFR50.91(b), Luminant Power is providing the State of Texas with a copy of this proposed amendment.

This communication contains no new or revised commitments.

Should you have any questions, please contact Mr. Robert A. Slough at (254) 897-5727.

I state under penalty of perjury that the foregoing is true and correct.

Executed on February 11, 2009.

Sincerely, Luminant Generation Company, LLC Mike Blevins By: ( 7.

F:rd W. Madden Director, Oversight and Regulatory Affairs ras Attachments 1. Description and Assessment

2. Proposed Unit 1 and Unit 2 Operating License changes

3. Proposed Technical Specifications Changes

4. Retyped Unit 1 and Unit 2 Operating License Pages

5. Retyped Technical Specifications Pages c E. E. Collins, Region IYV B. K. Singal, NRR Resident Inspectors, CPSES Alice Rogers Environmental & Consumer Safety Section Texas Department of State Health Services 1100 West 49th Street Austin, Texas 78756-3189

ATTACHMENT 1 to TXX-09029 DESCRIPTION AND ASSESSMENT to TXX-09029 Page 1 02/11/2009 LICENSEE'S EVALUATION

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

5.1 No Significant Hazards Consideration 5.2 Applicable Regulatory Requirements/ Criteria

6.0 ENVIRONMENTAL CONSIDERATION

7.0 PRECEDENTS

8.0 REFERENCES

to TXX-09029 Page 2 02/11/2009

1.0 DESCRIPTION

By this letter, Luminant Generation Company LLC (Luminant Power) requests an amendment to the CPSES Unit I Operating License (NPF-87) and CPSES Unit 2 Operating License (NPF-89) by incorporating the attached changes into the CPSES Unit 1 and 2 Operating Licenses (OL) and Technical Specifications (TS). Proposed change LAR 09-001 is a request to revise the OL and TS to change the plant name from Comanche Peak Steam Electric Station (CPSES) to Comanche Peak Nuclear Power Plant (CPNPP), remove the Table of Contents (TOC) from the TS and place it under licensee control, delete TS 3.2.1.1, TS 3.2.3.1, TS 5.5.9.1, TS 5.6.10, and several footnotes from Tables 3.3.1-1 and 3.3.2-1 and TS 3.4.10 since these TS and footnotes are no longer applicable to Unit 1 or Unit 2 operation and renumber subsequent TS, delete several topical reports from the list of approved analytical methods used to determine core operating limits in TS 5.6.5, correct various editorial errors in the TS, and reprint and reissue the entire CPSES Unit 1 and Unit 2 TS.

The change in the plant name will be incorporated in the next Certified Update to the CPSES Final Safety Analysis Report. No other changes to the CPSES Final Safety Analysis Report are anticipated at this time as a result of this License Amendment Request. Changes to the TS Bases will be made in accordance with in accordance with 10 CFR 50.59, the TS Bases Control Program as described in Section 5.5.14 of the TS, and existing site procedures.

2.0 PROPOSED CHANGE

The proposed change would revise the OL to change the plant name from Comanche Peak Steam Electric Station (CPSES) to Comanche Peak Nuclear Power Plant (CPNPP), remove the Table of Contents (TOC) from the TS and place it under licensee control, delete TS 3.2.1.1, TS 3.2.3.1, TS 5.5.9.1, TS 5.6.10, and several footnotes from Tables 3.3.1-1 and 3.3.2-1 and TS 3.4.10 since these TS and footnotes are no longer applicable to Unit 1 or Unit,2 operation and renumber subsequent TS, delete several topical reports from the list of approved analytical methods used to determine core operating limits in TS 5.6.5, correct various minor editorial errors in the TS, and reprint and reissue the entire TS.

3.0 BACKGROUND

A change in plant ownership and facility licensee from TXU Power to Luminant Power was approved by NRC Order dated September 10, 2007 (ML072210834) and Amendment 139 to the CPSES Unit I and Unit 2 Operating Licenses, NPF-87 and NPF-89 respectively (ML072760031).

Luminant Power, as the new owner and licensee, has changed the station name to Comanche Peak Nuclear Power Plant (CPNPP). This change does not affect the operating organization or corporate support structure.

The table of contents for the TS is not being eliminated. Rather, following approval of this license amendment request, responsibility for maintenance and issuance of updates to the TS TOC will transfer from the U.S. Nuclear Regulatory Commission (NRC) to Luminant Power, the facility licensee. The TOC will no longer be included in the NRC issued TS and as such will no longer be part of the TS (Appendix A to the Operating License). A TOC for the TS will still be maintained but will be under licensee control. The TOC will be issued by Luminant Power in conjunction with the implementation of future NRC approved TS amendments.

to TXX-09029 Page 3 02/11/2009 Current TS 3.2.1.1 and TS 3.2.3.1 are only applicable to Unit 1 operation during Cycle 13. Since Unit 1 has completed its 13th refueling outage and is now operating in Cycle 14, TS 3.2.1.1 and TS 3.2.3.1 are no longer applicable to Unit 1. Current TS 3.2.1.2 and 3.2.3.2 are renumbered to TS 3.2.1 and 3.2.3, respectively, and are applicable to both Unit 1 and to Unit 2 operation. TS 5.5.9.1 and TS 5.6.10 applied to the Unit 1, Model D4 steam generators which were replaced with Model D76 steam generators during the Unit 1 12th refueling outage, 1RF12, in the Spring of 2007.

Current TS 5.5.9.2 and 5.6.9 are applicable to both Unit 1 with the replacement Model D76 steam generators and to Unit 2 with the current Model D5 steam generators. TS 5.5.9.2 is renumbered to TS 5.5.9, while TS 5.6.9 does not require renumbering since there are no following TS in that section. Table 3.3.1-1 footnotes "#", "##", and "###", and Note 2 are deleted along with Table 3.3.2-1 footnotes "#" and "##" as these are no longer applicable to either Unit. Table 3.3.2-1, footnote "c" is revised to delete the Unit 1, Cycle 13 specific value for 'r1 > 50 seconds. Footnote "b" applicable to the ALLOWABLE VALUE for function 7.b in Table 3.3.2-1 is also deleted as the footnote is no longer applicable since Unit 1 has completed Cycle 12 operation.

The analytical methods described in the topical reports listed as TS 5.6.5b, Items 3 through 13, 15, 19, and 20 are no longer used to determine the core operating limits for CPSES. These topical reports are proposed to be deleted from the list of approved analytical methods in TS 5.6.5b and the remaining topical reports are sequentially renumbered.

Luminant Power has adopted the use of different software to produce and maintain the Technical Specifications. Previously, Luminant Power has used Microsoft's "Word" software. Luminant Power has converted all of the word processing files for the Technical Specifications to the "FrameMaker" application published by Adobe Systems, Inc. The use of the FrameMaker application is expected to result in better consistency in the application of the guidelines for formatting the Technical Specifications as described in TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications", published in June, 2005. Conversion of the current CPSES Unit 1 and Unit 2 Technical Specifications from the "Word" application to the "FrameMaker" application has resulted in minor, insignificant changes to numerous pages in the Technical Specifications, primarily due to changes in the location of page breaks, resulting in the renumbering of the TS pages. In addition, minor previously incorporated editorial errors in the current TS were identified as a result of the review to verify the correct conversion of the TS word processing files from the Microsoft "Word" application to the "FrameMaker" application. This license amendment request proposes to correct these editorial errors and reprint and reissue the entire CPSES Unit 1 and Unit 2 Technical Specifications.

4.0 TECHNICAL ANALYSIS

4.1 Change in Plant Name The change in plant ownership and facility licensee from TXU Power to Luminant Power was approved by NRC Order dated September 10, 2007 (ML072210834) and Amendment 139 to the CPSES Unit 1 and Unit 2 Operating Licenses, NPF-87 and NPF-89 respectively (ML072760031). Luminant Power, as the new owner and licensee, has changed the station name to Comanche Peak Nuclear Power Plant (CPNPP). This change in the plant name is purely administrative in nature and does not affect the operating organization or corporate support structure.

to TXX-09029 Page 4 02/11/2009 4.2 Removal of the Table of Contents The TOC does not meet the criteria specified in 10 CFR 50.36 requiring its inclusion within a plant's TS. 10 CFR 50.36(b) states:

"Each license authorizing operation of a production or utilization facility of a type described in § 50.21 or § 50.22 will include technical specifications. The technical specifications will be derived from the analyses and evaluation included in the safety analysis report, and amendments thereto, submitted pursuant to § 50.34 ......

10 CFR 50.36(c) states the "Technical specifications will include items in the following categories:". Review of 10 CFR 50.36 indicates that a TOC was not listed in the regulation as one of the categories.

10 CFR 50.36(a) indicates that a license application may provide other information associated with the TS, and gives an example of this information, i.e., the TS Bases, but 10 CFR 50.36(a) also clearly indicates that the Bases are not a part of the TS.

"Each applicant for a license ... shall include in his application proposed technical specifications in accordance with the requirements of this section. A summary statement of the bases or reasons for such specifications, other than those covering administrative controls, shall also be included in the application, but shall not become part of the technical specifications."

The TOC references where specific TS sections can be found throughout the TS, but does not contain technical information required by 10 CFR 50.36. Since the TOC does not include information required by 10 CFR 50.36 to be reviewed by the NRC staff, inclusion of a TOC within the TS is optional, and is not required by the regulation. Removal of the TOC from the TS therefore constitutes an administrative change and is therefore acceptable.

Additionally, the "Writer's Guide for Plant-Specific Improved Technical Specifications" (ITS) (Reference 8.1) was reviewed for guidance. The Writer's Guide refers to the TOC as "Technical Specification Front Matter," which also includes the Title Page and List of Effective Pages. The Writer's Guide describes the TS content as starting with Chapter 1, "Use and Application" and does not include the TOC as part of the content of the TS.

A license amendment was issued for the Waterford Steam Electric Station (Waterford 3) to remove the TS Index (which corresponds to the TOC) from the Waterford 3 TS on May 9, 2005 (Reference 8.2). Also, as discussed in the response (Reference 8.3) to an NRC request for additional information for this LAR (Reference 8.4), Arkansas Nuclear One (ANO) and Grand Gulf were issued TS during their ITS conversions which did not include a TOC. Both ANO and the Grand Gulf plants created and maintain a TOC and periodically provide updated pages to controlled copy holders. Also, a license amendment was issued to remove the TOC from the TS for the Monticello Nuclear Generating Plant (Reference 8.5).

to TXX-09029 Page 5 02/11/12009 The TOC for the CPSES TS will be maintained and revised in accordance with Luminant Power administrative procedures. Updating and issuance of the TOC to reflect changes due'to NRC approved license amendments will be in accordance with these procedures, consistent with the current processes for controlling TS Bases and TRM changes. Holders of copies of the TS receive periodic updates of the TOC pages. The distribution process requires that each time Luminant Power receives an approved change to the TS from the NRC, or makes a change to the TS Bases or the Technical Requirements Manual (TRM)J" a transmittal is made with the accompanying changes to all controlled copy holders that maintain controlled copies of the TS. This ensures that all stakeholders are informed of any changes to the TOC.

4.3 Deletion of Defunct Technical Specifications

a. CPNPP Unit I has completed its. 13th refueling outage and is now operating in Cycle 14. TS 3.2.1.1 and TS 3.2.3.1 are deleted as they are no longer applicable.

Current TS 3.2.1.2 and 3.2.3.2 are renumbered to TS 3.2.1 and 3.2.3, respectively, and are applicable to both Unit 1 and Unit 2 operation.

i. The deletion of TS 3.2.1.1 and renumbering of TS 3.2.1.2 require the following conforming changes:

The NOTE modifying current LCO 3.2.1.2 (now designated LCO 3.2.1) is deleted since it is no longer needed.

Current TS 3.2.1.2 (now designated TS 3.2.1) Required Actions.

A.4 and B.4 are revised to "Perform SR 3.2.1.1 and SR 3.2.1.2".

Current SR 3.2.1.2.1 and SR 3.2.1.2.2 are renumbered to SR 3.2.1.1 and SR 3.2.1.2.

Current SR 3.2.1.2.2, Note b. is revised to require repetition of SR 3.2.1.2.

The header for TS 3.2.1.2 on pages 3.2-6 through 3.2-10 is revised from "3.2.1.2" to "3.2.1".

The NOTE modifying LCO 3.2.4, Required Action A.3 is deleted since it is no longer necessary.

LCO 3.2.4, Required Action A.3 is revised consistent with the renumbering of current SR 3.2.1.2.1 and 3.2.1.2.2.

NOTE 2. modifying LCO 3.2.4, Required Action A.6 is deleted.

The number for LCO 3.2.4, Required Action A.6 Note 1. is deleted since it is not needed after deletion of Note 2.

LCO 3.2.4, Required Action A.6 is revised consistent with the renumbering of current SR 3.2.1.2.1 and 3.2.1.2.2.

ii. The deletion of TS 3.2.3.1 and renumbering of TS 3.2.3.2 require the following conforming changes:

Current LCO 3.2.3.2, Note 2 is deleted since it is no longer applicable.

The number for LCO 3.2.3.2 Note 1 is deleted since it is not needed after the deletion of Note 2.

SR 3.2.3.2.1 is renumbered SR 3.2.3.1.

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b. Also, TS 5.5.9.1 and TS 5.6.10 applied to the Unit 1, Model D4 steam generators which were replaced with Model D76 steam generators during the Unit 1 12th refueling outage, 1RF12, in the Spring of 2007. Current TS 5.5.9.2 and 5.6.9 are applicable to both Unit 1 with the replacement Model D76 steam generators and to Unit 2 with the current Model D5 steam generators. Therefore, TS 5.5.9.1 and TS 5.6.10 can be deleted since they are no longer applicable to either Unit. TS 5.5.9.2 is renumbered to TS 5.5.9, while TS 5.6.9 does not require renumbering since there are no following TSs in that section.

c. Table 3.3.1-1 footnotes "#", "##", and "###", and Note 2 are deleted along with Table 3.3.2-1 footnotes "#" and "##" as these footnotes are no longer applicable to either Unit. Table 3.3.2-1, footnote "c" is revised to delete the Unit 1, Cycle 13 specific value for T, > 50 seconds. Footnote "b", applicable to the ALLOWABLE VALUE for function 7.b in Table 3.3.2-1, is deleted as the footnote is no longer applicable since Unit 1 has completed Cycle 12 operation. The footnote "'",

modifying the lift setting values in LCO 3.4.10 for the Unit 1 Pressurizer Safety Valves during Cycle 13 operation, is deleted since Unit 1 has completed Cycle 13 operation.

4.4 Deletion of Topical Reports in TS 5.6.5b The analytical methods described in the topical reports listed as TS 5.6.5b, Items 3 through 13, 15, 19, and 20 have been replaced by standard Westinghouse methods and are no longer used to determine the core operating limits for CPSES. Even though the evaluation of the Inadvertent Loading and Operation of a Fuel Assembly in an Improper Location (FSAR 15.4.7) currently uses a method presented in Item 8, the analysis itself is not used to establish the core operating limits. For future cycles of Comanche Peak Units 1 and 2, the standard evaluation presented in the Pressurized Water Reactor Owners' Group report, WCAP-16676-NP, "Analysis Update for the Inadvertent Loading Event" will be used. These topical reports are proposed to be deleted from the list of approved analytical methods in TS 5.6.5b and the remaining topical reports are sequentially renumbered.

4.5 Correction of Editorial errors Several minor editorial changes and previously incorporated errors in the current TS were identified as a result of the review to verify the correct conversion of the TS word processing files from the Microsoft "Word" application to the "FrameMaker application.

This license amendment request proposes to correct the following editorial errors in accordance with the guidelines in TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications" and the format for Revision 3 to the improved Standard Technical Specifications for Westinghouse plants in NUREG-1431. A description of each editorial.change is provided below along with a cross-reference to the section of TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications" which provides the applicable formatting guidance.

to TXX-09029.

Page 7 02/11/2009 Applicable Description of Editorial Change Section of TSTF-RPT-01

a. Corrected a spelling error in the first sentence of the last N/A paragraph under EXAMPLE 1.3-3. Corrected "than" to "that".

b. The "Immediately" COMPLETION TIME for TS 3.3.1 2.5.5 CONDITION I is aligned with the first line of REQUIRED ACTION 1.1 instead of the first line of the NOTE modifying REQUIRED ACTION 1.1.

c. The COMPLETION TIME for TS 3.3.2 Required Action J.1 is N/A revised to correct an editorial error by adding an "s" to make "hour" plural.

d. Footnote "(r)" on page 3.3-32, Table 3.3.2-1 (page 4 of 6), is N/A revised to correct a spelling error by changing "determining" to "determine".

e. The FREQUENCY for SR 3.4.16.1 is moved vertically to align 2.5.7 with first line of the SR text.

f. The list of valves for SR 3.5.2.7 on current page 3.5-7 is N/A reformatted from a single column to a three-column format.

g. The NOTE modifying LCO 3.6.3 on current page 3.6-7 is moved 2.1.4 from prior to the LCO to immediately after the LCO.

h. The indentation of the AND logical connector between TS 3.7.10 2.1.5 Required Actions D.2.1. and D.2.2 is corrected to 0.5 inch from the column left margin.

i. The indentation of the AND logical connectors between TS 2.1.5 3.7.11 Required Actions C.2.1 and C.2.2, between Required Actions D.1.1. and D.1.2, between Required Actions D.2.1 and D.2.2, and between Required Actions E.1.1 and E.1.2 is corrected to 0.5 inch from the column left margin.

j. "(page 1 of 1)" is added after the Figure number for Figures 2.1.7 3.7.17-1, 3.7.17-2, 3.7.17-3, and 3.7.17-4.

k. The FREQUENCY for SR 3.8.3.2 is moved vertically to align 2.5.7 with first line of the SR text.

1. The Title for TS section "4.3 Fuel Storage" is inserted at the top 2.4.2 of current page 4.0-3 followed by "(continued)" to indicate the continuation of the section from the previous page.

m. The second occurrence of the word "to" is deleted from TS N/A 5.4.1b to make the sentence grammatically correct.

to TXX-09029 Page 8 02/11/2009 Applicable Description of Editorial Change Section of TSTF-RPT-01

n. TS 5.5.1 is reformatted by inserting a paragraph designator "c." 2.6.2 for the sentence beginning "Licensee initiated changes...",

renumbering the following sub-level paragraphs "1", "2", and "3" vice "a", "b", and "c" respectively, and renumbering paragraphs "a.l" and "a.2" using lower case roman numerals "i" and "ii" respectively.

o. TS 5.5.9.2.d.2a, 5.5.9.2.d.2b, and 5.5.9.2.d.3 are renumbered to 2.6.2 5.5.9.d.2, 5.5.9.d.3, and 5.5.9.d.4, respectively. The fourth sentence in TS 5.5.9.d is revised to delete "...of d.1, d.2, and d.3..." The new sentence reads "In addition to meeting the requirements below.... "

p. TS 5.5.15 is reformatted to use paragraph and ordered list 2.6.2 designators. "a." is inserted for the first paragraph, the following four items are numbered 1 through 4, the second paragraph is designated "b.', the next three items are numbered 1 through 3, and the last paragraph is designated "c."

4.6 Reprinting of the Technical Specifications The use of the FrameMaker software to produce and maintain the CPSES Unit 1 and Unit 2 Technical Specifications is expected to reduce the potential for introduction of errors into the Technical Specifications over time since the application provides the capability to implement stricter, software-driven controls over aspects such as page, paragraph, and table formatting and numbering, header and footer content and formatting, text outlining and indentation, and Chapter, section, and specification numbering and titling. The adoption of the FrameMaker application, the deletion of out-dated TSs 3.2.1.1, 3.2.3.1, 5.5.9.1, and 5.6.10, and the correction of editorial errors has resulted in the need to reproduce and reissue the entire Technical Specifications in order to "re-baseline" the Technical Specifications. Reprinting of the entire Technical Specifications will minimize the potential for error in use and application of the Technical Specifications which could arise due to inconsistent application of the rules of TS usage caused by inadvertent differences in formatting from one page or section of the Technical Specifications to another. The changes described in 4.1 through 4.5 are not identified with change bars in the right margin of the retyped pages in Attachment 5.

to TXX-09029 Page 9 02/11/2009

5.0 REGULATORY ANALYSIS

5.1 No Significant Hazards Consideration Luminant Power has evaluated whether or not a significant hazards consideration is involved with the proposed amendment(s) by focusing on the three standards set forth in 10CFR50.92, "Issuance of amendment," as discussed below:

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

Response: No The proposed change revises the station name, removes the Table of Contents from the Technical Specifications, deletes several Technical Specifications and footnotes which are no longer applicable to Unit 1 or Unit 2 operation, renumbers subsequent Technical Specifications, deletes several topical reports from the list of approved analytical methods used to determine core operating limits, and corrects various editorial and formatting errors. The Table of Contents does not include information required by 10 CFR 50.36 to be reviewed by the NRC staff and is not required by the regulation. The Technical Specifications and footnotes which are being deleted were only applicable during previous operational cycles and are now defunct requirements since both Units have completed the applicable operational cycles. The topical reports deleted from Technical Specification 5.6.5b are no longer used to determine the core operating limits for Comanche Peak Nuclear Power Plant. The remaining topical reports listed in Technical Specification 5.6.5b will be used to determine the core operating limits for both Comanche Peak Nuclear Power Plant units. All other changes proposed are corrections of previous inadvertent editorial errors or changes in format to increase conformity with the guidelines described in TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications",

published in June, 2005. All of the proposed changes are administrative changes which do not change the meaning, intent, interpretation, or application of the Technical Specifications. None of the proposed changes affect the operation, physical configuration, or function of plant equipment or systems. The changes do not affect the initiators or assumptions of analyzed events; nor do they impact the mitigation of accidents or transient events. Therefore, the proposed changes do not involve a significant increase in the probability or consequences of an accident previously evaluated.

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

Response: No The proposed change revises the station name, removes the Table of Contents from the Technical Specifications, deletes several Technical Specifications and footnotes which are no longer applicable to Unit 1 or Unit 2 operation, renumbers subsequent Technical Specifications, deletes several topical reports to TXX-09029 Page 10 02/11/2009 from the list of approved analytical methods used to determine core operating limits, and corrects various editorial and formatting errors. The Table of Contents does not include information required by 10 CFR 50.36 to be reviewed by the Nuclear Regulatory Commission staff and is not required by. the regulation. The Technical Specifications and footnotes which are being deleted were only applicable during previous operational cycles and are now defunct requirements since both Units have completed the applicable operational cycles.

The topical reports deleted from Technical Specification 5.6.5b are no longer used to determine the core operating limits for Comanche Peak Nuclear Power Plant.

The remaining topical reports listed in Technical Specification 5.6.5b will be used to determine the core operating limits for both Comanche Peak Nuclear Power Plant units. All other changes proposed are corrections of previous inadvertent editorial errors or changes in format to increase conformity with the guidelines described in TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications", published in June, 2005. All of the proposed changes are administrative changes which do not change the meaning, intent, interpretation, or application of the Technical Specifications. None of the changes alter the plant configuration, require installation of new equipment, alter assumptions about previously analyzed accidents, or impact the operation or function of any plant equipment or systems. Therefore, the proposed changes do not create the possibility of a new or different kind of accident from any previously evaluated.

3. Do the proposed changes involve a significant reduction in a margin of safety?

Response: No The proposed change revises the station name, removes the Table of Contents from the Technical Specifications, deletes several Technical Specifications and footnotes which are no longer applicable to Unit 1 or Unit 2 operation, renumbers subsequent Technical Specifications, deletes several topical reports from the list of approved analytical methods used to determine core operating limits, and corrects various editorial and formatting errors. The Table of Contents does not include information required by 10 CFR 50.36 to be reviewed by the Nuclear Regulatory Commission staff and is not required by the regulation. The Technical Specifications and footnotes which are being deleted were only applicable during previous operational cycles and are now defunct requirements since both Units have completed the applicable operational cycles.

The topical reports deleted from Technical Specification 5.6.5b are no longer used to determine the core operating limits for Comanche Peak Nuclear Power Plant.

The remaining topical reports listed in Technical Specification 5.6.5b will be used to determine the core operating limits for both Comanche Peak Nuclear Power Plant units. All other changes proposed are corrections of previous inadvertent editorial errors or changes in format to increase conformity with the guidelines described in TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications", published in June, 2005. All of the proposed changes are administrative changes which do not change the meaning, intent, interpretation, or application of the Technical Specifications. None of the proposed changes alter the effective technical content of the Technical Specifications. Therefore the proposed changes do not involve a reduction in a margin of safety.

to TXX-09029 Page 11 02/11/2009 Based on the above evaluations, Luminant Power concludes that the proposed amendment(s) present no significant hazards under the standards set forth in 10CFR50.92(c) and, accordingly, a finding of "no significant hazards consideration" is justified.

5.2 Applicable Regulatory Requirements/Criteria 10 CFR 50.36(a) states "Each applicant for a license ... shall include in his application proposed technical specifications in accordance with the requirements of this section. A summary statement of the bases or reasons for such specifications, other than those covering administrative controls, shall also be included in the application, but shall not become part of the technical specifications." Similar to the TS Bases, the TOC does not meet the criteria specified in 10 CFR 50.36 for inclusion within a plant's Technical Specifications.

None of the proposed changes alter the plant configuration, require installation of new equipment, alter assumptions about previously analyzed accidents, or impact the physical configuration, operation, or function of any plant equipment or systems. None of the proposed changes alter the effective technical content of the Technical Specifications. All of the proposed changes are administrative changes which do not change the meaning, intent, interpretation, or application of the Technical Specifications.

In 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, (2) such activities will be conducted in compliance with the Commission's regulations, and (3) the issuance of the amendment will not be inimical to the common defense and security or to the health and safety of the public.

6.0 ENVIRONMENTAL CONSIDERATION

Luminant Power has determined that the proposed amendment would change requirements with respect to the installation or use of a facility component located within the restricted area, as defined in 10CFR20, or would change an inspection or surveillance requirement. Luminant Power has evaluated the proposed changes and has determined that the changes do not involve (i) a significant hazards consideration, (ii) a significant change in the types or significant increase in the amount of effluent that may be released offsite, or (iii) a significant increase in the individual or cumulative occupational radiation exposure. Accordingly, the proposed change meets the eligibility criterion for categorical exclusion set forth in 10CFR51.22 (c)(9). Therefore, pursuant to 10CFR51.22 (b), an environmental assessment of the proposed change is not required.

7.0 PRECEDENTS 7.1 A license amendment was issued for the Waterford Steam Electric Station (Waterford 3) to remove the TS Index (which corresponds to the TOC) from the Waterford 3 TS on May 9, 2005 (Reference 8.2). Also, as discussed in the response (Reference 8.3) to an NRC request for additional information for this LAR (Reference 8.4), Arkansas Nuclear One (ANO) and Grand Gulf during their ITS conversions were issued TS which did not include a TOC. Both ANO and the Grand Gulf plants created and maintain a TOC and periodically provide updated pages to controlled copy holders.

to TXX-09029 Page 12 02/11/2009 7.2 Monticello Nuclear Generating Plant, License Amendment No. 152, issued on November 8, 2007. This amendment revised the Monticello Nuclear Generating Plant Technical Specifications by removing the Table of Contents from the Technical Specifications snf placing it under-licensee control. The Staff's Safety Evaluation Report for this license amendment stated "The Table of Contents does not contain any technical information required by 10 CFR 50.36. On such basis, inclusion of a Table of Contents as part of the TS is optional, and is not required by the regulation cited above. Therefore, removal of the Table of Contents from the TS constitutes a purely administrative change, and is acceptable to the NRC staff."

8.0 REFERENCES

8.1 Technical Specifications Task Force, TSTF-GG-05-01, "Writer's Guide for Plant-Specific Improved Technical Specifications," dated June 2005.

8.2 U.S. NRC letter to Entergy Operations, Inc., "Waterford Steam Electric Station, Unit 3 -

lssuance of Amendment Re: Modification of Technical Specification (TS) 5.3.1, Fuel Assemblies, TS 5.6.1, Criticality, TS 6.9.1.11.1, Core Operating Limits Reports, and Deletion of TS Index, (TAC No. MC3584), "dated May 9, 2005.

8.3 Entergy Operations, Inc., letter to U.S. NRC, "Supplement to Amendment Request NPF-38-258 to Modify Technical Specification'(TS) 5.3.1, Fuel Assemblies and TS 6.9.1.11.1 ,

Core Operating Limits Report, Waterford Steam Electric Station, Unit 3," dated March 8,'

2005.

8.4 Entergy Operations, Inc., letter to U.S. NRC, "License Amendment Request NPF-38-258 to Modify Technical Specification (TS) 5.3.1, Fuel Assemblies and TS 6.9.1.11.1, Core Operating Limits Report, Waterford Steam Electric Station, Unit 3," dated June 17, 2004.

8.5 U.S. NRC letter to Nuclear Management Co., LLC, "Monticello Nuclear Generating Plant

- Issuance Of Amendment Re: Removal of The Table of Contents Out Of The Technical Specifications (TAC NO. MD6027)," dated November 8, 2007.

ATTACHMENT 2 to TXX-09029 PROPOSED UNIT 1 AND UNIT 2 OPERATING LICENSE CHANGES (MARK-UP)

Unit 1 Pages 1 2

6 7

Unit 2 Pages 1 2-6

LUMINANT GENERATION COMPANY LLC INUCLEAR POWER PLANT- DOCKET NO. 50-445 COMANCHE PEAK ELECTRICSTO. UNIT NO. 1 FACILITY OPERATING LICENSE

[Nuclear Power Plant License No. NPF-87

1. The Nuclear Regulatory Co ission (the Commission) has found that:

A. The application. for a licens filed by Luminant Generation Company LLC*

(licensee), complies with the ndards and requirements of the Atomic Energy Act of 1954, as amended (the A and the Commission's regulations set forth in 10 CFR Chapter 1, and all required tifications to other agencies or bodies have been duly made; B. Construction of the Comanche Peak ,Unit No. 1 (the facility), has been substantially completed in conformity with Construction Permit No. CPPR-126 and the application, as amended, the provisions of the Act, and the regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.D below);

D. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter 1, except as exempted from compliance in Section 2.D below;

Luminant Generation Company LLC was previously named as TXU Generation CompanyLP. The legal name was changed in connection with the indirect license transfer application dated April 18, 2007, as supplemented July 20, 2007 and October 2, 2007.

Amendment No. 68 89, 90, 139

E. Luminant Generation Company LLC is technically qualified to engage in the activities authorized by this operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter 1; F. The licensee has satisfied the applicable provisions of 10 CFR 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against.environmental and other costs and considering available alternatives, the issuance of Facility Operating License No. NPF-87 subject to the conditions for protection of the environment set forth herein, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and The receipt, possession, and use of source, byproduct, and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70, except that an exemption to the provisions of 70.24 is granted as described in paragraph 2.D below.

2. Based on the foregoing findings regarding this facility, Facility Operating License No.

NPF-87 is hereby issued to the licensee, to read as follows:

A. This license applies to the Comanche P~chea cA Elecltric Statien, Unit No. 1, a pressurized ':aco and associated equipment (the facility), owned

[Nuclear Power Plant - -Eicensee. The facility is located on Squaw Creek Reservoir in Somervell County, Texas about 5 miles north-northwest of Glen Rose, Texas, and about 40 miles southwest of Fort Worth in north-central Texas and is described in the licensee's Final Safety Analysis Report, as supplemented and amended, and the licensee's Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Pursuant to Section 103 of the Act and 10 CFR Part 50, "Domestic Licensing and Production and Utilization Facilities," Luminant Generation Company LLC to possess, use, and operate the facility at the designated location in Somervell County, Texas in accordance with the procedures and limitations set forth in this license; (2) NOT USED Amendment No. 68, 89 90, 139

(b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (9) License Transfer Luminant Generation Company LLC shall enter into the $250 million support agreement with Luminant Investment Company LLC, as described in the July 20, 2007 supplement to the April 18, 2007 indirect license transfer application, no later than the time the proposed transactions and indirect license transfers occur. Luminant Generation Company LCC shall take no action to cause Luminant Investment Company LLC, or its successors and assigns, to void, cancel, or modify the support agreement or cause it to fail to perform, or impair its performance under the support agreement, without the prior written consent of the NRC. The support agreement may not be amended or modified without 30 days prior written notice to the Director of the Office of Nuclear Reactor Regulation or his designee. An executed copy of the support agreement shall be submitted to the NRC no later than 30 days after the completion of the proposed transactions and the indirect license transfers. Luminant Generation Company LLC shall inform the NRC in writing anytime it draws upon the support agreement.

Following the subject indirect transfer of control of the licenses, all of the CPNoPeffirs of the general partner or controlling member of the licensee of ILJ-, ,.-,.,shall be U.S. citizens. This condition may be amended upon application by the licensee and approval by the Director of the Office of Nuclear Reactor Regulation.

D. The following exemptions are authorized by law and will not endanger life or property or the common defense and security. Certain special circumstances are present and these exemptions are otherwise in the public interest. Therefore, these exemptions are hereby granted pursuant to 10 CFR 50.12.

(1) The facility requires a technical exemption from the requirements of 10 CFR 50, Appendix J, Section IIl.D.2(b)(ii). The justification for this exemption is contained in Section 6.2.5 of Supplement 22 to the Safety Evaluation Report dated January 1990. The staffs environmental assessment was published on November 14, 1989 (54 FR 47430).

Amendment No. 68-, 90, 0, 139 Revised by letter dated July 26, 2007

Therefore, pursuant to 10 CFR 50.12(a)(1), and 10 CFR 50.12(a)(2)(ii)

I~uclear Poe , e Rea (,tCorctrie-Stafan, Unit 1 is hereby granted an exemption from the cited requirement and instead, is required erform the overall air lock leak test at pressure Pa prior to establishing nta ent integrity if air lock maintenance has been performed that

' a e h arlock sealing capability.

(2) The f hi was pre usly granted an exemption from the criticality monitori r uirement 10 CFR 70.24 (see Materials License No. SNM-1 ated Dece r 1, 1988 and Section 9.1.1 of Supplement to e Safety Ev tion Report dated January 1990). The staff's environme a ssessment wa lished on November 14, 1989 (54 FR 47432). The o nche Peak _T, m Flcctri, Statmo, Unit 1 is hereby exempted froto he iticality monitoring provisions of 10 CFR 70.24 as applied to fuel e lies held under this license.

(3) The facility requires a tempora ex ption from the schedular requirements of 10 CFR 50.33(k) d CFR 50.75. The justification for this exemption is contained in Secti 20. of Supplement 22 to the Safety Evaluation Report dated Janua 199 The staffs environmental assessment was published on November 4, 1 9 (54 FR 47431).

Therefore, pursuant to 10 CFR 50.12(a)(1), .12 )(iii) and 50.12(a)(2)(v), the Comanche Peak Stem e Unit 1 is hereby granted a temporary exemption from the s edular requirements of 10 CFR 50.33(k) and 10 CFR 50.75 and is requirelo submit a decommissioning funding report for Comanche Peak Sta:i4e, Unit 1 on or before July 26, 1990.

E. DELETED F. In order to ensure that Luminant Generation Company LLC will exercise the authority as the surface landowner in a timely manner and that the requirements of 10 CFR Part 100.3 (a) are satisfied, this license is subject to the additional conditions specified below: (Section 2.1.1, SER)

(1) For that portion of the exclusion area which is within 2250 ft of any seismic Category I building or within 2800 ft of either reactor containment building, Luminant Generation Company LLC must prohibit the exploration and/or exercise of subsurface mineral rights, and if the subsurface mineral rights owners attempt to exercise their rights within this area, Luminant Generation Company LLC must immediately institute immediately effective condemnation proceedings to obtain the mineral rights in this area.

(2) For the unowned subsurface mineral rights within the exclusion area not covered in item (1), Luminant Generation Company LLC will prohibit the exploration and/or exercise of mineral rights until and unless the licensee and the owners of the mineral rights enter into an agreement which gives Luminant Generation Company LLC absolute authority to determine all activities -- including times of arrival and locations of personnel and the authority to remove personnel and equipment -- in event of emergency.

If the mineral rights owners attempt to exercise their rights within this area without first entering into such an agreement, Luminant Generation Company LLC must institute immediately effective condemnation proceedings to obtain the mineral rights in this area.

Amendment No. 68, 82, 90,1 139 Revised by letter dated July 26, 2007

LUMINANT GENERATION COMPANY LLC DOCKET NO. 50-446 NUCEAR POWER PLANTI COMANCHE PEAK STEAM ELECTR',CSTAT 10', UNIT NO. 2 FACILITY OPERATING LICENSE License No. NPF-89

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

A. The application for a license filed by Luminant Generation Company LLC*

(licensee), complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; Nuclear Power Plantl B. Construction of the Comanche Peak Ste"-"ee tric Stati,, Unit No. 2 (the facility), has been substantially completed in conformity with Construction Permit No. CPPR-127 and the application, as amended, the provisions of the Act, and the regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.D below);

D. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering, the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I, except as exempted from compliance in Section 2.D. below; E. Luminant Generation Company LLC is technically qualified to engage in the activities authorized by this operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter I;

Luminant Generation Company LLC was previously named as TXU Generation Company LP. The legal name was changed in connection with the indirect license transfer application dated April 18, 2007, as supplemented July 20, 2007 and October 2, 2007.

Amendment No. 68,89,90, 139

F. The licensee has satisfied the applicable provisions of 10 CFR 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of Facility Operating License No. NPF-89 subject to the conditions for protection of the environment set forth herein, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and The receipt, possession, and use of source, byproduct, and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70, except that an exemption to the provisions of 70.24 is granted as described in paragraph 2.D below.

2. Pursuant to approval by the Nuclear Regulatory Commission at a meeting on April 6,1993, the License for Fuel Loading and Low Power Testing, License No. NPF-88, issued on February 2, 1993, is superseded by Facility Operating License No. NPF-89 hereby issued to the licensee, to read as follows: Nuclear Power Plant I&

A. This license applies to the Comanche Peak Steam ,_e!FtP Sttlon, Unit No. 2, a pressurized-water nuclear reactor and associated equipment (the facility), owned by the licensee. The facility is located on Squaw Creek Reservoir in Somervell County, Texas about 5 miles north-northwest of Glen Rose, Texas, and about 40 miles southwest of Fort Worth in north-central Texas and is described in the licensee's Final Safety Analysis Report, as supplemented and amended, and the licensee's Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Pursuant to Section 103 of the Act and 10 CFR Part 50, "Domestic Licensing of Production and Utilization Facilities," Luminant Generation Company LLC to possess, use, and operate the facility at the designated location in Somervell County, Texas in accordance with the procedures and limitations set forth in this license; (2) NOT USED Amendment No. 68 89, 90, 139

(9) License Transfer Luminant Generation Company LLC shall enter into the $250 million support agreement with Luminant Investment Company LLC, as described in the July 20, 2007 supplement to the April 18, 2007 indirect license transfer application, no later than the time the proposed transactions and indirect license transfers occur. Luminant Generation Company LCC shall take no action to cause Luminant Investment Company LLC, or its successors and assigns, to void, cancel, or modify the support agreement or cause it to fail to perform, or impair its performance under the support agreement, without the prior written consent of the NRC. The support agreement may not be amended or modified without 30 days prior written notice to the Director of the Office of Nuclear Reactor Regulation or his designee. An executed copy of the support agreement shall be submitted to the NRC no later than 30 days after the completion of the proposed transactions and the indirect license transfers. Luminant Generation Company LLC shall inform the NRC in writing anytime it draws upon the support agreement.

Following the subject indirect transfer of control of the licenses, all of the I PPPofficers of the general partner or controlling member of the licensee of shall be U.S. citizens. This condition may be amended upon application by the licensee and approval by the Director of the Office of Nuclear Reactor Regulation.

D. The following exemptions are authorized by law and will not endanger life or property or the common defense and security. Certain special circumstances are present and these exemptions are otherwise in the public interest.

Therefore, these exemptions are hereby granted:

(1) The facility requires a technical exemption from the requirements of 10 CFR Part 50, Appendix J, Section III.D.2(b)(ii). The justification for this exemption is contained in Section 6.2.5.1 of Supplement 26 to the Safety Evaluation Report dated February 1993. The staffs INuclear PwrPlant[_ environmental assessment was published on Jan uary 19, 1993 ursuant to 10 CFR 50.12(a)(1), 10 CFR

'0.1.2(a)(2)(ii) and (iii), the Comanche P-ea

E.ctl str , Unit 2 is he granted an exemption from the cited requirement and instead, is require erform the overall air lock leak test at pressure Pa prior to establishing con i ent integrity if air lock maintenance has been performed that could a t the air lock sealing capability.

The facility was previously grante emption from the criticality Monitoring requirements of 10 CFR 70. see Materials License No.

SNM-1986 dated April 24,1989 and Section . 1 of SSER 26 dated February 1993.) The staffs environmental assess nt was published on January 19, 1993 (58 FR 5035). The Comanche Peak Stat-ie, Unit 2 is hereby exempted from the criticality monitoring provisions of 10 CFR 70.24 as applied to fuel assemblies held under this license.

Amendment No. 68, 9, 19,,, 139

ATTACHMENT 3 to TXX-09029 PROPOSED TECHNICAL SPECIFICATIONS CHANGES (Markup For Information Only)

Pages TS Cover Page i

ii iii iv 1.3-7 2.0-2 2.0-3 3.2-1 through 3.2-10 3.2-14 through 3.2-18 3.2-20 3.3-5 3.3-15 through 3.3-20a 3.3-25 3.3-29 3.3-31 through 3.3-34

.3.4-21 3.4-45 3.4-47 3.5-7 3.6-7 3.7-24 3.7-26 through 3.7-27 3.7-38 through 3.7-41 3.8-23 4.0-3 5.0-6 through 5.0-8 5.0-13 through 5.0-19d 5.0-26 5.0-28 5.0-33 through 5.0-35 5.0-38 through 5.0-39

TECHNICAL SPECIFICATIONS FOR COMANCHE PEAK STEAM ELECTRIG ST.A.40N UNITS 1 AND 2

[NUCLEAR POWER PLANT

TABLE OF CONTENTS 1.0 U S E A N D AP P LIC AT IO N ............................................................................................ 1 -1 1.1 D efin itio ns ...................................................................................................... .. . 1.1 -1 1.2 Logical Connectors........................................ ..... 1.2-1 1.3 C om pletion Tim es ........................................................................................ 1.3-1 1.4 Frequency ............................................................................................... ... 1.4-1 2.0 S A FE TY LIM IT S (S Ls) .............................................................................. . ............... 2.0-1 2 .1 S Ls ................................................................................................ . .................. 2 .0 -1 2 .2 S L V io la tio n s ................................................................................ . ..................... 2 .0 -1 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILIT ........................... 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ......... .............................. 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ............................ ..................................... 3.1-1 3.1.1 SHUTDOW N MARG IN (SDM ) ............................ ........................................ 3.1-1 3.1.2 C ore R eactivity ................................................................................... 3.1-2 3.1.3 Moderator Temperature Coefficient (MTC) ... .............................................. 3.1-4 3.1.4 Rod G roup A lignm ent Lim its ........................................................................ 3.1-7 3.1.5 Shutdow n Bank Insertion Lim its .............. .................................................... 3.1-11 3.1.6 Control Bank Insertion Lim its .............. ........................................................ 3.1-13 3.1.7 R od Position Indication ..................... ......................................................... 3.1-16 3.1.8 PHYSICS TESTS Exceptions- MO 2 ....................................................... 3.1-19 3.2 POWER DISTRIBUTION LIMITS ...."'................................................ 3.2-1 3.2.1 Heat Flux Hot Channel Facto (FQ(Z)) ............................ 3.2-1 3.2.2 Nuclear Enthalpy Rise Hot hannel Factor (FNAH) ........................................ 3.2-11 3.2.3 AXIAL FLUX DIFFEREN (AFD) ............................................................... 3.2-14 3.2.4 QUADRANT POWER t.T RATIO (QPTR) ........................ 3.2-18 3.3 IN ST R U M EN TAT IO N . ...........................................

... ........................................... 3.3-1 3.3.1 Reactor Trip Syst m (RTS) Instrumentation ................................................. 3.3-1 3.3.2 Engineered Saf y Feature Actuation System (ESFAS) Instrumentation ..... 3.3-21 3.3.3 Post Accident lonitoring (PAM) Instrumentation ......................................... 3.3-35 3.3.4 Rem ote Sh dow n System ............................................................................ 3.3-40 3.3.5 Loss of P er (LOP) Diesel Generator (DG) Start Instrumentation ............. 3.3-43 3.3.6 Contain ent Ventilation Isolation Instrumentation ........................................ 3.3-48 3.3.7 Contr Room Emergency Filtration System (CREFS)

Act tion Instrum entation ............................................................................. 3.3-52 (continued)

C MANCHE PEAK - UNITS 1 AND 2 i Amendment No. 64,144

TABLE OF CONTENTS (continued) 3.4 REACTOR COOLANT SYSTEM (RCS) ......................................................... 3. -1 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (D NB) Lim its ................................................................... .. 3.4-1 3.4.2 RCS Minimum Temperature for Criticality ...................... ..... 3.4-4 3.4.3 RCS Pressure and Temperature (P/T) Limits ..................................... ........ 3.4-5 3.4.4 RCS Loops - MODES 1 and 2 .................................. 3.4-7 3.4.5 RCS Loops-M O DE 3 ................................................................... ........... 3.4-8 3.4.6 RCS Loops - MODE 4 .................................... . 3.4-11 3.4.7 RCS Loops-MODE 5, Loops Filled ........................... 3.4-14 3.4.8 RCS Loops-MODE 5, Loops Not Filled .............................. ..................... 3.4-17 3.4.9 Pressurizer ...................................................... 3.4-19 3.4.10 Pressurizer Safety Valves ........................................ 3.4-21 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ........ ....... 3.4-23 3.4.12 Low Temperature Overpressure Protection (LTOP) stem ........... 3.4-27 3.4.13 RCS O perational LEAKAG E .................................. .................................... 3.4-33 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage... ...................... ......... 3.4-35 3.4.15 RCS Leakage Detection Instrumentation ......... .......................................... 3.4-40 3.4.16 RCS Specific Activity .................................. ......... 3.4-44 3.4.17 Steam Generator (SG) Tube Integrity ....... ................................................. 3.4-48 3.5 EMERGENCY CORE COOLING SYSTEM (ECCS) ........................................ 3.5-1 3.5.1 Accum ulators ................................... ........................................... 3.5-1 3.5.2 E C C S - O perating .......................... .............................................................. 3.5-4 3.5.3 ECCS-Shutdown ................................ ....... 3.5-8 3.5.4 Refueling Water Storage Tank WST).......................... 3.5-10 3.5.5 Seal Injection Flow .............. ........................................... 3.5-12 3.6 CO NTAINM ENT SYSTEM S ................................................................................ 3.6-1 3 .6 .1 C o nta inm e nt ................ ................................ I............................................ 3 .6-1 3.6.2 Containment Air Lock..... .. ........................ ..... 3.6-2 3.6.3 Containment Isolati Valves ...................... . ........ 3.6-7 3.6.4 Containment Pres ure ............................. ........ 3.6-16 3.6.5 Containment Ai emperature ................................ 3.6-17 3.6.6 Containment ray System.......................... ...... 3.6-18 3.6.7 Spray Additi e System ............................................. ............................... 3.6-20 (continued)

PEAK - UNITS 1 AND 2 II Amendment No. 84, 4-1-7, 128

TABLE OF CONTENTS (continued) /

3.7 P LANT SYST EM S .............................................................................................. 3.. -

3.7.1 Main Steam Safety Valves (MSSVs) .............................................................. /.7-1 3.7.2 Main Steam Isolation Valves (MSIVs) ........................................................ .. 3.7-6 3.7.3 Feedwater Isolation Valves (FIVs) and Associated Bypass Valves ......... .... 3.7-8 3.7.4 Steam Generator Atmospheric Relief Valves (ARVs) ........................... ...... 3.7-10 3.7.5 Auxiliary Feedwater (AFW) System .................................................. .......... 3.7-12 3.7.6 Condensate Storage Tank (CST) ............................. 3.7-16 3.7.7 Component Cooling Water (CCW) System ................................. ................ 3.7-17 3.7.8 Station Service Water System (SSWS) ................................... ................... 3.7-19 3.7.9 Ultimate Heat Sink (UHS) ......................... ......... 3.7-22 3.7.10 Control Room Emergency Filtration/Pressurization System CREFS) ......... 3.7-23 3.7.11 Control Room Air Conditioning System (CRACS) ............ ............................ 3.7-26 3.7.12 Primary Plant Ventilation System (PPVS) - ESF Filtrati Trains ................. 3.7-29 3.7.13 Fuel Building Air Cleanup System (FBACS) - Not use ................................. 3.7-32 3.7.14 Penetration Room Exhaust Air Cleanup System (P ACS) - Not used .... .7-33 3.7.15 Fuel Storage Area Water Level ............................ ......................................... 3.7-34 3.7.16 Fuel Storage Pool Boron Concentration .......................... 3.7-35 74 3.7.17 Spent Fuel Assembly Storage ....................... ....... I........................................ 3.7-36 3.7.18 Secondary Specific Activity ..................... ...... ............................................... 3.7-42 74 3.7.19 Safety Chilled Water System .................... ................................................. 3.7-43 3.7.20 U PS HVA C System ........................................................................................ 3.7-45 3.8 ELECTRICAL POWER SYSTEMS ........ ..................... ....................................... 3.8-1 3.8.1 A C Sources -O perating ................ ................................................................ 3.8-1 3.8.2 AC Sources-Shutdown ...................... ........

3.8-17 3.8.3 Diesel Fuel Oil, Lube Oil, and arting Air ................................................... 3.8-21 3.8.4 DC Sources- O perating ....... ........................................................................ 3.8-24 3.8.5 D C Sources -Shutdow n ................................................................................. 3.8-28 3.8.6 Battery Parameters ....... ................................................ 3.8-30 113 3.8.7 Inverters - O perating .. ................................................................................. 3.8-34 3.8.8 Inverters - S hutdow n ...................................................................................... 3.8-36 3.8.9 Distribution System -Operating ................................... 3.8-38 3.8.10 Distribution Syste s-Shutdown .................................................................... 3.8-40 (continued' ICHE PEAK - UNITS 1 AND 2 o°° Amendment No. 113

TABLE OF CONTENTS (continued) /

3.9 R EFU ELING O PERATIO NS ................................................................................ 3 -1 3.9.1 Boron C oncentration .................................................................................... / .9-1 3.9.2 Unborated Water Source Isolation Valves................................................ 3.9-3 3.9.3 Nuclear Instrumentation...................................................... ..... 3.9-5 3.9.4 Containm ent Penetrations .................................................................. ..... 3.9-7 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation -

High W ater Level ........................................................................... .............. 3 .9-9 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation -

Low Water Level. ..................... .......... ............... 3.9-11 3.9.7 Refueling Cavity Water Level .................................. 3.9-13 4.0 D ES IG N FEA T UR E S ..................................................................... ............................ 4 .0-1 4.1 Site Location ................... ................................ 4.0-1 4.2 Reactor Core ............... ................................... 4.0-1 4.3 Fuel S torage ................................................................ . ............................... 4.0-2 5.0 ADM INISTRATIVE CO NTRO LS ................................................................................. 5.0-1 5.1 Responsibility ............................................................................ 5.0-1 5.2 Organ.......

r ga n i bion ....................................... . .......................................... 5.0-2 5.3 Unit Staff Qualifications ................. ............................................... 5.0-5 5.4 Pc P u...........................................................................

rocedures ............................. 5.0-6 5.5 Program s and Manuals ........................... ....................................................... 5.0-7 5.6 Reporting R equirem ents ....................... ........................................................... 5.0-29 5.7 High R adiation A rea ........................... ................................................................ 5.0-4 0 PEAK - UNITS 1 AND 2 iv Amendment No. 64,144

Completion Times 1.3

-1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion Times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. If the Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).

It is possibl to alternate between Conditions A, B, and C in such a manner than operation could continue indefinitely without ever restoring systems to meet the LCO. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 1.3-7 Am,endment No. 64, 142

SI Figure 2.1.1-1 (page 1 of 2)

Reactor Core Safety Limits (Unit 1)

(THIS FIGURE AND PAGE HAVE BEEN 1 67 PEAK - UNITS 1 AND 2 2.0-2 Amendment No. 67

SLs, Figure 2.1.1-1 (page 2 of 2)

Reactor Core Safety Limits (Unit 2) 67 (THIS FIGURE AND PAGE HAVE BEEN I --LETED.)

PEAK - UNITS 1 AND 2 2.0-3 Amendment No. 67

FQ(Z) (CAOC-W(Z) Methodology) 3.2.1.

3.2 POWER DISTR IBUTION LIMITS 3.2.1 Heat Flux Ho it Channel Factor (F a(Z))

3.2.1.1 Heat Flux Hlot Channel Factor (FQ(Z)) (CAOC-W(Z) Methodology)

LCO 3.2.1.1 FQ(Z), as approximated by Fc(Z) and F~w(Z), shall be with' the limits specified in the COLR.

------------------- IU I -------

This LCO is only applicable to Unit 1, Cycle 13.

APPLICABILITY: MODE 1 ACTIONS CONDITIONCONDIOMP REQUIRED A ION COMPLETION ETINOIM TIME A. FQc(Z) not within limit. A.1 Reduce ERMAL 15 minutes after POWE >1% RTP for. each Fc(Z) each % FC(Z ) exceeds determination limi.

AND A.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each Neutron Flux -- High trip FOc(Z) determination setpoints >1% for each 1% Fc(Z) exceeds limit.

AND A.3 Reduce Overpower N-16 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each trip setpoints >1% for Fc(Z) determination each 1% FC(Z) exceeds limit.

AND A.4 Perform SR 3.2.1.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

C MANCHE PEAK - UNITS 1 AND 2 3.2-1 Amendment No. 64,144

FQ(Z) (CAOC-W(Z) Methodology ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETIOyTIME B. FaW(Z) not within limits. B.1 Reduce AFD limits > 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for each 1% F w(Z) exceeds limit.

C. Required Action and C.1 Be in MODE 2. 6 hgdrs associated Completion Time not met.

C MANCHE PEAK - UNITS 1 AND 2 3.2-2 Amendment No. 64,144

FQ(Z) (CAOC-W(Z) Methodology 3.2.1 SURVEILLANCE REQUIREMENTS

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

During power escalation following shutdown, THERMAL POWER may be increased ntil an equilibrium power level has been achieved at which a power distribution map is obt ined.

SURVEILLANCE FREQUENCY SR 3.2.1.1.1 Verify F C(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving' equilibrium conditions after exceeding, by

Žt 20% RTP, the THERMAL POWER at which FQC(Z) was last verified AND 31 EFPD thereafter (continued)

C ANCHE PEAK - UNITS 1 AND 2 3.2-3 Amendment No. 64,144

FQ(Z) (CAOC-W(Z) Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUOE$Y SR 3.2.1.1.2 ----------------- NOTE----

If FQC(Z) measurements indicate maximum over z L(

[ K(Z) ]

has increased since the previous evaluation of F c(Z):

a. Increase FQW(Z) by the appropriate factor and reverify FOW(Z) is within limits; or

b. Repeat SR 3.2.1.1.2 once per 7 EFPD unti wo successive flux maps indicate

[FQc(Z)]

maximum overz [K(z)_

has not increased.

Verify F~w(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND (continued)

C ANCHE PEAK - UNITS 1 AND 2 324AedetN.6,4 3.2-4 Amendment No. 64,144

FQ(Z) (CAOC-W(Z) Methodolog 3.2 .1 SURVEILLANCE FREQUE Y SR 3.2.1.1.2 (continued) Once wit in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months er achieN ng equbrium co ditions after ceeding, by

/ 20% RTP, the THERMAL POWER at which FaC(Z) was last verified AND 31 EFPD thereafter

HE PEAK - UNITS 1 AND 2 3.2-5 Amendment No. 64,144

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1.2-3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Ho9t Chkanno.l Factor (Fr_(Z) 2.2.!.2 Heat Flux Hot Channel Factor (FQ(Z)) (RAOC-W(Z) Methodology)

LCO 3.2.1.- FQ (Z), as approximated by FC(Z) and F~w(Z), shall be within the limits specified in the COLR.

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

This LCO is not applicable APPLICABILITY: MODE 1 ACTIONS CONDITION] REQUIRED ACTION COMPLETION TIME NOTE --------

Required Action A.4 shall be completed whenever this Condition is entered.

A. F c(Z) not within limit. A.1 Reduce THERMAL 15 minutes after POWER > 1% RTP for each Fc(Z) each 1% FQC(Z ) exceeds determination limit.

AND A.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each Neutron Flux -- High trip FC(Z) determination setpoints > 1% for each 1% FC(Z) exceeds limit.

AND A.3 Reduce Overpower N-16 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each trip setpoints > 1% for Fc(Z) determination each 1% FQC(Z) exceeds limit.

AND A.4 Perform SR 3.2.1-.2.1 and Prior to increasing SR 3.2.1-.2. THERMAL POWER above the limit of Required Action A.1 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-6 Amendment No. 144

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1.-2.

ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME NOTE---------

Required Action B.4 shall be completed whenever this Condition is entered.

B. F w(Z) not within limits. B.1 Reduce'AFD limits > 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for each 1% FQW(Z) exceeds limit.

AND B.2 Reduce Power Range 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Neutron Flux - High trip setpoints > 1% for each 1% that the maximum allowable power of the AFD limits is reduced.

AND B.3 Reduce Overpower N-16 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months trip setpoints > 1 % for each 1% that the maximum allowable power of the AFD limits is reduced.

AND B.4 Perform SR 3.2.1.2.1 and Prior to increasing SR 3.2.1-2.2. THERMAL POWER above the maximum allowable power of the AFD limits.

C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

COMANCHE PEAK - UNITS 1 AND 2 3.2-7 Amendment No. 144

FQ(Z) (RAOC-W(Z) Methodology) 3.2.14-SURVEILLANCE REQUIREMENTS

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

During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved at'which a power distribution measurement is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1-.2.1 Verify FQC(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions after exceeding, by

> 20% RTP, the THERMAL POWER at which FQc(Z) was last verified AND 31 EFPD thereafter (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-8 Amendment No. 144

Fa(Z) (RAOC-W(Z) Methodology) 3.2.1-2 SURVEILLANCE REQUIREMENTS (continued),

SURVEILLANCE FREQUENCY

---7---------------------------

S R 3.2.1.--.2 ---------- ------ NOTE-....

if Fc(Z) measurements indicate maximum over z [FK--Z)]

has increased since the previous evaluation of Fc(Z):

a. Increase Few(Z) by an appropriate factor specified in the COLR and reverify FQW(Z) is within limits; or

b. Repeat SR 3.2.1-2.2 once per 7 EFPD until either a.

above is met or two successive power distribution measurements indicate maximum over z FK(Z)]

has not increased.

Verify FQW(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-9 Amendment No. 144

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1-2.2 (continued) Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions after exceeding, by

> 20% RTP, the THERMAL POWER at which FC(Z) was last verified AND 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.2-10 Amendment No. 144

AFD (CAOC METHODOLOGY) 3.2.3.

3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) 3.2.3.1 AXIAL FLUX DIFFERENCE (AFD) (Constant Axial Offset Control (CAOC) M odology)

LCO 3.2.3.1 The AFD:

a. Shall be maintained within the target band abo the target flux difference. The target band is specified in th COLR.

b. May deviate outside the target band with ERMALPOWER

< 90% RTP but > 50% RTP, provided A is within the acceptable operation limits and cumul ive penalty deviation time is < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 h rs. The acceptable operation limits are specified in the OLR.

c. May deviate outside the target nd with THERMAL POWER

< 50% RTP.

N ES ----------------------------------

1. The AFD shall be consid red outside the target band when two or more OPERABLE exc e channels indicate AFD to be outside the target band.

2. With THERMAL PWER > 50% RTP, penalty deviation timeshall be accumulated n the basis of a 1 minute penalty deviation for each 1 minute f power operation with AFD outside the target band.

3. With TH MAL POWER < 50% RTP, penalty deviation time shall be acc ulated on the basis of a 0.5 minute penalty deviation for each minute of power operation with AFD outside the target ban.

4. total of 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months of operation may be accumulated with AFD outside the target band without penalty deviation time during surveillance of power range channels in accordance with SR 3.3.1.6, provided AFD is maintained within acceptable operation limits.

5. This LCO is only applicable to Unit 1, Cycle 13.

APPLICABILI Y: MODE 1 with THERMAL POWER > 15% RTP PEAK - UNITS 1 AND 2 3.2-14 Amendment No. 64,144

AFD (CAQO METHODOLOGY) 3.2 ACTIONS CONDITION REQUIRED ACTION COMPLETIONIlME A. THERMAL POWER A.1 Restore AFD to within 15 minutes

> 90% RTP. target band.

AND AFD not within the target band.

B. Required Action and B.1 Reduce THERMAL 15 minutes associated Completion POWER to < 90% RTP.

Time of Condition A not met.

C. -------- NOTE --------------- C.1 Reduce THERMAL 30 minutes Required Action C.1 must POWER to < 50% TP.

be completed whenever Condition C is entered.

THERMAL POWER < 90%

and > 50% RTP with cumulative penalty deviation time > 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months during the previous 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

OR THERMAL POWER < 90%

and > 50% RTP with AFD not within the acceptable operation limits.

(continued)

C ANCHE PEAK - UNITS 1 AND 2 ,3.2-15 Amendment No. 64,144 1

AFD (CAOC METHODOLOGY) 3.2.3.

CONDITION REQUIRED ACTION COMPLETION TIE D. Required Action and D.1 Reduce THERMAL 9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months associated Completion POWER to < 15% RTP.

Time for Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE *FREQUENCY SR 3.2.3.1.1 Verify AFD is within limits for each OPERABLE e ore 7 days channel./

SR 3.2.3.1.2 Not Used.

SR 3.2.3.1.3 ------------------------------- NOTE -----------/ ------------------- Whenever FQw(Z)

The initial target flux difference after e h refueling may is verified per be determined from design predictio . ------/ / 3.2.1.1.2.

Determine, by measurement, th target flux difference of each OPERABLE excore chaa/el.

C MANCHE PEAK - UNITS 1 AND 2 3.2-16 32-6AedntN.4,4 Amendment No. 64,144

AFD (RAOC METHODOLOGY) 3.2.3.

3.2 POWER DISTRIBUTION LIMITS 3.2.3 ,AXAL FLUX DIFFERENCE (AFD) 322 2 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC)

Methodology)

LCO 3.2.3.-2 The AFD in % flux difference units shall be maintained within the limits specified in the COLR.

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

4- The AFD shall be considered outside limits when two or more

,OPERABLE excore channels indicate AFD to be outside limits.

2i- LGOis t-HI nt ap li~a Let Unit -, G.yUU I a.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Reduce THERMAL 30 minutes POWER to < 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3-.2.1 Verify AFD is within limits for each OPERABLE excore 7 days channel.

COMANCHE PEAK - UNITS 1 AND 2 3.2-17 Amendment No. 144

QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be < 1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP ACTIONS CONDITION [ REQUIRED ACTION FCOMPLETION TIME A. QPTR not within limit. A.1 Reduce THERMAL 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after each POWER > 3% from RTP QPTR determination for each 1 % of QPTR

> 1.00.

AND A.2 Determine QPTR. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND A.3 NOTE Fr-, It*R* 1, CGyle 1 3, Actfion A.3 roquires SR 3.2.1.1.1, SR 3.2.1.1.2, anid SR 3.2.2.1 to be pe~fbmed.

Perform SR 3.2.1-.1, 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.14.2 and achieving equilibrium SR 3.2.2.1. conditions from a THERMAL POWER reduction per Required Action A.1 AND Once per 7 days thereafter AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-18 Amendment No. 64,144

QPTR 3.2.4 ACTIONS (continued CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.6 -------- NOTE-------

4- Perform Required Action A.6 only after Required Action A.5 is completed.

P2A.FrI-Unit 1, CGycl 13, Action A.6 requirez SR 3.2.1.1.1, SR 3.2.1.1.2, aRnd SR 242424.1 hp Perform SR 3.2.1-2.1, Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.1.-2.2 and achieving equilibrium SR 3.2.2.1. conditions at RTP not to exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Actions A.1 B. Required Action and B.1 Reduce THERMAL 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion POWER to < 50% RTP.

Time not met.

COMANCHE PEAK - UNITS 1 AND 2 3.2-20 Amendment No. 64,1144 1

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME One Source Range Neutron 1.1 -------- NOTE --------- immediately 105 Flux channel inoperable. Limited boron concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.

Suspend operations involving positive reactivity additions.

J. Two Source Range Neutron J.1 Open reactor trip Immediately Flux channels inoperable, breakers (RTBs).

K. One Source Range Neutron K.1 Restore channel to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Flux channel inoperable. OPERABLE status.

OR K.2.1 Initiate action to fully 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months insert all rods.

AND K.2.2 Place the Rod Control 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months System in a condition incapable of rod withdrawal.

L. Not used.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-5 Amendment No. 105

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1o4)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

1. Manual 1,2 2 B SR 3.3.1.14 NA Reactor Trip 3 (b), 4 (b), 5 (b) 2 C SR 3.3.1.14 NA

2. Power Range Neutron Flux

a. High 1,2 4 D SR 3.3.1.1 < 109.6% RTP(q)(r)#

SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.16

b. Low 1 (c), 2 4 E SR 3.3.1.1 < 25.6% RTp(q)(r)#

SR 3.3.1.8 -

SR 3.3.1.11.

SR 3.3.1.16

3. Power Range 1,2 4 E SR 3.3.1.7 _6.3% RTP Neutron Flux Rate SR 3.3.1.11 with time constant High Positive Rate Ž2 sec

4. Intermediate 1(c), 2 (d) 2 F,G SR 3.3.1.1 *31.5% RTP Range Neutron SR 3.3.1.8 Flux SR 3.3.1.11 (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(c) Below the P-1 0 (Power Range Neutron Flux) interlock.

(d) Above the P-6 (Intermediate Range Neutron Flux) interlock.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

For Unit 1, through CycGo 13, the ALLO0 W.N.ABILE V.AILU E,:forF th-,A P.w.. Rango Noutron Flux HMih rmnin.s ;t I I0.8°%

I I-Pand the0 Powor PRaRn NwoutroR Fl'x Low .r..a.. at 27.7 ,RTP.

COMANCHE PEAK - UNITS 1 AND 2 3.3-15 Amendment No. 89, 145

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 o-)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Source Range 2(e) 2 I,J SR 3.3.1.1 <1.4 E5 cps Neutron Flux SR 3.3.1.8 SR 3.3.1.11 3 (b), 4(b), 5 (b) 2 J,K SR 3.3.1.1 *_1.4 E5 cps SR 3.3.1.7 SR 3.3.1.11

6. Overtemperature 1,2 4 E SR 3.3.1.1 Refer to Note 1(q)(r) I N-16 SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

7. Overpower 1,2 4 ESR 3.3.1.1 < 112.8% RTP N-16 SR 3.3.1.2 (q)(r)##

SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

8. Pressurizer Pressure

a. Low i(g) 4 M SR 3.3.1.1 Ž1863.6 psig SR 3.3.1.7 (Unit 1)

SR 3.3.1.10 >_1865.2 psig SR 3.3.1.16 (Unit 2)

b. High 1,2 4 ESR 3.3.1.1 < 2400.8 psig SR 3.3.1.7 (Unit 1)

SR 3.3.1.10 < 2401.4 psig SR 3.3.1.16 (Unit 2)

(continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.

(g) Above the P-7 (Low Power Reactor Trips Block) interlock.

(q) Ifthe as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

R* J A* LR AN n *LAmA*N *L#AI ll* A

1. I-or unt 1, nRFOUgn GYGI8 13, the ALLG'WAXULLF VALUE f6rG~v9rpowerPltf rom-rnin;t 11P.U 99A T-.

COMANCHE PEAK - UNITS 1 AND 2 3.3-16 Amendment No. 99, 145

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3Boi)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

9. Pressurizer Water i(g) 3 M SR 3.3.1.1 < 93.9% of Level - High SR 3.3.1.7 instrument span SR 3.3.1.10

10. Reactor Coolant i(g) 3 per loop M SR 3.3.1.1 >88.6% of indicated Flow - Low SR 3.3.1.7 loop flow (Unit 1)

SR 3.3.1.10 >_88.8% of indicated SR 3.3.1.16 loop flow (Unit 2)

11. Not Used

12. Undervoltage i(g) 1 per bus M SR 3.3.1.9 > 4753.V RCPs SR 3.3.1.10 SR 3.3.1.16

13. Underfrequency l(g) 1 per bus M SR 3.3.1.9 >57.06 Hz RCPs SR 3.3.1.10 SR 3.3.1.16

14. Steam Generator 1,2 4 per SG E SR 3.3.1.1 >37.5%### of (SG) Water Level SR 3.3.1.7 narrow range Low-Low (I) SR 3.3.1.10 instrument span SR 3.3.1.16 (Unit 1)(q)(r)

> 34.9% of narrow range instrument span (Unit 2) (q)(r)

15. Not Used.

(continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(g) Above the P-7 (Low Power Reactor Trips Block) interlock.

(I) The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

Fer Ui't 1, through GCyce narow ano ictmentatiOn.

13, the ALLOWABLE VALUE tor ýitea ,,.. .......ator Lc L.o .

Low rcm.ai.. at 36% o. ; I COMANCHE PEAK - UNITS 1 AND 2 3.3-17 Amendment No. 64,4-34,145

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 o-7)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

16. Turbine Trip

a. Low Fluid Oil 16() 3 0 SR 3.3.1.10 >46.6 psig Pressure SR 3.3.1.15

b. Turbine Stop 16() 4 p SR 3.3.1.10 Ž1% open Valve Closure SR 3.3.1.15

17. Safety 1,2 2 trains Q SR 3.3.1.14 NA Injection (SI) Input from Engineered Safety Feature Actuation System (ESFAS)

18. Reactor Trip System Interlocks

a. Intermediate 2(e) 2 S SR 3.3.1.11 _>6E-1 1 amp Range SR 3.3.1.13 Neutron Flux, P-6 1 per train T SR 3.3.1.5 NA

b. Low Power Reactor Trips Block, P-7 1 4 T SR 3.3.1.11 < 50.7% RTP

c. Power Range SR 3.3.1.13 Neutron Flux, P-8 1 4 T SR 3.3.1.11 < 52.7% RTP

d. Power Range SR 3.3.1:13 Neutron Flux, P-9 1,2 4 S SR 3.3.1.11 > 7.3% RTP and

e. Power Range SR 3.3.1.13 _<12.7% RTP Neutron Flux, P-10 2 T SR 3.3.1.10 < 12.7% turbine

f. Turbine First SR 3.3.1.13 power Stage Pressure, P-13 (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.

(j) Above the P-9 (Power Range Neutron Flux) interlock.

COMANCHE PEAK - UNITS 1 AND 2 3.3-18 Amendment No. 64,145

RTS Instrumentation

.3.3.1 Table 3.3.1-1 (page 5o ý)

Reactor Trip System Instrumentation APPLICABLE MODES OR

. OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

19. Reactor Trip 1,2 2 trains R SR 3.3.1.4 NA Breakers(RTBs)(k) 3 (b), 4 (b), 5(b) 2 trains C SR 3.3.1.4 NA

20. Reactor Trip 1,2 1 each per U SR 3.3.1.4 NA Breaker RTB Undervoltage and Shunt Trip Mechanisms(k) 3 (b), 4 (b), 5 (b) 1 each per C SR 3.3.1.4 NA RTB

21. Automatic Trip 1,2 2 trains Q SR 3.3.1.5 NA Logic 3(b), 4(b), 5 (b) 2 trains C SR 3.3.1.5 NA (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(k) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

COMANCHE PEAK - UNITS 1 AND 2 3.3-19 Amendment N6. 64,145

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 )

Reactor Trip System Instrumentation Note 1: Overtemperature N-16 (For Unit 1 Cycle 13, see I'oto 2)

The Overtemperature N-16 Function Allowable Values shall not exceed the following setpoint by more than 0.5% N-16 span for N-16 input, 0.5% Tmcodspan for TCO.d input, 0.5% pressure span for pressure input, and 0.5% Aq span for Aq input.

Qsetpoint =K,- K2L+' TcS) - TJ K-f(P-P1)f(Aq)

Where:

Qsetpolnt = Overtemperature N-16 trip setpoint, K1 =

K2 = */OF K3 = */psig Tc = Measured cold leg temperature, OF Tc° = Indicated reference Tc at RATED THERMAL POWER, *OF P = Measured pressurizer pressure, psig P1 >

psig (Nominal RCS operating pressure) s = the Laplace transform operator, sec1 .

T1 ,J2 = Time constants utilized in lead-lag controller for T.,

Tl,

sec, and T2 <

sec fl(Aq) =

{(qt- qb) + when (qt - qb) < *% RTP 0% when *% RTP < (qt - qb) < *% RTP

{(qt- qb) - when (qt - qb) >-*% RTP

as specified in the COLR (eeG ed)

COMANCHE PEAK - UNITS 1 AND 2 3.3-20 Amendment No. 67,145

RTS Instrumentatio

3. .1 Table 3.3.1-1 (page 7 of 7)

Reactor Trip System Instrumentation Note 2: The Overtemperature N-16 Function Allowable Value shall not exceed the following setpoint by more t n 1.72% of span.

setpoint =KT -SK2 Q~~p,.=K-K

[ (1+T S) i-+--- 21s)T m* +3 01 (P p )_f,(A q)

Where:

Qsetpoint = Overtemperature N-16 trip setpoint, Ki =

0 K2 = */ F K3 = */psig Tc = Measured cold leg temperature T00° = Indicated reference Tc at RATED THERMAL POWER, *°F P = Measured pressurizer pressure, psig P 1,

psig (Nominal RCS operating pressure) s = the Laplace transform operator, sec1 .

S,2= Time constants utilized in lead-lag controller Tc, T>* sec, and T2 <* sec f1(Aq) =

{(qt- qb) + *%} when (qt - q ! *% RTP 0% when *% P < (qt - qb) < *% RTP

{(qt- qb) - *%} when (q qb) *% RTP

as specified in the COLR MANCHE PEAK - UNITS 1 AND 2 3.3-20a Amendment No. 145

ESFAS Instrumentation 3.3.2 ACTIONS (continued CONDITION REQUIRED ACTION COMPLETION TIME I. One channel inoperable. ------------------- NOTE ---------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

1.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 1.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months J. One Main Feedwater Pump J.1 Place channel in trip. 6 hourk--J trip channel inoperable.

OR J.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months K. One channel inoperable. -------------- NOTE ---------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

K.1 Place channel in bypass. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR K.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND K.2.2 Be in MODE 5. 108 hours0.00125 days 0.03 hours 1.785714e-4 weeks 4.1094e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-25 Amendment No. 64,444,121

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

1. Safety Injection.

a. Manual 1,2,3,4 2 B SR 3.3.2.8 NA Initiation

b. Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays

c. Containment 1,2,3 3 D SR 3.3.2.1 _ 3.8 psig Pressure -- SR 3.3.2.5 High 1 SR 3.3.2.9 SR 3.3.2.10

d. Pressurizer 1, 2, 3(b) D SR 3.3.2.1 > 1803.6 psig Pressure -- SR 3.3.2.5 Low SR 3.3.2.9 SR 3.3.2.10

e. Steam Line 1, 2, 3(b) 3 per steam D SR 3.3.2.1 > 594.0 psig(c)

Pressure line *SR 3.3.2.5 (Unit 1)

Low SR 3.3.2.9 > 578.4 psig(c)

SR 3.3.2.10 (Unit 2)

2. Containment Spray

a. Manual 1,2,3,4 2 per train, B SR 3.3.2.8 NA Initiation 2 trains

b. Automatic 1,2,3,4 2 trains C. SR 3.3.2.2 NA Actuation Logic SR'3.3.2.4 and Actuation SR 3.3.2.6 Relays

c. Containment 1,2,3 4 E SR 3.3.2.1 *18.8 psig Pressure SR 3.3.2.5 High -- 3 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the limiting safety system setting except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) interlock and below P-11, unless the Function is blocked.

(c) Time constants used in the lead/lag controller are T1>_ 10 seconds and T2 *<5 seconds. For Unit 1, Cycle 13

4Ž_50 se condr .

COMANCHE PEAK - UNITS 1 AND 2 3.3-29 Amendment No. 64,145

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

4. Steam Line Isolation

a. Manual 1, 2 (i), 3 (i) 2 F SR 3.3.2.8 NA Initiation

b. Automatic 1, 2 (i), 3 (i) 2 trains G SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays

c. Containment 1, 2 (i), 3 (i) 3 D SR 3.3.2.1 *6.8 psig Pressure-- SR 3.3.2.5 High 2 SR 3.3.2.9 SR 3.3.2.10

d. Steam Line Pressure (1) Low 1, 2 (i), 3 (b)(i) 3 per steam D SR 3.3.2.1 > 594.0 psig(c) line SR 3.3.2.5 (Unit 1)

SR 3.3.2.9 _>578.4 psig(c)

SR 3.3.2.10 (Unit 2)

(2) Negative 3(g)(i) 3 per steam D SR 3.3.2.1 < 178.7. psi(h)

Rate -- line SR 3.3.2.5 High SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the limiting safety system setting except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11, unless the Function is blocked.

(c) Time constants used in the lead/lag controller are Ti> 10 seconds and T2 *5 seconds. For Unit 1, CYclo 13 T4Ž! 50 6eGend..

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-11 when safety injection on steam line pressure-low is not blocked.

(h) Time constant utilized in the rate/lag controller is > 50 seconds.

(i) Except when all MSIVs and their associated upstream drip pot isolation valves are closed and deactivated.

COMANCHE PEAK - UNITS 1 AND 2 3.3-31 Amendment No. 64,145

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Turbine Trip and Feedwater Isolation

a. Automatic 1,20) 2 trains H SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 eiete #

Relays

_ _ __4

b. SG Water 1,20) 3 per SG(P) I SR 3.3.2.1 -<84.5%1.,40 Level -- High SR 3.3.2.5 narrow range span High (P-14) SR 3.3.2.9 (Unit 1) (q)(r)

SR 3.3.2.10 < 82.0% of narrow range span (Unit 2) (q)(r)

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(continued)

(a) The Allowable Value defines the limiting safety system setting except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

() Except when all MFIVs and associated bypass valves are closed and de-activated or isolated by a closed manual valve.

(p) A channel selected for use as an input to the SG water level controller must be declared inoperable.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determin'the as-left tolerance shall be specified in the Technical Specification Bases.

'Uttu yrie 13, the ALLOWABLE VALUE fer the SG Water Level High High romainc ;A860 of narrow Fange 6paR.

COMANCHE PEAK - UNITS 1 AND 2 3.3-32 Amendment No. 64, 434,145

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

6. Auxiliary Feedwater

a. Automatic 1,2, 3 2 trains G SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (Solid State Protection System)

b. Not Used. IDelete

c. SG Water 1,2,3 4 per SG D SR 3.3.2.1 >37. 5 o/o of Level Low-Low SR 3.3.2.5 narrow range span SR 3.3.2.9 (Unit 1) (q)(r)

SR 3.3.2.10 >34.9% of narrow range span (Unit 2) (q)(r)

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

e. Loss of Offsite 1,2, 3 1 per train F SR 3.3.2.7 NA Power SR 3.3.2.9 SR 3.3.2.10

f. Not Used.

g. Trip of all Main 1, 2 2 per AFW J SR 3.3.2.8 NA Feedwater pump Pumps

h. Not Used.

(continued)

(a) The Allowable Value defines the limiting safety system setting except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined as-found acceptance criteria band, then the channel shall be evaluated to verify that it is functioning asrequired before returning the channel to service.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a va!ue that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

1. i For Unit 1, through Cycle 13, the ALLOWABL1-E VALUE for tho SG .wfato~r Lovoil LOW LOW roaieR;-R at 36% of nIro FanG paiR.

COMANCHE PEAK - UNITS 1 AND 2 3.3-33 Amendment No. 64, 434,145

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

7. Automatic Switchover to Containment Sump

a. Automatic 1,2,3,4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays K

IDelete "(b)'"

SR 3.3.2.1

b. Refueling 1,2,3,4 4 Water Storage SR 3.3.2.5 instrument span Tank (RWST) SR 3.3.2.9 Level - Low SR 3.3.2.10' Low Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection

8. ESFAS Interlocks

a. Reactor Trip, 1,2,3 1 per train, 2 F SR 3.3.2.11 NA P-4 trains

b. Pressurizer 1,2,3 3 L SR 3.3.2.5 < 1975.2 psig Pressure, P-1I SR 3.3.2.9 (Unit 1)

< 1976.4 psig (Unit 2)

(a) The Allowable Value defines the limiting safety system setting except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) The Un~it 1 RW.ST Leve'l Lovi Low.A AlIeviablc Value w~ill romair; > 43.9,1 instrumcnet rspan until comRplotiGn of CYce12 COMANCHE PEAK - UNITS 1 AND 2 3.3-34 Amendment No. 4-25,4-29,145

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings

> 24101 psig and < 2485- psig.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures > 320°F

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

The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety A.1 Restore valve to 15 minutes valve inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months RCS cold leg Two or more-pressurizer temperatures < 320 0 F.

safety valves inoperable.

ForF Unit 1. throuah CYcle 13. the throo DroeGUriZeF safoty Yalve lift settinas shall be N J 246 psig and 2610 Psici tor theo Limnitin oniioo perat'on.

COMANCHE PEAK - UNITS 1 AND 2 3.4-21 Amendment No. 64,145

RCS Specific Activity 3.4.16 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. DOSE EQUIVALENT ------------- NOTE ----------

XE-1 33 not within limit. LCO 3.0.4.c is applicable.

B.1 Restore DOSE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months EQUIVALENT XE-1 33 to within limit.

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 A or B AND not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR DOSE EQUIVALENT 1-131

> 60 ýtCi/gm.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 --------------------- NOTE --------------------- 7 days Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT XE-1 33 specific activity < 500 pCi/gm.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-45 Amendment No. 64,137

PEAK - UNITS I AND 2 3.4-47 Amendment No. 64,137 ECCS-- Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.5.2.6 Verify each ECCS pump starts automatically on an 18 months actual or simulated actuation signal.

I/1 SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each 18 months mechanical position stop is in the correct position.

Valve Number 8810A 8816A 8822A 8810B 8816B I 8810C 8816C I 8810D 8816D88 I8816A SR 3.5.2.8 Verify, by visual inspection, each ECCS train 18 months containment sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.

COMANCHE PEAK - UNITS 1 AND 2 3.5-7 Amendment No. 64,129

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves be OPERABLE.

isolation valve shall n Each containment LCO 3.6.3 APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS by Actions for systems made inoperable Conditions and Required

3. Enter applicable valves.

containment isolation when Actions of LCO 3.6.1, "Containment," acceptance Conditions and Required the overall containment leakage rate

4. Enter applicable results in exceeding isolation valve leakage (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-7 Amendment No. 64

CREFS 3.7.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Place OPERABLE Immediately associated Completion CREFS train in Time of Condition A not emergency recirculation met in MODE 5 or 6, or mode.

during movement of irradiated fuel assemblies. OR D.2.1 Suspend CORE Immediately ALTERATIONS.

D.2.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CREFS trains E.1 Suspend CORE Immediately inoperable in MODE 5 or 6, ALTERATIONS.

or during movement of irradiated fuel assemblies. AND OR E.2 Suspend movement of Immediately irradiated fuel One or more CREFS trains assemblies.

inoperable due to an inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies.

F. Two CREFS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

(

COMANCHE PEAK - UNITS 1 AND 2 3.7-24 Amendment No. 64, 408, 42-0,136

CRACS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room Air Conditioning System (CRACS)

LCO 3.7.11 Two CRACS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

(

A. One CRACS train A.1 Restore CRACS train to 30 days inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met AND in MODE 1, 2, 3, or 4.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE Immediately associated Completion CRACS train in operation.

Time of Condition A not met in MODE 5, or 6, or during OR movement of irradiated fuel assemblies. C.2.1 Suspend CORE Immediately ALTERATIONS.

C.2.2 Suspend movement of Immediately irradiated fuel assemblies.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-26 Amendment No. 64

CRACS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACS trains D.1.1 Verify at least 100% of the Immediately inoperable in MODE 5 or 6, required heat removal or during movement of capability equivalent to a irradiated fuel assemblies, single OPERABLE train available.

D.1.2 Restore the CRACS trains 30 days to OPERABLE status.

OR D.2.1 Suspend CORE Immediately ALTERATIONS.

D.2.2 Suspend movement of Immediately irradiated fuel assemblies.

E. Two CRACS trains E.1.1 Verify at least 100% of the Immediately inoperable in MODE 1, 2, 3, required heat removal or 4. capability equivalent to a single OPERABLE train available.

E.1.2 Restore one CRACS train 30 days to OPERABLE status. 1 66 OR E.2 Enter LCO 3.0.3. Immediately COMANCHE PEAK - UNITS 1 AND 2 3.7-27 Amendment No. 66

Spent Fuel Assembly Storage 3.7.17 Decay 65000 Time:

74 0 Years 87 60000 55000 50000 45000 C- 40000 a.

35000 E

U. 30000 E

Z I/0 4 25000

'ii 20000 15000 10000 5000 0

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

FIGURE 3.7.17-1 Fuel Assembly Burnup vs. U-235 Enrichments vs. Decay Time Limits For a 4 out of 4 Storage Configuration in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-38 Amendment No. 87

Spent Fuel Assembly Storage 3.7.17 45000 Decay Time:

74 87 0 Years 40000 35000 30000 25000 20000 E

1

= 15000 10000 5000 0

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

/-(page 1of 1)

Figure 3.7.17-2 Minimum Burnup vs. Initial U-235 Enrichment vs. Decay Time For a 3 out of 4 Storage Configuration in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-39 Amendment No. 87

Spent Fuel Assembly Storage 3.7.17 17 20000 74 87 I~tIII~Th~

I -iii i+ 1+ I -t---!i -t 1 111 1 1-1 Z4-1.f-15000 ACCETABLE I-20.

CL

" 10000

.0 E

(n 4)

L.

5000 UNACCEPTABLE

. 0 2.8 3.0 3.2 . 3.4 3.6 3.8 4.0 4.2 4.4 4.6 4.8 5.0 Initial U-235 Enrichment (w/o)

Figure 3.7.17-3 Minimum Burnup vs. Initial U-235 Enrichment For a 2 out of 4 Storage Configuration in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-40 Amendment No. 87

Spent Fuel Assembly Storage 3.7.17 A A A A A A B B B 74 A A A A A A B B B B B B 87 A A A A A A B B B A A A A A A B B B B B B A A A A A A B B B A A A A A A B B B B B B C C C C C C D D D C C C C C C D D D C C C C C C D D D A Region 11 (4/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-1.

B Region 11 (3/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-2.

C Region 11 (2/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-3.

D Region 11 (1/4), new or partially spent fuel assemblies which are stored in an expanded checkerboard (1 out of 4).

empty Note: All possible 2 by 2 matrices containing Region II rack cells shall~comply with at least one of the following: (1) within the "acceptable" domain of Figure 3.7.17-1 in a 4 out of 4 configuration, (2) within the "acceptable" domain of Figure 3.7.17-2 in a 3 out of 4 configuration, (3) within the "acceptable" domain of Figure 3.7.17-3 in a 2 out of 4 configuration, or (4) a 1 out of 4 configuration.

Region I and Region II interface restrictions: The Region II 1 out of 4 configuration shall be oriented such that the single fuel assembly resides in the internal row with the empty cells facing Region I. There are no interface restrictions between the Region 11 (2/4, 3/4, 4/4) and Region I configurations.

(page 1of1)

Figure 3.7.17-4 Storage Configurations (4/4, 3/4, 2/4, 1/4) in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-41 Amendment No. 87

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains > 86,000 gal 31 days (MODES 1-4) or 75,000 gal (MODES 5 & 6) of fuel.

SR 3.8.3.2 -------------------- NOTE ------------------- 31 days Not required to be performed until the engine has 75 been shutdown for> 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months .

Verify lubricating oil inventory is > a level 1.75" below 31 days the low static level on the lube oil dipstick.

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the the Diesel Fuel Oil limits of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is 31 days

> 180 psig.

SR 3.8.3.5 Check for and remove accumulated water from each 31 days fuel oil storage tank.

COMANCHE PEAK - UNITS 1 AND 2 3.8-23 Amendment No. 75

Design Features 4.0 4.0 DESIGN FEATURES 4.3.1.1 (I ntinu. d)

(I New or partially spent fuel assemblies with a discharge 14.3 Fuel Storage (continued) burnup in the "acceptable" domain of Figure 3.7.17-3 may 74 be allowed restricted storage in a 2 out of 4 configuration 87 in Region IIfuel storage racks as shown in Figure 3.7.17-4.

4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. keff < 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR; C. keff < 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR; and

d. A nominal 21 inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 Drainage The spent fuel storage pools are designed and shall be maintained to prevent inadvertent draining of the pool below elevation 854 ft.

4.3.3 Capacity The spent fuel storage pools are designed and shall be maintained with a storage capacity limited to no more than 3373 fuel assemblies. 74 87 COMANCHE PEAK - UNITS 1 AND 2 4.0-3 Amendment No. 87

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 andE 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.

COMANCHE PEAK - UNITS 1 AND 2 5.0-6 Amendment No. 64

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Report required by Specification 5.6.2 and Specification 5.6.3.

E' Licensee initiated changes to the ODCM:

Shall be documented and records of reviews performed shall be retained.

This documentation shall contain:

sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s), and

-7f-*. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

-. Shall become effective after the approval of the Plant Manager; and (continued)

COMANCHE PEAK - UNITS I AND 2 5.0-7 Amendment No. 64,134

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.1 Offsite Dose Calculation Manual (ODCM) (continued)

Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e., month and year) the change was implemented.

5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the post accident recirculation portion of the Containment Spray System, Safety Injection System, Chemical and Volume Control System, RHR System and RCS Sampling System (Post Accident Sampling System portion only until such time as 91 a modification eliminates the PASS penetration as a potential leakage path). The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.3 Not Used 91 (continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-8 Amendment No. 91

Programs and Manuals 5.,

5.5 Programs and Manuals (continued) 5.5.9 Steam Generator (SG) Program 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Progqram Each steam generator shall be demonstrated OPERABLE by pe mance of the following augmented inservice inspection program.

The provisions of SR 3.0.2 are applicable to the SG Surveill ce Program test frequencies.

a. Steam Generator Sample Selection and Ins pec "n - Each steam generator shall be determined OPERABLE d ing shutdown by selecting and inspecting at least the minimum numbe of steam generators specified in Table 5.5-1.

b. Steam Generator Tube Sample Selec n and Inspection - The steam generator tube minimum sample siz , inspection result classification, and the corresponding action required all be as specified in Table 5.5-2 or 5.5-3. Table 5.5-2 applies to all bes except repaired tubes (Unit 1 only) which are covered by Table 5 The inservice inspection of steam generator tubes shall be perf rmed at the frequencies specified in Specification 5.5.9.1d., an he inspected tubes shall be verified acceptable per the accep ance criteria of Specification 5.5.9.1e. The tubes selected for eac nnservice inspection per Table 5.5-2 shall include at least 3% of all the panded tubes and at least 3% of the remaining number of tubes in I steam generators; the tubes selected for these inspections shle selected on a random basis except:

1. Where experience in similar plants with similar water chemistry indic tes critical areas to be inspected, then at least 50% of the tu s inspected shall be from these critical areas;

2. he first sample of tubes selected for each inservice inspection (subsequent to the preservice inspection) of each steam generator shall include:

a) All nonplugged tubes that previously had detectable wall penetrations (greater than 20%),

b) Tubes in those areas where experience has indicated potential problems, and (continued)

C /MANCHE PEAK- UNITS 1 AND 2 5.0-13 Amendment No. 83,128

Programs and Manual

.-5 5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued) c) A tube inspection (pursuant to Specification 5. .9.1e.1.h) shall be performed on each selected tube. I any selected tube does not permit the passage of the e y current probe for a tube inspection, this shall be corded and an adjacent tube shall be selected and su jected to a tube inspection.

d) Indications left in service as a res It of the application of the tube support plate voltage r pair criteria shall be inspected by bobbin probe du ng all future refueling outages.

3. The tubes selected as the seco d and third samples (if required by Table 5.5-2 during each in rvice inspection may be subjected to a partial tube inspection ovided:

a) The tubes select d for these samples include the tubes from those are of the tube sheet array where tubes with imperfections ere previously found, and b) The insp tions include those portions of the tubes where imperfe ions were previously found.

4. Implement on of the steam generator tube/tube support plate repair crit ia requires a 100% bobbin coil inspection for hot-leg and col leg tube support plate intersections down to the lowest cold-I support with known outside diameter stress corrosion cra g (ODSCC) indications. The Determination of the lowest co,7leg tube support plate intersections having ODSCCo dications shall be based on the performance of at least a 20%

random sampling of the tubes inspected over their full length.

f lowing three categories:

Category Inspection Results C-1 Less than 5% of the total tubes inspected are degraded tubes and none of the inspected tubes are defective.

(continued)

C ANCHE PEAK - UNITS 1 AND 2 5.0-14 Amendment No. 74,128

Programs and Manual 5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

C-2 One or more tubes, but not more than 1% of th total tubes inspected are defective, or between 50/Xand 10% of the total tubes inspected are degraded tube.

C-3 More than 10% of the total tubes inspect are degraded tubes or more than 1% of the inspected ubes are defective.

Note: In all inspections, previously degraded t es must exhibit significant (greater than 10%) further w1ll penetrations to be included in the above percentage cal lations.

c. Steam Generator F* Tube Inspection (Ut 1 only) - In addition to the minimum sample size as determined b/Specification 5.5.9.1b., all F*.

tubes will be inspected within the tub e'sheet region. The results of the inspections of F* tubes identified in. 1revious inspections will not be a cause for additional inspections p r Tables 5.5-1 and 5.5-2.

d. Inspection Frequencies - The bove required inservice inspections of steam generator tubes shall e performed at the following frequencies:

1. The first inservic inspection shall be performed after 6 Effective Full Power Mo s (EFPM) and before 12 EFPM and shall include a special insp ction of all expanded tubes in all steam generators.

Subseque inservice inspections shall be performed at intervals of not les han 12 nor more than 24 calendar months after the previou inspection. If two consecutive inspections, not including the pr ervice inspection, result in all inspection results falling into the -1 category or if two consecutive inspections demonstrate th previously observed degradation has not continued and no ditional degradation has occurred, the inspection interval may e extended to a maximum of once per 40 months;

2. If the results of the inservice inspection of a steam generator conducted in accordance with Table 5.5-2 at 40-month intervals fall in Category C-3, the inspection frequency shall be increased to at least once per 20 months. The increase in inspection frequency shall apply until the subsequent inspections satisfy the criteria of Specification 5.5.9. ld.1; the interval may then be extended to a maximum of once per 40 months; and (continued)

C MANCHE PEAK - UNITS 1 AND 2 5.0-15 Amendment No. -74,128

Programs and Manual 5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

3. Additional, unscheduled inservice inspections shall be erformed on each steam generator in accordance with the firs sample inspection specified in Table 5.5-2 during the shut wn subsequent to any of the following conditions:

a) Primary-to secondary tube leaks (not/ cluding leaks originating from tube-to-tube sheet elds) in excess of the limits of Specification 3.4.13, or b) A seismic occurrence greater an the Operating Basis Earthquake, or c) A loss-of-coolant accide requiring actuation of the Engineered Safety Fea res, or d) A main steam line feedwater line break.

e. Acceptance Criteria

1. As used in this spe ication:

a) Im erfectio eans an exception to the dimensions, finish, or contour of tube from that required by fabrication drawings or s pecific ons. Eddy-current testing indications below 20% of the no inal tube wall thickness, ifdetectable, may be cons' ered as imperfections; b) D.radation means a service-induced cracking, wastage, ear, or general corrosion occurring on either inside or outside of a tube; c) Degraded Tube means a tube containing imperfections greater than or equal to 20% of the nominal wall thickness caused by degradation; d) % Degradation means the percentage of the tube wall thickness affected or removed by degradation; e) Defect means an imperfection of such severity that it exceeds the plugging limit or (for Unit 1 only) repair limit. A tube containing a defect is defective; (continued)

/MANCHE PEAK - UNITS 1 AND 2 5.0-15a Amendment No. 89, 128

S Programs and Manuals 5 5.5 Programs and Manuals /

(continued)

(SG) Progqram Generator D4 Steam

.9.1 Unit 1 Model 5.5 f) Plugging or Repair Limit means the imperfection de th at or beyond which the tube shall be removed from se ce by plugging or (for Unit 1 only) repaired by sleeving nd is equal to 40% of the wall thickness. The plugging limi or laser welded sleeves is equal to 43% of the nomina, wall thickness.

The plugging limit for Leak Tight sleeves is qual to 20% of the nominal wall thickness. This definitioný oes not apply to that portion of the Unit 1 tubing that meet the definition of an F* tube. This definition does not apply t tube support plate intersections for which the voltage-bas d plugging criteria are being applied. Refer to 5.5.9.1e.1m) r the repair limit applicable to these intersections. A tubes repaired with Leak Limiting sleeves shall be plu ed upon detection of degradation in the sleeve and/or ressure boundary portion of the original tube wall in the sI eve/tube assembly (i.e., the sleeve-to-tube joint) regardlesrof depth. The F* criteria is not applicable to the parent tbe located behind tube the Leak or if it leaks Limiting sleeves installed in condition e tubesheet of a transition zone; integrity describes/te to affec t its structural g) Unserviceable nough contains a defectf/large,ating Basis Earthquake, a r f ee dw a te r l ine in the event of an Ope, id, nt , r a st a in e o ld.3, above;

-co o lan t ac c Specification 5.5.9.

.lo s s -ofas break specified/ generator inspection of the steam around the neans an completely Inspection leg side) h) Tube ~et end (hot a tube repaired tube from the/g of the cold leg. For shall include supportthe tube; tube inspection U-bend to the/{op *or Unitof1 only) the by sleeving the sleevedportion of the full length means an inspection e Inspection ed by eddy i) Preserv m g nrator perform i a h se e and in ed tube a b lthe t e stshall ba s elent a perform is hbeequipm of eac r t o si r i i se etion ing cu rr e lt t ec h ni ue supi iOPERATION T us n ft ER g. inservice con pr ii oiiilPOW e s d d rn subsequent ex e t d t N. 1-12,12 t h i u s menmet

,/,spections; .0-6 histance of the hard roll length Ui 1o l )i vdesa sufficient tube NIT 1AND2F* D sa c ANCE EAK- fat b hc r eist pullout of the portio n e *p dnsi a n ct is e q u a l t o 1.13 in ch es ,

he f r o h -duegs haeeet . u

/ / expanded t masurem ent uncertainty, or the

/ of non n e f re dy c re of the tubesheet, pl s a low the top down from in elevation.

is measured itio, whcever is lower tube located

~and of the roll transo p lc b et the parent the tubesheet in Sbottom F rtrai e k L mtng se v sisalled SThe ind th e Sbeh re t rt a dit n e e ua;o o dera daition beownhe*

C- e(continued

Programs and Manua

.5 5.5 Programs and Manuals ..

5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

I) Hard Roll Expansion (Unit 1 only) is that portion o a tube which has been increased in diameter by a rolli process such that no crevice exists between the outsid diameter of the tube and the hole in the tubesheet; and m) For Unit 1 only, the Tube Support Plate u in Limit is used for the disposition of alloy 600 steam g erator tubes for continued service that are experienci predominantly axially oriented outside diameter stress co osion cracking confined within the thickness of the tube s port plates and flow distribution baffle (FDB). At tub pport plate intersections (and FDB), the plugging limit i based on maintaining steam generator tube serviceability s described below:

1. Steam generator tub , whose degradation is attributed to outside diameter str ss corrosion cracking within the bounds of the tub support plate with bobbin voltages less than or equal be allowed to to e lower

,main voltage repair limit (1.0 volt), will in service.

2. Steam gen rator tubes, whose degradation is attributed to outside d meter stress corrosion cracking within the bounds f the tube support plate with the bobbin voltage great than the lower voltage repair limit (1.0 volt), will be rep red, except as noted in 5.5.9.1e.1m)3. below.

3. team generator tubes with indications of potential degradation attributed to outside diameter stress corrosion cracking within the bounds of the tube support plate with a bobbin voltage greater than the lower voltage repair limit (1.0 volt) but less than or equal to the upper voltage repair limit*, may remain inservice if a rotating pancake coil inspection does not detect degradation. Steam generator tubes, with indications of outside diameter stress corrosion cracking degradation with a bobbin voltage greater than the upper repair limit** will be plugged or repaired.

(continued)

The u er voltage repair limit is calculated according to the methodology in GIL 95-05 as V u* will differ at the TSPs and flow distribution baffle.

C/MANCHE PEAK - UNITS 1 AND 2 5.0-16a Amendment No. 74, 128

Programs and M anual 71 5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

4. Certain intersections as identified in WPT-159 will be excluded from application of the voltage-bas repair criteria as it is determined that these interse tions may collapse or deform following a postulated/ CA + SSE event.

5. If an unscheduled mid-cycle inspectio is performed, the following mid-cycle repair limits appl instead of the limits identified in 5.5.9.1e.1.m)l., 5.5.9. e.1.m)2., and 5.5.9.1e.1 .m)3. The midcycle rep ir limits are determined from the following equations:

-- VSL V ......

1.0+NDE+Grr CL*

=V ( VLL )CL~t VLRL .CL-At (VU VMLRL = VMURL where:

VURL = upper voltage rep air limit VLRL - lower voltage rep air limit VMURL - mid-cycle upper v'oltage limit based on time into cycle VM L = mid-cycle lower v oltage repair limit based on VMLRL aind time into cycle

= length of time sinice last scheduled inspection during which VURL and VLRL were implem ented CL = cycle length (the ttime between two scheduled steam generator inspections)

VSL = structural limit vol tage Gr = average growth p er cycle NDE = 95-percent cumul ative probability allowance for non destructive examination unce rtainty (i.e., a value of 20-perce nt has been approved by theI NRC)

Implementation of these mid-cycle r epair limits should follow the same approach as in TS 5.5.9.1 e.1.m)1.,

5.5.9.1 e.1 m)2., and 5.5.9>1 e.1.m)3.

n. Tube Renai (for Unit 1 only) refers to the pirocess that establishes tube serviceability. Acceptable tube repairs will be performed in accordance with the proce, ss described in Westinghouse WCAP-1 3698, Rev. 3 and VW testinghouse Letter WPT-16094 dated March 20, 2000, VVCAP-1 5090, Rev. 1, CEN-630-P, Rev. 2 dated June 199 7, and WCAP-15918, Rev. 1, dated January, 2004.

(continued)

/MANCHE PEAK - UNITS 1 AND 2 5.0-17 Amendment No. 44.2,128

Programs and Manualss 55.

5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Progqram (continued)

2. The steam generator shall be determined OPERABLE a r completing the corresponding actions (plug all tubes ex eeding the plugging limit and all tubes containing through-wall cr ks) required by Table 5.5-2 and Table 5.5-3.

(continued)

MANCHE PEAK - UNITS 1 AND 2 5.0-17a Amendment No. 4-04, 128

Programs and Manual X-5 5.5 Programs and Manuals

)

5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Procram (continued)

TABLE 5.5-1 MINIMUM NUMBER OF STEAM GENERATORS TO BE INSPECTEFD DURING INSERVICE INSPECTION J

Preservice Inspection Four No. of Steam Generators per Unit Four First Inservice Inspection Two)U Second & Subsequent Inservice Inspections On TABLE NOTATIONS

1. The two steam generators that were not ins cted during the first inservice inspection shall be inspected dur" g the second and third inspections, one in each inspection perio . For the fourth and subsequent inspections, the inservice i spection may be limited to one steam generator on a rotating sched e encompassing 12% of the tubes if the results of the previous inspec i ns of the four steam generators indicate that all steam generators re performing in a like manner. Note that under some circumstances he operating conditions in one or more steam generators may be fou d to be more severe than those in other steam generators. Under s h circumstances the sample sequence shall be modified to inspe the most severe conditions.

PEAK - UNITS 1 AND 2 5.0-18 Amendment No. 64, 128

Programs and Manuals 5

5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

TABLE 5.5-2 STEAM GENERATOR TUBE INSPECTION 1 ST SAMPLE 2 ND SAMPLE 3 R SAMPLE INSPECTION INSPECTION I SPECTION Sample Result Action Result Action R sult Action Isize __ Required __ Required Required

/

A C-1 None N.A. N.A. N.A. N.A.

minimum :,-

of C-2 Plug or repair* C-1 None / N.A. N.A.

S Tubes defective tubes per S.G. and inspect C-2 Plug or rep ir* C-1 None additional 2S defective ubes tubes in this S.G. and ins ect C-2 Plug or repair*

additi al 4S defective tubes tub in this S.G.

C-3 Perform action for C-3 result of first sample C- Perform action for C-3 result of first sample N.A. N.A.

C-3 Inspect all tubes /11 other None N.A. N.A.

in this S.G., plug, S.G.s are or repair* C-1 defective tubes and inspect 2 Some Perform action for N.A. N.A.

tubes in eac S.G.s C-2 C-2 result of other S.G. but no second sample additional S.G. C-3 Additional Inspect all tubes N.A. N.A.

S.G. is in each S.G. and C-3 plug or repair*

defective tubes.

(continued)

S = 12/n0 ! Where n is the number of steam generators inspected during an inspection

for Un' 1 only CMANC'HE PEAK - UNITS 1 AND 2 5.0-19 Amendment No. 4-Wa, 128

Programs and Manual 5'

5.5 Programs and Manuals 5.5.9.1 Unit 1 Model D4 Steam Generator (SG) Program (continued)

TABLE 5.5-3 STEAM GENERATOR REPAIRED TUBE INSPECTION FOR UNIT 1 NLY 16T SAMPLE INSPECTION 2ND SAMPLE INSPIECTION Sample Size Result Action Required Result Actio Required A minimum C-1 None N.A. N.A.

of 20% of repaired tubes (1) //

C-2 Plug defective repaired C-1 None tubes and inspect 100%

of the repaired tubes in this S.G.

C- Plug defective repaired tubes CA Perform action for C-3 result of

/70 first sample C-3 Inspect all repaired tubes Ayother None in this S.G., plug B.G.s are defective tubes and C-1 inspect 20% of the repaired tubes in eac Same Perform action for C-2 result of other S.G. S.G.s C-2 first sample but no additional S.G. are C-3 Additional Inspect all repaired tubes in S.G is C-3 each S.G. and plug defective tubes.

~(continued)

(1) Each repair me od is considered a separate population for determination of initial C ANCHE PEAK - UNITS 1 AND 2 5.0-19a Amendment No. 403, 128

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9/ Unit 1 Model D76 and Unit 2 Model D5 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes.

Condition monitoring assessments shall be conducted during each outage during which the SG tubes are inspected or plugged to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, 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 1 gpm per SG.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-19b Amendment No. 128

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9/. Unit 1 Model D76 and Unit 2 Model D5 Steam Generator (SG) Program (continued)

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,. For the Unit 2 model D5 steam generators (Alloy 600 thermally treated) inspect 100% of the tubes at sequential periods of 120, 90, 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 48 effective full power months or two refueling outages (whichever is less) without being inspected.]

For the Unit 1 model Delta-76 steam generators (Alloy 690 thermally treated) 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)

COMANCHE PEAK - UNITS 1 AND 2 5.0-19c Amendment No. 128

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9/ Unit 1 model D76 and Unit 2 model D5 Steam Generator (SG) Program (continued)

E1"/ Ifcrack 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 COMANCHE PEAK - UNITS 1 AND 2 5.0-19d Amendment No. 128

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.15 Safety Function Determination Program (SFDP)

This program ensures loss of safety function is detected and appropriate actions Floss a - taken. Upon entry into LCO 3.0.6, an evaluation shall be made to determine if of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6. The SFDP shall contain the following:

Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

-- . Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists; Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and EIJ>. Other appropriate limitations and remedial or compensatory actions.

E V > A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or A required system redundant to the system(s) in turn. supported by the inoperable supported system is also inoperable; or A required system redundant to the support system(s) for the supported systems (a) and (b) above is also inoperable.

I --- '>TheSFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-26 Amendment No. 64

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16. Containment Leakage Rate Testing Program (continued)

2. Air lock testing acceptance criteria are:

a) Overall air lock leakage rate is < 0.05 La when tested at >

Pa.

b) For each door, leakage rate is -<0.01 La when pressurized to > Pa.

e. The provision of SR 3.0.2 do not apply to the test frequencies specified in the Containment Leakage Rate Testing Program, with the exception of the containment ventilation isolation valves.

f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

5.5.17 Technical Reguirements Manual (TRM)

The TRM contains selected requirements which do not meet the criteria for inclusion in the Technical Specification but are important to the operation of

-.PSES. Much of the information in the TRM was relocated from the TS.

FCPNPP Changes to the TRM shall be made under appropriate administrative controls and reviews. Changes may be made to the TRM without prior NRC approval provided the changes do not require either a change to the TS or NRC approval pursuant to 10 CFR 50.59. TRM changes require approval of the Plant Manager.

5.5.18 Configuration Risk Manaaement Proaram (CRMP)

The Configuration Risk Management Program (CRMP) provides a proceduralized risk-informed assessment to manage the risk associated with equipment inoperability. The program applies to technical specification structures, systems, or components for which a risk-informed Completion Time has been granted. The program shall include the following elements:

a. Provisions for the control and implementation of a Level 1, at-power, internal events PRA-informed methodology. The assessment shall be capable of evaluating the applicable plant configuration.

(continued COMANCHE PEAK - UNITS 1 AND 2 5.0-28 Amendment No. 94, 4-34, 141 1

Reporting Requirements 5.6 5.6 Reporting Requirements (continued)-

5.6.5 Core Operating Limits Report (COLR) (continued) allowing use of 100.6 percent of rated power in safety analysis methodology when the LEFM4i is used for feedwater flow measurement.

The approved analytical methods are described in the following documents:

1) WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (W Proprietary)

2) WCAP-1 0216-P-A, Revision 1A, "RELAXATION OF CONSTANT AXIAL OFFSET CONTROL FQ SURVEILLANCE TECHNICAL.

SPECIFICATION," February 1994 (W Proprietary).

4 RXE 90 006 P A, "Power Distribution Control Analysis and OV8ertmpeature N 16 and Overpower N 16 TrFip Setpoint Methodology," Juno 1901.

44 RXE---R-8812-P A, "TUE 1 Dcpaqre from Nucleate Bo6iig Correlation," July 1992.

5- RXE 88 102 P, Sup. 1, "TUE ! DNB Corrorlation Supplement 1,"

Doeeembe 199-00.

64 RXE 89 002 A, "VIPRE 01 Core Thermal Hydraul!c Analysis Methods for ComFanc~he Peak Steam Elcctri6 Station Liccnsing Applications," September 1993.

7-) RXE 91 001 A, "Transicnt Analysis Mcthods for Comanchc Peak S+teafm Ele*ctric Station Lic.ensing Application,," October 1993.

8) RXE- 91 Q002 A, "Reactivity' Anomaly Events Methodology,"

Octobcr 1993-.

AnalysisrJMehdloy"Mrc 00

9) ERX 2000 002 R,"Rcvised L~argc Brcak Loss of Coolant Acciden 404) TXX 88306, "Steam Gener.ater Tube Ruptre Analysis,"

March 15,14988.

14-4 RXE= 91 005 A, "Methodology for Reactor Core Response to Steam.line Break Events," February 1994.

4-24 RXE 91 001 A, "Safety Analysis of Postulated Inadve.tent EleUIA LJIiUlIuti event1 Iin Modes. a, 14, andf a, r-uuruy I ut-4-.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-33 Amendment No. 9, 2,, 144

Reporting Requirements 5.6 5.6 Reporting Requirements (continued) 5.6.5 Core Operating Limits Report (COLR) (continued) 4-4 RXE 95 001 P A, "Small Break Loss of Coolant A..idcnt Analysis Methodology," September 1996.

-Caldon, Inc. Engineering Report-80P, "Improving Thermal Power Accuracy and Plant Safety While Increasing Operating Power level Using the LEFM/ System," Revision 0, March 1997 and Caldon Engineering Report - 160P, "Supplement to Topical Report ER-80P; Basis for a Power Uprate With the LEFM~r System," Revision 0, May 2000.

4-1 ERX '201i 005 P, "Z7IRLOQTM Cladding and. Boron Coating Models for T-XUJIEler,,t-, Los , f Coolant Accid-n-Ic-'5 Analysis Methodologies," October 2001.

ý i-6 WCAP-1 0444-P-A, "Reference Core Report VANTAGE 5 Fuel Assembly," September 1985.

" 1-7) WCAP-15025-P-A, "Modified WRB-2 Correlation, WRB-2M, for Predicting Critical Heat Flux in 17x17 Rod Bundles for Modified LPD Mixing Vane Grids," April 1999.

Fr--+8) WCAP-13060-P-A, "Westinghouse Fuel Assembly Reconstitution.

Evaluation Methodology," July, 1993.

.. ) EDRX 04 004 A; "Replacement Steam Generator Supplement To T-XIU PoweFr'- Ia*go and Small Break Lo.ss Of Coolant Accident Analysis Mothodologies" Revision 0, March 2007.

2-0 ERX 04 005 A; "Applicatfion of T-XU Power's Non LOCGA TrFansien Analysis Methodologies to a Feod Ring Steam Gonor-ator Delsign" Revision 0, March 200n7.

F7->521) WCAP-1 1397-P-A, "Revised Thermal Design Procedure," April 1989.

[j---)z) WCAP-8745-P-A, "Design Bases for the Thermal Overpower AT and Thermal Overtemperature AT Trip Functions," September 1986.

>2-3e) WCAP-14565-P-A, "VIPRE-01 Modeling and Qualification for Pressurized Water Reactor Non-LOCA Thermal-Hydraulic Safety Analysis," October 1999.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-34 Amendment No. 44-9,4-2-3, 435,144

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

[To1--4) WCAP-14882-P-A, "RETRAN-02 Modeling and Qualification for Westinghouse Pressurized Water Reactor Non-LOCA Safety Analyses," April 1999.

WCAP-10054-P-A, "Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code," August 1985.

WCAP-1 0054-P-A, Addendum 2, Revision 1, "Addendum to the F13-->-7 Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code: Safety Injection into the Broken Loop and COSI Condensation Model," July 1997.

WCAP-10079-P-A, "NOTRUMP, A Nodal Transient Small Break and General Network Code," August 1985.

114[--->98) WCAP-16009-P-A, "Realistic Large-Break LOCA Evaluation Methodology Using the Automated Statistical Treatment of Uncertainty Method (ASTRUM)," January 2005.

[*j-**-9) WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System," August 1994.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-35 Amendment No. 44-9,4-23, 435,144

Programs and Manuals 5.6 5.6 Reporting Requirements (continued)

I I.*!L A iJ_--ln r-*A t'*L ...... *_ "f- L _ I 5.6.419 a- iti15 days foiloew ng the comnpletionA of e~ach nseto 9-o~c f tbes, th nm erf tubos plugged, repaired or stoam goerator dcsignated as an F=*tube in eac-h Steam gcnReatGr Shall be repertcd to the GGMRiGsG4-The complete results of the steamn generator tube isrieiseto Fshall be su-b~mitted- to the Commissini eotwti 2mnh following the comRpletion of the inspection. T-his report Shall icue

-14) Number and extenAt -oftub,-es and (for Unit I only) Sleeves ispe~eted, 24 Loc~ation and percent of Wall thicknRess penetration for each R1indication o-.f aR*nimperf~eto, and 24 Idetifca~tfion of tubes plugged or repaired.

r.. Results of steam genierator tube inspections which fall into Categor,' C 3 SGhall bwe reported to the Commission in a report w~ithin 3 days and prior IV 1:9 F L:t-:i: "lof .L UJU,.:iF. +H:1. FepeL Ud:;;; pFFuV;I a u*t*u p U

t,;i inRvestigations conducted to determin cas f the tube degradation and corrective mneasures taken to prevent recurrence (G94Rtued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-38 Amendment No. 7Q, 429,144 1

Programs and Manuals 5.6 5.6 Reporting Requirements (continued) f 6 10 I I.--*z A II A_ Jl I-% A t'*L "f"_ . L __

Unit 4 Nnedel w4 Steam k!98R8Fa!GF +--Qe--1t36-m=-n-T1GR I.

KGOGFE (69434WH46434 4-I For imp.lemen-tation o-f the voltage based repa.ir criteria to tube suppor Plate intersoctions,, no~tify the Gtaff prior to returning the steamR goneatercs to ser.'-e should any Of the folloWing conditions arioe:

-. If esti*m*ated leakage based on th projected end of cycle (Or if not practical, using the actual mea;sureAd end4 ofcc ")lage di*tFibuWt*i ex"eeds the leakage limit (determined from the l;cen*i*g basi*s dos.Ge -ca-lulation for the postulated Fmain steam line break) for the next operating cGyle.

2- if cicumnferenti-al crack like indications are deteted at the tube support plate intersections,.

3 I indicatiens are identified that extend beyend the confines of the If tube SUPPort plate.

Ifidcain are identified at the tube support plate elevations that a;re- a;ttribu--table to primnar' water stress corrosion cracking.

& If the calculated con-ditionmal b3urSt probability based nthe R

projected end Of cycle (or if not practical, using the actual mneasured end of eayele) voltage distribution exceeds 4x 0~

notify the NSRC and provide an assessment of the Safety significance of the occurrence.

COMANCHE PEAK - UNITS 1 AND 2 5.0-39 Amendment 4-28,144 1

ATTACHMENT 4 to TXX-09029 RETYPED UNIT 1 AND UNIT 2 OPERATING LICENSE PAGES Unit 1 Pages 1 2

6 7

Unit 2 Pages 1 2

6

LUMINANT GENERATION COMPANY LLC DOCKET NO. 50-445 COMANCHE PEAK NUCLEAR POWER PLANT. UNIT NO. 1 I FACILITY OPERATING LICENSE License No. NPF-87

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

A. The application for a license filed by Luminant Generation Company LLC*

(licensee), complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter 1, and all required notifications to other agencies or bodies have been duly made; B. Construction of the Comanche Peak Nuclear Power Plant, Unit No. 1 (the facility),

has been substantially completed in conformity with Construction Permit No.

CPPR-126 and the application, as amended, the provisions of the Act, and the regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.D below);

D. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter 1, except as exempted from compliance in Section 2.D below;

Luminant Generation Company LLC was previously named as TXU Generation Company LP. The legal name was changed in connection with the indirect license transfer application dated April 18, 2007, as supplemented July 20, 2007 and October 2, 2007.

Amendment No. 68, 89, 0, Q19.

E. Luminant Generation Company LLC is technically qualified to engage in the activities authorized by this operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter 1; F. The licensee has satisfied the applicable provisions of 10 CFR 140, "Financial Protection Requirements and Indemnity Agreements,"\-of the Commission's regulations; G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of Facility Operating License No. NPF-87 subject to the conditions for protection of the environment set forth herein, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and The receipt, possession, and use of source, byproduct, and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70, except that an exemption to the provisions of 70.24 is granted as described in paragraph 2.D below.

2. Based on the foregoing findings regarding this facility, Facility Operating License No.

NPF-87 is hereby issued to the licensee, to read as follows:

A. This license applies to the Comanche Peak Nuclear Power Plant, Unit No. 1, a pressurized-water nuclear reactor and associated equipment (the facility), owned by the licensee. The facility is located on Squaw Creek Reservoir in Somervell County, Texas about 5 miles north-northwest of Glen Rose, Texas, and about 40 miles southwest of Fort Worth in north-central Texas and is described in the licensee's Final Safety Analysis Report, as supplemented and amended, and the licensee's Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Pursuant to Section 103 of the Act and 10 CFR Part 50, "Domestic Licensing and Production and Utilization Facilities," Luminant Generation Company LLC to possess, use, and operate the facility at the designated location in Somervell County, Texas in accordance with the procedures and limitations set forth in this license; (2) NOT USED Amendment No. 68, 89, 90, 139,

(b) Operations to mitigate fuel damage considering the following:

1. Protection and use of personnel assets

2. Communications

3. Minimizing fire spread

4. Procedures for implementing integrated fire response strategy

5. Identification of readily-available pre-staged equipment

6. Training on integrated fire response strategy

7. Spent fuel pool mitigation measures (c) Actions to minimize release to include consideration of:

1. Water spray scrubbing

2. Dose to onsite responders (9) License Transfer Luminant Generation Company LLC shall enter into the $250 million support agreement with Luminant Investment Company LLC, as described in the July 20, 2007 supplement to the April 18, 2007 indirect license transfer application, no later than the time the proposed transactions and indirect license transfers occur. Luminant Generation Company LCC shall take no action to cause Luminant Investment Company LLC, or its successors and assigns, to void, cancel, or modify the support agreement or cause it to fail to perform, or impair its performance under the support agreement, without the prior written consent of the NRC. The support agreement may not be amended or modified without 30 days prior written notice to the Director of the Office of Nuclear Reactor Regulation or his designee. An executed copy of the support agreement shall be submitted to the NRC no later than 30 days after the completion of the proposed transactions and the indirect license transfers. Luminant Generation Company LLC shall inform the NRC in writing anytime it draws upon the support agreement.

Following the subject indirect transfer of control of the licenses, all of the officers of the general partner or controlling member of the licensee of CPNPP shall be U.S. citizens. This condition may be amended upon application by the licensee and approval by the Director of the Office of Nuclear Reactor Regulation.

D. The following exemptions are authorized by law and will not endanger life or property or the common defense and security. Certain special circumstances are present and these exemptions are otherwise in the public interest. Therefore, these exemptions are hereby granted pursuant to 10 CFR 50.12.

(1) The facility requires a technical exemption from the requirements of 10 CFR 50, Appendix J, Section IIl.D.2(b)(ii). The justification for this exemption is contained in Section 6.2.5 of Supplement 22 to the Safety Evaluation Report dated January 1990. The staff's environmental assessment was published on November 14, 1989 (54 FR 47430).

Amendment No. 68, 00, 1-3, 139, Revised by lcttcr dated July 26, 2097

Therefore, pursuant to 10 CFR 50.12(a)(1), and 10 CFR 50.12(a)(2)(ii) and (iii), the Comanche Peak Nuclear Power Plant, Unit 1 is hereby granted an exemption from the cited requirement and instead, is required to perform the overall air lock leak test at pressure Pa prior to establishing containment integrity if air lock maintenance has been performed that could affect the air lock sealing capability.

(2) The facility was previously granted an exemption from the criticality monitoring requirements of 10 CFR 70.24 (see Materials License No. SNM-1912 dated December 1, 1988 and Section 9.1.1 of Supplement 22 to the Safety Evaluation Report dated January 1990). The staff's environmental assessment was published on November 14, 1989 (54 FR 47432). The Comanche Peak Nuclear Power Plant, Unit 1 is hereby exempted from the criticality monitoring provisions of 10 CFR 70.24 as applied to fuel assemblies held under this license.

(3) The facility requires a temporary exemption from the schedular requirements of 10 CFR 50.33(k) and 10 CFR 50.75. The justification for this exemption is contained in Section 20.6 of Supplement 22 to the Safety Evaluation Report dated January 1990. The staffs environmental assessment was published on November 14, 1989 (54 FR 47431).

Therefore, pursuant to 10 CFR 50.12(a)(1), 50.12(a)(2)(iii) and 50.12(a)(2)(v), the Comanche Peak Nuclear Power Plant, Unit 1 is hereby granted a temporary exemption from the schedular requirements of 10 CFR 50.33(k) and 10 CFR 50.75 and is required to submit a decommissioning funding report for Comanche Peak Nuclear Power Plant, Unit 1 on or before July 26, 1990.

E. DELETED F. In order to ensure that Luminant Generation Company LLC will exercise the authority as the surface landowner in a timely manner and that the requirements of 10 CFR Part 100.3 (a) are satisfied, this license is subject to the additional conditions specified below: (Section 2.1.1, SER)

(1) For that portion of the exclusion area which is within 2250 ft of any seismic Category I building or within 2800 ft of either reactor containment building, Luminant Generation Company LLC must prohibit the exploration and/or exercise of subsurface mineral rights, and if the subsurface mineral rights owners attempt to exercise their rights within this area, Luminant Generation Company LLC must immediately institute immediately effective condemnation proceedings to obtain the mineral rights in this area.

(2) For the unowned subsurface mineral rights within the exclusion area not covered in item (1), Luminant Generation Company LLC will prohibit the exploration and/or exercise of mineral rights until and unless the licensee and the owners of the mineral rights enter into an agreement which gives Luminant Generation Company LLC absolute authority to determine all activities -- including times of arrival and locations of personnel and the authority to remove personnel and equipment -- in event of emergency.

If the mineral rights owners attempt to exercise their rights within this area without first entering into such an agreement, Luminant Generation Company LLC must institute immediately effective condemnation proceedings to obtain the mineral rights in this area.

Amendment No. 68, 82, 90, 103, 130, Rvi,,,d by Ic..c. dated July 26, 2007-

LUMINANT. GENERATION COMPANY LLC DOCKET NO. 50-446 COMANCHE PEAK NUCLEAR POWER PLANT, UNIT NO. 2 FACILITY OPERATING LICENSE License No. NPF-89

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

A. The application for a license filed by Luminant Generation Company LLC*

(licensee), complies with the standards and requirements of the Atomic Energy Act of 1954, as amended (the Act), and the Commission's regulations set forth in 10 CFR Chapter I, and all required notifications to other agencies or bodies have been duly made; B. Construction of the Comanche Peak Nuclear Power Plant, Unit No. 2 (the facility),'

has been substantially completed in conformity with Construction Permit No.

CPPR-127 and the application, as amended, the provisions of the Act, and the regulations of the Commission; C. The facility will operate in conformity with the application, as amended, the provisions of the Act, and the regulations of the Commission (except as exempted from compliance in Section 2.D below);

D. There is reasonable assurance: (i) that the activities authorized by this operating license can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Commission's regulations set forth in 10 CFR Chapter I, except as exempted from compliance in Section 2.D. below; E. Luminant Generation Company LLC is technically qualified to engage in the activities authorized by this operating license in accordance with the Commission's regulations set forth in 10 CFR Chapter I;

Luminant Generation Company LLC was previously named as TXU Generation Company LP. The legal name was changed in connection with the indirect license transfer application dated April 18, 2007, as supplemented July 20, 2007 and October 2, 2007.

Amendment No. 68, 89, 90, 139,-

F. The licensee has satisfied the applicable provisions of 10 CFR 140, "Financial Protection Requirements and Indemnity Agreements," of the Commission's regulations; G. The issuance of this license will not be inimical to the common defense and security or to the health and safety of the public; H. After weighing the environmental, economic, technical, and other benefits of the facility against environmental and other costs and considering available alternatives, the issuance of Facility Operating License No. NPF-89 subject to the conditions for protection of the environment set forth herein, is in accordance with 10 CFR Part 51 of the Commission's regulations and all applicable requirements have been satisfied; and The receipt, possession, and use of source, byproduct, and special nuclear material as authorized by this license will be in accordance with the Commission's regulations in 10 CFR Parts 30, 40, and 70, except that an exemption to the provisions of 70.24 is granted as described in paragraph 2.D below.

2. Pursuant to approval by the Nuclear Regulatory Commission at a meeting on April 6,1993, the License for Fuel Loading and Low Power Testing, License No. NPF-88, issued on February 2, 1993, is superseded by Facility Operating License No. NPF-89 hereby issued to the licensee, to read as follows:

A. This license applies to the Comanche Peak Nuclear Power Plant, Unit No. 2, a pressurized-water nuclear reactor and associated equipment (the facility), owned by the licensee. The facility is located on Squaw Creek Reservoir in Somervell County, Texas about 5 miles north-northwest of Glen Rose, Texas, and about 40 miles southwest of Fort Worth in north-central Texas and is described in the licensee's Final Safety Analysis Report, as supplemented and amended, and the licensee's Environmental Report, as supplemented and amended.

B. Subject to the conditions and requirements incorporated herein, the Commission hereby licenses:

(1) Pursuant to Section 103 of the Act and 10 CFR Part 50, "Domestic Licensing of Production and Utilization Facilities," Luminant Generation Company LLC to possess, use, and operate the facility at the designated location in Somervell County, Texas in accordance with the procedures and limitations set forth in this license; (2) NOT USED Amendment No. 68, 89, 90, 139,

(9) License Transfer Luminant Generation Company LLC shall enter into the $250 million support agreement with Luminant Investment Company LLC, as described in the July 20, 2007 supplement to the April 18, 2007 indirect license transfer application, no later than the time the proposed transactions and indirect license transfers occur. Luminant Generation Company LCC shall take no action to cause Luminant Investment Company LLC, or its successors and assigns, to void, cancel, or modify the support agreement or cause it to fail to perform, or impair its performance under the support agreement, without the prior written consent of the NRC. The support agreement may not be amended or modified without 30 days prior written notice to the Director of the Office of Nuclear Reactor Regulation or his designee. An executed copy of the support agreement shall be submitted to the NRC no later than 30 days after the completion of the proposed transactions and the indirect license transfers. Luminant Generation Company LLC shall inform the NRC in writing anytime it draws upon the support agreement.

Following the subject indirect transfer of control of the licenses, all of the officers of the general partner or controlling member of the licensee of CPNPP shall be U.S. citizens. This condition may be amended upon application by the licensee and approval by the Director of the Office of Nuclear Reactor Regulation.

D. The following exemptions are authorized by law and will not endanger life or property or the common defense and security. Certain special circumstances are present and these exemptions are otherwise in the public interest.

Therefore, these exemptions are hereby granted:

(1) The facility requires a technical exemption from the requirements of 10 CFR Part 50, Appendix J, Section IIl.D.2(b)(ii). The justification for this exemption is contained in Section 6.2.5.1 of Supplement 26 to the Safety Evaluation Report dated February 1993. The staffs environmental assessment was published on January 19, 1993 (58 FR 5036). Therefore, pursuant tol10 CFR 50.12(a)(1), 10 CFR 50.12(a)(2)(ii) and (iii), the Comanche Peak Nuclear Power Plant, Unit 2 is hereby granted an exemption from the cited requirement and instead, is required to perform the overall air lock leak test at pressure Pa prior to establishing containment integrity if air lock maintenance has been performed that could affect the air lock sealing capability.

The facility was previously granted exemption from the criticality Monitoring requirements of 10 CFR 70.24 (see Materials License No.

SNM-1986 dated April 24,1989 and Section 9.1.1 of SSER 26 dated February 1993.) The staffs environmental assessment was published on January 19, 1993 (58 FR 5035).The Comanche Peak Nuclear Power Plant, Unit 2 is hereby exempted from the criticality monitoring provisions of 10 CFR 70.24 as applied to fuel assemblies held under this license.

Amendment No. 68, 90, 103, 13-,

ATTACHMENT 5 to TXX-09029 RETYPED TECHNICAL SPECIFICATIONS PAGES Pages Cover Page 1.1-1 through 1.1-8 1.2-1 through 1.2-2 1.3-1 through 1.3-8 1.4-1 through 1.4-3 2.0-1 3.0-1 through 3.0-5 3.1-1 through 3.1-18 3.2-1 through 3.2-13 3.3-1 through 3.3-54 3.4-1 through 3.4-43 3.5-1 through 3.5-10 3.6.-i through 3.6-18 3.7-1 through 3.7-46 3.8-1 through 3.8-39 3.9-1 through 3.9-12 4.0-1 through 4.0-3 5.1-1 5.2-1 through 5.2-2 5.3-1 5.4-1 5.5-1 through 5.5-16 5.6-1 through 5.6-5 5.7-1 through 5.7-3

TECHNICAL SPECIFICATIONS FOR COMANCHE PEAK NUCLEAR POWER PLANT UNITS 1 AND 2

Definitions 1.1 1.0 USE AND APPLICATION 1.1 Definitions

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

The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications and Bases.

Term Definition ACTIONS ACTIONS shall be that part of a Specification that prescribes Required Actions to be taken under designated Conditions within specified Completion Times.

ACTUATION LOGIC TEST An ACTUATION LOGIC TEST shall be the application of various simulated or actual input combinations in conjunction with each possible interlock logic state required for OPERABILITY of a logic circuit and the verification of the required logic output. The ACTUATION LOGIC TEST, as a minimum, shall include a continuity check of output devices.

AXIAL FLUX DIFFERENCE AFD shall be the difference in normalized flux signals between the (AFD) top and bottom halves of an excore neutron detector.

CHANNEL CALIBRATION A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel output such that it responds within the necessary range and accuracy to known values of the parameter that the channel monitors. The CHANNEL CALIBRATION shall encompass all devices in the channel required for channel OPERABILITY. Calibration of instrument channels with resistance temperature detector (RTD) or thermocouple sensors may consist of an inplace qualitative assessment of sensor behavior and normal calibration of the remaining adjustable devices in the channel. The CHANNEL CALIBRATION may be performed by means of any series of sequential, overlapping or total channel steps.

CHANNEL CHECK A CHANNEL CHECK shall be the qualitative assessment, by observation, of channel behavior during operation. This determination shall include, where possible, comparison of the channel indication and status to other indications or status derived from independent instrument channels measuring the same parameter.

COMANCHE PEAK - UNITS 1 AND 2 1.1-1 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

CHANNEL OPERATIONAL A COT shall be the injection of a simulated or actual signal into TEST (COT) the channel as close to the sensor as practicable to verify.

OPERABILITY of all devices in the channel required for channel OPERABILITY. The COT shall include adjustments, as necessary, of the required alarm, interlock, and trip setpoints required for channel OPERABILITY so that the setpoints are within the necessary range and accuracy. The COT may be performed by means of any series of sequential, overlapping or total channel steps.

CORE ALTERATION CORE ALTERATION shall be the movement of any fuel, sources, or reactivity control components, within the reactor vessel with the vessel head removed and fuel in the vessel. Suspension of CORE ALTERATIONS shall not preclude completion of movement of a component to a safe position.

CORE OPERATING LIMITS The COLR is the. unit specific document that provides cycle REPORT (COLR) specific parameter limits for the current reload cycle. These cycle specific parameter limits shall be determined for each reload cycle in accordance with Specification 5.6.5. Plant operation within these limits is addressed in individual Specifications.

DOSE EQUIVALENT 1-131 DOSE EQUIVALENT 1-131 shall be that concentration of 1-131 (microcuries per gram) that alone would produce the same dose when inhaled as the combined activities of iodine isotopes 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The determination of DOSE EQUIVALENT 1-131 shall be performed using thyroid dose conversion factors from Table III of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites," or from Table E-7 of Regulatory Guide 1.109, Revision 1, NRC, 1977, or from ICRP-30, 1979, Supplement to Part 1, page 192-212, Table titled "Committed Dose Equivalent in Target Organs or Tissues per Intake of Unit Activity," or from Table 2.1 of EPA Federal Guidance Report No. 11, 1988, "Limiting Values of Radionuclide Intake and Air Concentration and Dose Conversion Factors for Inhalation, Submersion, and Ingestion."

COMANCHE PEAK - UNITS 1 AND 2 1.1-2 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

DOSE EQUIVALENT XE-1 33 DOSE EQUIVALENT XE-1 33 shall be that concentration of Xe-133 (microcuries per gram) that alone would produce the same acute dose to the whole body as the combined activities of noble gas nuclides Kr-85m, Kr-87, Kr-88, Xe-133m, Xe-133, Xe-135m, Xe-1 35, and Xe-1 38 actually present. If a specific noble gas nuclide is not detected, it should be assumed to be present at the minimum detectable activity. The determination of DOSE EQUIVALENT XE-1 33 shall be performed using effective dose conversion factors for air submersion listed in Table 111.1 of EPA Federal Guidance Report No. 12, 1993, "External Exposure to Radionuclides in Air, Water, and Soil", or using the dose conversion factors from Table B-1 of Regulatory Guide 1.109, Revision 1, NRC, 1977.

ENGINEERED SAFETY The ESF RESPONSE TIME shall be that time interval from when FEATURE (ESF) RESPONSE the monitored parameter exceeds its ESF actuation setpoint at TIME the channel sensor until the ESF equipment is capable of performing its safety function (i.e., the valves travel to their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel generator starting and sequence loading delays, where applicable. 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.

COMANCHE PEAK - UNITS 1 AND 2 1.1-3 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

LEAKAGE LEAKAGE shall be:

a. Identified LEAKAGE

1. LEAKAGE, such as that from pump seals or valve packing (except reactor coolant pump (RCP) seal water injection or leakoff), that is captured and conducted to collection systems or a sump or collecting tank;

2. LEAKAGE into the containment atmosphere from sources that are both specifically located and known either not to interfere with the operation of leakage detection systems or not to be pressure boundary LEAKAGE; or

3. Reactor Coolant System (RCS) LEAKAGE through a steam generator to the Secondary System (primary to secondary LEAKAGE);

b. Unidentified LEAKAGE All LEAKAGE (except RCP seal water injection or leakoff) that is not identified LEAKAGE;

c. Pressure Boundary LEAKAGE LEAKAGE (except primary to secondary LEAKAGE) through a nonisolable fault in an RCS component body, pipe wall, or vessel wall.

MASTER RELAY TEST A MASTER RELAY TEST shall consist of energizing all master relays in the channel required for channel OPERABILITY and verifying the OPERABILITY of each required master relay. The MASTER RELAY TEST shall include a continuity check of each associated required slave relay. The MASTER RELAY TEST may be performed by means of any series of sequential, overlapping or total steps.

MODE A MODE shall correspond to any one inclusive combination of core reactivity condition, power level, average reactor coolant temperature, and reactor vessel head closure bolt tensioning specified in Table 1.1-1 with fuel in the reactor vessel.

COMANCHE PEAK - UNITS 1 AND 2 1.1-4 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

OPERABLE - OPERABILITY A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified safety function(s) and when all necessary attendant instrumentation, controls, normal or emergency electrical power, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its specified safety function(s) are also capable of performing their related support function(s).

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation. These tests are:

a. Described in Chapter 14, of the FSAR;

b. Authorized under the provisions of 10 CFR 50.59; or

c. Otherwise approved by the Nuclear Regulatory Commission.

PRESSURE AND The PTLR is the unit specific document that provides the reactor TEMPERATURE LIMITS vessel pressure and temperature limits, including heatup and REPORT (PTLR) cooldown rates, the power operated relief valve (PORV) lift settings and the LTOP arming temperature associated with the Low Temperature Overpressurization Protection (LTOP) System, for the current reactor vessel fluence period. These pressure and temperature limits shall be determined for each fluence period in accordance with Specification 5.6.6.

QUADRANT POWER TILT QPTR shall be the ratio of the maximum upper excore detector RATIO (QPTR) calibrated output to the average of the upper excore detector calibrated outputs, or the ratio of the maximum lower excore detector calibrated output to the average of the lower excore detector calibrated outputs, whichever is greater.

RATED THERMAL POWER RTP shall be a total reactor core heat transfer rate to the reactor (RTP) coolant of 3458 MWt through Cycle 13 for Unit 1 and through Cycle 11 for Unit 2. Starting with Cycles 14 and 12 of Units 1 and 2, respectively, RTP shall be 3612 MWt.

COMANCHE PEAK - UNITS 1 AND 2 1.1-5 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

REACTOR TRIP SYSTEM The RTS RESPONSE TIME shall be that time interval from when (RTS) RESPONSE TIME the monitored parameter exceeds its RTS trip setpoint at the channel sensor until loss of stationary gripper coil voltage. 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 rod cluster control assemblies (RCCAs) are fully inserted except for the single RCCA of highest reactivity worth, which is assumed to be fully withdrawn. With any RCCA not capable of being fully inserted, the reactivity worth of the RCCA must be accounted for in the determination of SDM; and

b. In MODES 1 and 2, the fuel and moderator temperatures are changed to the hot zero power temperatures.

SLAVE RELAY TEST A SLAVE RELAY TEST shall consist of energizing all slave relays in the channel required for channel OPERABILITY and verifying the OPERABILITY of each required slave relay. The SLAVE RELAY TEST shall include a continuity check of associated testable actuation devices. The SLAVE RELAY TEST may be performed by means of any series of sequential, overlapping or total steps.

STAGGERED TEST BASIS A STAGGERED TEST BASIS shall consist of the testing of one of the systems, subsystems, channels, or other designated components during the interval specified by the Surveillance Frequency, so that all systems, subsystems, channels, or other designated components are tested during n Surveillance Frequency intervals, where n is the total number of systems, subsystems, channels, or other designated components in the associated function..

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

COMANCHE PEAK - UNITS 1 AND 2 1.1-6 Amendment No.

Definitions 1.1 1.1 Definitions (continued)

TRIP ACTUATING DEVICE A TADOT shall consist of operating the trip actuating device and OPERATIONAL TEST (TADOT) verifying the OPERABILITY of all devices in the channel required for trip actuating device OPERABILITY. The TADOT shall include adjustment, as necessary, of the trip actuating device so that it actuates at the required setpoint within the necessary accuracy. The TADOT may be performed by means of any series of sequential, overlapping or total channel steps.

COMANCHE PEAK - UNITS 1 AND 2 1.1-7 Amendment No.

Definitions 1.1 Table 1.1-1 (page 1 of 1)

MODES REACTIVITY % RATED AVERAGE REACTOR CONDITION THERMAL COOLANT (keff) POWER(a) TEMPERATURE (OF)

I Power Operation _ 0.99 >5 NA 2 Startup >0.99 *5 NA 3 Hot Standby < 0.99 NA _ 350 4 Hot Shutdown(b) < 0.99 NA 350 > Tavg >,200 5 Cold Shutdown(b) < 0.99 NA < 200 6 Refueling(C) NA NA NA (a) Excluding decay heat.

(b) All reactor vessel head closure bolts fully tensioned.

(c) One or more reactor vessel head closure bolts less than fully tensioned.

COMANCHE PEAK - UNITS 1 AND 2 1.1-8 Amendment No.

Logical Connectors 1.2 1.0 USE AND APPLICATION 1.2 Logical Connectors PURPOSE The purpose of this section is to explain the meaning of logical connectors.

Logical connectors are used in Technical Specifications (TS) to discriminate between, and yet connect, discrete Conditions, Required Actions, Completion Times, Surveillances, and Frequencies. The only logical connectors that appear in TS are AND and OR. The physical arrangement of these connectors constitutes logical conventions with specific meanings.

BACKGROUND Several levels of logic may be used to state Required Actions. These levels are identified by the placement (or nesting) of the logical connectors and by the number assigned to each Required Action. The first level of logic is identified by the first digit of the number assigned to a Required Action and the placement of the logical connector in the first level of nesting (i.e., left justified with the number of the Required Action). The successive levels of logic are identified by additional digits of the Required Action number and by successive indentations of the logical connectors.

When logical connectors are used to state a Condition, Completion Time, Surveillance, or Frequency, only the first level of logic is used, and the logical connector is left justified with the statement of the Condition, Completion Time, Surveillance, or Frequency.

EXAMPLES The following examples illustrate the use of logical connectors.

EXAMPLE 1.2-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Verify...

AND A.2 Restore...

In this example the logical connector AND is used to indicate that when in Condition A, both Required Actions A.1 and A.2 must be completed.

COMANCHE PEAK - UNITS 1 AND 2 1.2-1 Amendment No.

Logical Connectors 1.2 1.2 Logical Connectors EXAMPLES (continued)

EXAMPLE 1.2-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. LCO not met. A.1 Trip...

OR A.2.1 Verify...

AND A.2.2.1 Reduce...

OR A.2.2.2 Perform...

OR A.3 Align...

This example represents a more complicated use of logical connectors.

Required Actions A.1, A.2, and A.3 are alternative choices, only one of which must be performed as indicated by the use of the logical connector OR and.

the left justified placement. Any one of these three Actions may be chosen. If A.2 is chosen, then both A.2.1 and A.2.2 must be performed as indicated by the logical connector AND. Required Action A.2.2 is met by performing A.2.2.1 or A.2.2.2. The indented position of the logical connector OR indicates that A.2.2.1 and A.2.2.2 are alternative choices, only one of which must be performed.

COMANCHE PEAK - UNITS 1 AND 2 1.2-2 Amendment No.

Completion Times 1.3 1.0 USE AND APPLICATION 1.3 Completion Times PURPOSE The purpose of this section is to establish the Completion Time convention and to provide guidance for its use.

BACKGROUND Limiting Conditions for Operation (LCOs) specify minimum requirements for ensuring safe operation of the unit. The ACTIONS associated with an LCO state Conditions that typically describe the ways in which the requirements of the LCO can fail to be met. Specified with each stated Condition are Required Action(s) and Completion Time(s).

DESCRIPTION The Completion Time is the amount of time allowed for completing a Required Action. It is referenced to the time of discovery of a situation (e.g., inoperable equipment or variable not within limits) that requires entering an ACTIONS Condition unless otherwise specified, providing the unit is in a MODE or specified condition stated in the Applicability of the LCO. Required Actions must be completed prior to the expiration of the specified Completion Time.

An ACTIONS Condition remains in effect and the Required Actions apply until the Condition no longer exists or the unit is not within the LCO Applicability.

If situations are discovered that require entry into more than one Condition at a time within a single LCO (multiple Conditions), the Required Actions for each Condition must be performed within the associated Completion Time. When in multiple Conditions, separate Completion Times are tracked for each Condition starting from the time of discovery of the situation that required entry into the Condition.

Once a Condition has been entered, subsequent trains, subsystems, components, or variables expressed in the Condition, discovered to be inoperable or not within limits, will not result in separate entry into the Condition, unless specifically stated. The Required Actions of the Condition continue to apply to each additional failure, with Completion Times based on initial entry into the Condition.

However, when a subsequent train, subsystem, component, or variable expressed in the Condition is discovered to be inoperable or not within limits, the Completion Time(s) may be extended. To apply this Completion Time extension, two criteria must first be met. The subsequent inoperability:

a. Must exist concurrent with the first inoperability; and

b. Must remain inoperable or not within limits after the first inoperability is resolved.

COMANCHE PEAK - UNITS 1 AND 2 1.3-1 Amendment No.

Completion Times 1.3 1.3 Completion Times DESCRIPTION (continued)

The total Completion Time allowed for completing a Required Action to address the subsequent inoperability shall be limited to the more restrictive of either:

a. The stated Completion Time, as measured from the initial entry into the Condition, plus an additional 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ; or

b. The stated Completion Time as measured from discovery of the subsequent inoperability.

The above Completion Time extensions do not apply to those Specifications that have exceptions that allow completely separate re-entry into the Condition (for each train, subsystem, component, or variable expressed in the Condition) and separate tracking of Completion Times based on this re-entry. These exceptions are stated in individual Specifications.

The above Completion Time extension does not apply to a Completion Time with a modified "time zero." This modified "time zero" may be expressed as a repetitive time (i.e., "once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ," where the Completion Time is referenced from a previous completion of the Required Action versus the time of Condition entry) or as a time modified by the phrase "from discovery..

EXAMPLES The following examples illustrate the use of Completion Times with different types of Conditions and changing Conditions.

EXAMPLE 1.3-1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and associated Completion Time AND not met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Condition B has two Required Actions. Each Required Action has its own separate Completion Time. Each Completion Time is referenced to the time that Condition B is entered.

COMANCHE PEAK - UNITS 1 AND 2 1.3-2 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-1 (continued)

The Required Actions of Condition B are to be in MODE 3 within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND in MODE 5 within 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months . A total of 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months is allowed for reaching MODE 3 and a total of 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (not 42 hours4.861111e-4 days 0.0117 hours 6.944444e-5 weeks 1.5981e-5 months ) is allowed for reaching MODE 5 from the time that Condition B was entered. If MODE 3 is reached within 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 months , the time allowed for reaching MODE 5 is the next 33 hours3.819444e-4 days 0.00917 hours 5.456349e-5 weeks 1.25565e-5 months because the total time allowed for reaching MODE 5 is 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

If Condition B is entered while in MODE 3, the time allowed for reaching MODE 5 is the next 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months .

EXAMPLE 1.3-2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pump A.1 Restore pump to 7 days inoperable. OPERABLE status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months When a pump is declared inoperable, Condition A is entered. If the pump is not restored to OPERABLE status within 7 days, Condition B is also entered and the Completion Time clocks for Required Actions B.1 and B.2 start. If the inoperable pump is restored to OPERABLE status after Condition B is entered, Condition A and B are exited, and therefore, the Required Actions of Condition B may be terminated.

When a second pump is declared inoperable while thefirst pump is still inoperable, Condition A is not re-entered for the second pump. LCO 3.0.3 is entered, since the ACTIONS do not include a Condition for more than one inoperable pump. The Completion Time clock for Condition A does not stop after LCO 3.0.3 is entered, but continues to be tracked from the time Condition A was initially entered.

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has not expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition A.

COMANCHE PEAK - UNITS 1 AND 2 1.3-3 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-2 (continued)

While in LCO 3.0.3, if one of the inoperable pumps is restored to OPERABLE status and the Completion Time for Condition A has expired, LCO 3.0.3 may be exited and operation continued in accordance with Condition B. The Completion Time for Condition B is tracked from the time the Condition A Completion Time expired.

On restoring one of the pumps to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first pump was declared inoperable. This Completion Time may be extended if the pump restored to OPERABLE status was the first inoperable pump. A 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months extension to the stated 7 days is allowed, provided this does not result in the second pump being inoperable for > 7 days.

EXAMPLE 1.3-3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One Function X A.1 Restore Function X 7 days train inoperable, train to OPERABLE status.

B. One Function Y B.1 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable, train to OPERABLE status.

C. One Function X C.1 Restore Function X 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable, train to OPERABLE status.

AND OR One Function Y train inoperable. C.2 Restore Function Y 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train to OPERABLE status.

COMANCHE PEAK - UNITS 1 AND 2 1.3-4 Amendment No.

N

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-3 (continued)

When one Function X train and one Function Y train are inoperable, Condition A and Condition B are concurrently applicable. The Completion times for Condition A and Condition B are tracked separately for each train starting from the time each train was declared inoperable and the Condition was entered. A separate Completion Time is established for Condition C and tracked from the time the second train was declared. inoperable (i.e., the time the situation described in Condition C was discovered).

If Required Action C.2 is completed within the specified Completion Time, Conditions B and C are exited. Ifthe Completion Time for Required Action A.1 has not expired, operation may continue in accordance with Condition A. The remaining Completion Time in Condition A is measured from the time the affected train was declared inoperable (i.e., initial entry into Condition A).

It is possible to alternate between Conditions A, B, and C in such a manner that operation could continue indefinitely without ever restoring systems to meet the LCO. However, doing so would be inconsistent with the basis of the Completion Times. Therefore, there shall be administrative controls to limit the maximum time allowed for any combination of Conditions that result in a single contiguous occurrence of failing to meet the LCO. These administrative controls shall ensure that the Completion Times for those Conditions are not inappropriately extended.

EXAMPLE 1.3-4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve(s) to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

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

B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 1.3-5 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-4 (continued)

A single Completion Time is used for any number of valves inoperable at the same time. The Completion Time associated with Condition A is based on the initial entry into Condition A and is not tracked on a per valve basis. Declaring subsequent valves inoperable, while Condition A is still in effect, does not trigger the tracking of separate Completion Times.

Once one of the valves has been restored to OPERABLE status, the Condition A Completion Time is not reset, but continues from the time the first valve was declared inoperable. The Completion Time may be extended if the valve restored to OPERABLE-status was the first inoperable valve. The Condition A Completion Time may be extended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months provided this does not result in any subsequent valve being inoperable for > 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

If the Completion Time of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months (including the extension) expires while one or more valves are still inoperable, Condition B is entered.

EXAMPLE 1.3-5 ACTIONS

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

Separate Condition entry is allowed for each inoperable valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more A.1 Restore valve to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months valves OPERABLE status.

inoperable.

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

B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months The Note above the ACTIONS Table is a method of modifying how the Completion Time is tracked. If this method of modifying how the Completion Time is tracked was applicable only to a specific Condition, the Note would appear in that Condition rather than at the top of the ACTIONS Table.

The Note allows Condition A to be entered separately for each inoperable valve, and Completion Times tracked on a per valve basis. When a valve is COMANCHE PEAK - UNITS 1 AND 2 1.3-6 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-5 (continued) declared inoperable, Condition A is entered and its Completion Time starts. If subsequent valves are declared inoperable, Condition A is entered for each valve and separate Completion Times start and are tracked for each valve.

If the Completion Time associated with a valve in Condition A expires, Condition B is entered for that valve. If the Completion Times associated with subsequent valves in Condition A expire, Condition B is entered separately for each valve and separate Completion Times start and are tracked for each valve. If a valve that caused entry into Condition B is restored to OPERABLE status, Condition B is exited for that valve.

Since the Note in this example allows multiple Condition entry and tracking of separate Completion Times, Completion Time extensions do not apply.

EXAMPLE 1.3-6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One channel A.1 Perform SR 3.x.x.x. Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable.

OR A.2 Reduce THERMAL 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months POWER to *50% RTP.

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

Entry into Condition A offers a choice between Required Action A.1 or A.2.

Required Action A.1 has a "once per" Completion Time, which qualifies for the 25% extension, per SR 3.0.2, to each performance after the initial performance. The initial 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval of Required Action A.1 begins when Condition A is entered and the initial performance of Required Action A.1 must be complete within the first 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval. If Required Action A.1 is followed, and the Required Action is not met within the Completion Time (plus the extension allowed by SR 3.0.2), Condition B is entered. If Required Action A.2 is followed and the Completion Time of 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months is not met, Condition B is entered.

COMANCHE PEAK - UNITS 1 AND 2 1.3-7 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES EXAMPLE 1.3-6 (continued)

Ifafter entry into Condition B, Required Action A.1 orA.2 is met, Condition B is exited and operation may then continue in Condition A.

EXAMPLE 1.3-7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One subsystem A.1 Verify affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable, subsystem isolated.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 Restore subsystem to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Required Action A.1 has two Completion Times. The 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Completion Time begins at the time the Condition is entered and each "Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter" interval begins upon performance of Required Action A.1.

If after Condition A is entered, Required Action A.1 is not met within either the initial 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months or any subsequent 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months interval from the previous performance (plus the extension allowed by SR 3.0.2), Condition B is entered. The Completion Time clock for Condition A does not stop after Condition B is entered, but continues from the time Condition A was initially entered. If Required Action A.1 is met after Condition B is entered, Condition B is exited and operation may continue in accordance with Condition A, provided the Completion Time for Required Action A.2 has not expired.

IMMEDIATE When "Immediately" is used as a Completion Time, the Required Action COMPLETION should be pursued without delay and in a controlled manner TIME COMANCHE PEAK - UNITS 1 AND 2 1.3-8 Amendment No.

Frequency 1.4 1.0 USE AND APPLICATION 1.4 Frequency PURPOSE The purpose of this section is to define the proper use and application of Frequency requirements.

DESCRIPTION Each Surveillance Requirement (SR) has a specified Frequency in which the Surveillance must be met in order to meet the associated LCO. An understanding of the correct application of the specified Frequency is necessary for compliance with the SR.

The "specified Frequency" is referred to throughout this section and each of the Specifications of Section 3.0, Surveillance Requirement (SR) Applicability.

The "specified Frequency" consists of the requirements of the Frequency column of each SR as well as certain Notes in the Surveillance column that modify performance requirements.

Situations where a Surveillance could be required (i.e., its Frequency could expire), but where it is not possible or not desired that it be performed until sometime after the associated LCO is within its Applicability, represent potential SR 3.0.4 conflicts. To avoid these conflicts, the SR (i.e., the Surveillance or the Frequency) is stated such that it is only "required" when it can be and should be performed. With an SR satisfied, SR 3.0.4 imposes no restriction.

EXAMPLES The following examples illustrate the various ways that Frequencies are specified. In these examples, the Applicability of the LCO (LCO not shown) is MODES 1, 2, and 3.

EXAMPLE 1.4-1 SURVEILLANCE REQUIREMENTS SURVEILLANCE 12FREQUENCY Perform CHANNEL CHECK. 12hours Example 1.4-1 contains the type of SR most often encountered in the Technical Specifications (TS). The Frequency specifies an interval (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ) during which the associated Surveillance must be performed at least one time.

Performance of the Surveillance initiates the subsequent interval. Although the Frequency is stated as 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , an extension of the time interval to 1.25 times the stated Frequency is allowed by SR 3.0.2 for operational flexibility.

The measurement of this interval continues at all times, even when the SR is COMANCHE PEAK - UNITS 1 AND 2 1.4-1 Amendment No.

Frequency 1.4 1.4 Frequency EXAMPLES EXAMPLE 1.4-1 (continued) not required to be met per SR 3.0.1 (such as when the equipment is inoperable, a variable is outside specified limits, or the unit is outside the Applicability of the LCO). If the interval specified by SR 3.0.2 is exceeded while the unit is in a MODE or other specified condition in the Applicability of the LCO, and the performance of the Surveillance is not otherwise modified (refer to Example 1.4-3), then SR 3.0.3 becomes applicable.

If the interval as specified by SR 3.0.2 is exceeded while the unit is not in a MODE or other specified condition in the Applicability of the LCO for which performance of the SR is required, the Surveillance must be performed within the Frequency requirements of SR 3.0.2 prior to entry into the MODE or other specified condition. Failure to do so would result in a violation of SR 3.0.4.

EXAMPLE 1.4-2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY Verify flow is within limits. Once within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after Ž 25% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months thereafter Example 1.4-2 has two Frequencies. The first is a one time performance Frequency, and the second is of the type shown in Example 1.4-1. The logical connector "AND" indicates that both Frequency requirements must be met.

Each time reactor power is increased from a power level < 25% RTP to Ž_25%

RTP, the Surveillance must be performed within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

The use of "once" indicates a single performance will satisfy the specified Frequency (assuming no other Frequencies are connected by "AND"). This type of Frequency does not qualify for the 25% extension allowed by SR 3.0.2.

"Thereafter" indicates future performances must be established per SR 3.0.2, but only after a specified condition is first met (i.e., the "once" performance in this example). If reactor power decreases to < 25% RTP, the measurement of both intervals stops. New intervals start upon reactor power reaching 25%

RTP.

COMANCHE PEAK - UNITS 1 AND 2 1.4-2 Amendment No.

Frequency 1.4 1.4 Frequency EXAMPLES (continued)

EXAMPLE 1.4-3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

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

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

> 25% RTP.

Perform channel adjustment. 7 days The interval continues, whether or not the unit operation is < 25% RTP between performances.

As the Note modifies the required performance of the Surveillance, it is construed to be part of the "specified Frequency." Should the 7 day interval be exceeded while operation is < 25% RTP, this Note allows 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after power reaches > 25% RTP to perform the Surveillance. The Surveillance is still considered to be performed within the "specified Frequency." Therefore, if the Surveillance were not performed within the 7 day (plus the extension allowed by SR 3.0.2) interval, but operation was < 25% RTP, it would not constitute a failure of the SR or failure to meet the LCO. Also, no violation of SR 3.0.4 occurs when changing MODES, even with the 7 day Frequency not met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power > 25% RTP.

Once the unit reaches 25% RTP, 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months would be allowed for completing the Surveillance. If the Surveillance were not performed within this 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months interval, there would then be a failure to perform a Surveillance within the specified Frequency, and the provisions of SR 3.0.3 would apply.

COMANCHE PEAK - UNITS 1 AND 2 1.4-3 Amendment No.

SLs 2.0 2.0 SAFETY LIMITS (SLs) 2.1 SLs

,2.1.1 Reactor Core SLs 2.1.1.1 In MODES 1 and 2, the departure from nucleate boiling ratio (DNBR) shall be maintained _>the 95/95 DNB criterion for the DNB correlation(s) specified in Section 5.6.5.

2.1.1.2 In MODES 1 and 2, the peak fuel centerline temperature shall be maintained < 4700°F.

2.1.2 RCS Pressure SL In MODES 1, 2, 3, 4, and 5, the RCS pressure shall be maintained < 2735 psig.

2.2 SL Violations 2.2.1 If SL 2.1.1 is violated, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2 If SL 2.1.2 is violated:

2.2.2.1 In MODE 1 or 2, restore compliance and be in MODE 3 within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

2.2.2.2 In MODE 3, 4, or 5, restore compliance within 5 minutes.

COMANCHE PEAK - UNITS 1 AND 2 2.0-1 Amendment No.

LCO Applicability 3.0 3.0 LIMITING CONDITION FOR OPERATION (LCO) APPLICABILITY LCO 3.0.1 LCOs shall be met during the MODES or other specified conditions in the Applicability, except as provided in LCO 3.0.2 and LCO 3.0.7.

LCO 3.0.2 Upon discovery of a failure to meet an LCO, the Required Actions of the associated Conditions shall be met, except as provided in LCO 3.0.5 and LCO 3.0.6.

If the LCO is met or is no longer applicable prior to expiration of the specified Completion Time(s), completion of the Required Action(s) is not required unless otherwise stated.

LCO 3.0.3 When an LCO is not met and the associated ACTIONS are not met, an associated ACTION is not provided, or if directed by the associated ACTIONS, the unit shall be placed in a MODE or other specified condition in which the LCO is not applicable. Action shall be initiated within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months to place the unit, as applicable, in:

a. MODE 3 within 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ;

b. MODE 4 within 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months ; and

c. MODE 5 within 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months .

Exceptions to this Specification are stated in the individual Specifications..

Where corrective measures are completed that permit operation in accordance with the LCO or ACTIONS, completion of the actions required by LCO 3.0.3 is not required.

LCO 3.0.3 is only applicable in MODES 1, 2, 3, and 4.

LCO 3.0.4 When an LCO is not met, entry into a MODE or other specified condition in the Applicability shall only be made:

a. When the associated ACTIONS to be entered permit continued operation in the MODE or other specified condition in the Applicability for an unlimited period of time; COMANCHE PEAK - UNITS 1 AND 2 3.0-1 Amendment No.

LCO Applicability 3.0 3.0 LCO APPLICABILITY LCO 3.0.4 (continued)

b. After performance of a risk assessment addressing inoperable systems and components, consideration of the results, determination of the acceptability of entering the MODE or other specified condition in the Applicability, and establishment of risk management actions, if appropriate; exceptions to this Specification are stated in the individual Specifications, or

c. When an allowance is stated in the individual value, parameter, or other Specification.

This Specification shall not prevent changes in MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

LCO 3.0.5 Equipment removed from service or declared inoperable to comply with ACTIONS may be returned to service under administrative control solely to perform testing required to demonstrate its OPERABILITY or the OPERABILITY of other equipment. This is an exception to LCO 3.0.2 for the system returned to service under administrative control to perform the testing required to demonstrate OPERABILITY.

LCO 3.0.6 When a supported system LCO is not met solely due to a support system LCO not being met, the Conditions and Required Actions associated with this supported system are not required to be entered. Only the support system LCO ACTIONS are required to be entered. This is an exception to LCO 3.0.2 for the supported system. In this event, an evaluation shall be performed in accordance with Specification 5.5.15, "Safety Function Determination Program (SFDP)." If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

When a support system's Required Action directs a supported system to be declared inoperable or directs entry into Conditions and Required Actions for a supported system, the applicable Conditions and Required Actions shall be entered in accordance with LCO 3.0.2.

COMANCHE PEAK - UNITS 1 AND 2 3.0-2 Amendment No.

LCO Applicability 3.0 3.0 LCO APPLICABILITY (continued)

LCO 3.0.7 Test Exception LCO 3.1.8, allows specified Technical Specification (TS) requirements to be changed to permit performance of special tests and operations. Unless otherwise specified, all other TS requirements remain unchanged. Compliance with Test Exception LCOs is optional. When a Test Exception LCO is desired to be met but is not met, the ACTIONS of the Test Exception LCO shall be met. When a Test Exception LCO is not desired to be met, entry into a MODE or other specified condition in the Applicability shall be made in accordance with the other applicable Specifications.

\.

COMANCHE PEAK - UNITS 1 AND 2 3.0-3 Amendment No.

SR Applicability 3.0 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY SR 3.0.1 SRs shall be met during the MODES or other specified conditions in the Applicability for individual LCOs, unless otherwise stated in the SR. Failure to meet a Surveillance, whether such failure is experienced during the performance of the Surveillance or between performances of the Surveillance, shall be failure to meet the. LCO. Failure to perform a Surveillance within the specified Frequency shall be failure to meet the LCO except as provided in SR 3.0.3. Surveillances do not have to be performed on inoperable equipment or I

variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met ifthe Surveillance is performed within 1.25 times the interval specified in the Frequency, as measured from the previous performance or as measured from the time a specified condition of the Frequency is met.

For Frequencies specified as "once," the above interval extension does not apply.

If a Completion Time requires periodic performance on a "once per.. ." basis, the above Frequency extension applies to each performance after the initial performance.

Exceptions to this Specification are stated in the individual Specifications.

SR 3.0.3 If it is discovered that a Surveillance was not performed within its specified Frequency, then compliance with the requirement to declare the LCO not met may be delayed, from the time of discovery, up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or up to the limit of the specified Frequency, whichever is greater. This delay period is permitted to allow performance of the Surveillance.

If the Surveillance is not performed within the delay period, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered. A risk evaluation shall be performed for any Surveillance delayed greater than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and the risk impact shall be managed.

When the Surveillance is performed within the delay period and the Surveillance is not met, the LCO must immediately be declared not met, and the applicable Condition(s) must be entered.

COMANCHE PEAK - UNITS 1 AND 2 3.0-4 Amendment No.

SR Applicability 3.0 3.0 SR APPLICABILITY (continued)

SR 3.0.4 Entry into a MODE or other specified condition in the Applicability of an LCO shall only be made when the LCO's Surveillances have been met within their specified Frequency, except as provided by SR 3.0.3. When an LCO is not met due to Surveillances not having been met, entry into a MODE or other specified condition in the Applicability shall only be made in accordance with LCO 3.0.4.

This provision shall not prevent entry into MODES or other specified conditions in the Applicability that are required to comply with ACTIONS or that are part of a shutdown of the unit.

COMANCHE PEAK - UNITS 1 AND 2 3.0-5 Amendment No.

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

LCO 3.1.1 SDM shall be within the limits provided in the COLR.

APPLICABILITY: MODE 2 with keff <,1.0, MODES 3, 4, and 5

---Ii I--------------------------------------------------

While this LCO is not met, entry into MODE 5 from MODE 6 is not permitted.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore SDM to 15 minutes within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.1.1 Verify SDM to be within limits. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.1-1 Amendment No.

Core Reactivity 3.1.2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 Core Reactivity LCO 3.1.2 The measured core reactivity shall be within +/- 1 % Ak/k of predicted values.

APPLICABILITY: MODES 1 and 2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Measured core reactivity A.1 Re-evaluate core design and safety 7 days not within limit, analysis, and determine that the reactor core is acceptable for continued operation.

AND A.2 Establish appropriate operating 7 days restrictions and SRs.

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

COMANCHE PEAK - UNITS 1 AND 2 3.1-2 Amendment No.

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

-I-SR 3.1.2.1 NOTE ------------------

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

Verify measured core reactivity is within +/- 1 % Ak/k of Once prior to predicted values. entering MODE 1 after each refueling AND NOTE- -

Only required after 60 EFPD 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.1-3 Amendment No.

MTC 3.1.3 3.1 REACTIVITY CONTROL SYSTEMS 3.1.3 Moderator Temperature Coefficient (MTC)

LCO 3.1.3 The MTC shall be maintained within the limits specified in the COLR. The maximum upper limit shall be that specified in Figure 3.1.3-1.

APPLICABILITY: MODE 1 and MODE 2 with keff _>1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. MTC not within upper limit. A.1 Establish administrative withdrawal 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months limits for control banks to maintain MTC within limit.

B. Required Action and B.1 Be in MODE 2 with keff < 1.0. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met.

C. MTC not within lower limit. C.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.1-4 Amendment No.

MTC 3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE 1 after each refueling SR 3.1.3.2 -----------------------

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

1. Not required to be performed until 7 effective full power days (EFPD) after reaching the equivalent of an equilibrium RTP all rods out (ARO) boron concentration of 300 ppm.

2. If the MTC is more negative than the 300 ppm Surveillance limit (not LCO limit) specified in the COLR, SR 3.1.3.2 shall be repeated once per 14 EFPD during the remainder of the fuel cycle.

3. SR 3.1.3.2 need not be repeated if the MTC measured at the equivalent of equilibrium RTP-ARO boron concentration of < 60 ppm is less negative than the 60 ppm Surveillance limit specified in the COLR.

Verify MTC is within lower limit. Once each cycle COMANCHE PEAK - UNITS 1 AND 2 3.1-5 Amendment No.

MTC 3.1.3 1

0.9 Ad 0

- 0.8 0.-

UNACCEPTABLE 0.7 OPERATION 0.3

- 0.6 0 ACCEPTABLE OPERATION

=0.4

'= 0.1 0

j 0 10 20 30 40 50 60 70 80 90 100 Percent Rated Thermal Power Figure 3.1.3-1 (page 1 of 1)

Moderator Temperature Coefficient vs. Power Level COMANCHE PEAK - UNITS 1 AND 2 3.1-6 Amen(iment No.

Rod Group Alignment Limits 3.1.4 3.1 REACTIVITY CONTROL SYSTEMS 3.1.4 Rod Group Alignment Limits LCO 3.1.4 All shutdown and control rods shall be OPERABLE.

AND llndividual indicated rod positions shall be within 12 steps of their group step counter demand position.

APPLICABILITY: MODES 1 and 2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more rod(s) A.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable, provided in the COLR.

OR A.1.2 Initiate boration to restore SDM to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit.

AND A.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-7 Amendment No.

Rod Group Alignment Limits 3.1.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One rod not within B.1 Restore rod to within alignment limits. 11 hour1.273148e-4 days 0.00306 hours 1.818783e-5 weeks 4.1855e-6 months alignment limits.

OR B.2.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months provided in the COLR.

OR B.2.1.2 Initiate boration to restore SDM to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit.

AND B.2.2 Reduce THERMAL POWER to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

75% RTP.

AND B.2.3 Verify SDM to be within the limits Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months provided in the COLR.

AND B.2.4 Perform SR 3.2.1.1 and SR 3.2.1.2.172 hours0.00199 days 0.0478 hours 2.843915e-4 weeks 6.5446e-5 months AND B.2.5 Perform SR 3.2.2.1. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AND B.2.6 Re-evaluate safety analyses and 5 days confirm results remain valid for duration of operation under these conditions.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-8 Amendment No.

Rod Group Alignment Limits 3.1.4 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 of Condition B not met.

D. More than one rod not D.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within alignment limit, provided in the COLR.

OR D.1.2 Initiate boration to restore required 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SDM to within limit.

AND D.2 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.4.1 Verify individual rod positions within alignment limit. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.1.4.2 Verify rod freedom of movement (trippability) by moving 92 days each rod not fully inserted in the core > 10 steps in either direction.

SR 3.1.4.3 Verify rod drop time of each rod, from the fully withdrawn Prior to reactor position, is < 2.7 seconds from the beginning of decay of criticality after each stationary gripper coil voltage to dashpot entry, with: removal of the reactor head

a. Tavg > 5 0 0 'F; and

b. All reactor coolant pumps operating.

COMANCHE PEAK - UNITS 1 AND 2 3.1-9 Amendment No.

Shutdown Bank Insertion Limits 3.1.5 3.1 REACTIVITY CONTROL SYSTEMS 3.1.5 Shutdown Bank Insertion Limits LCO 3.1.5 Each shutdown bank shall be within insertion limits specified in the COLR.

APPLICABILITY: MODE 1, MODE 2 with any control bank not fully inserted.

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

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more shutdown A.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months banks not within limits, provided in the COLR.

OR A.1.2 Initiate boration to restore SDM to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit.

AND A.2 Restore shutdown banks to within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits.

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

COMANCHE PEAK - UNITS 1 AND 2 3.1-10 Amendment No.

Shutdown Bank Insertion Limits 3.1.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.5.1 Verify each shutdown bank is within the limits specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the COLR.

COMANCHE PEAK - UNITS 1 AND 2 3.1-11 Amendment No.

Control Bank Insertion Limits 3.1.6 3.1 REACTIVITY CONTROL SYSTEMS 3.1.6 Control Bank Insertion Limits LCO 3.1.6 Control banks shall be within the insertion, sequence, and overlap limits specified in the COLR.

APPLICABILITY: MODE 1, MODE 2 with keff > 1.0.

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

This LCO is not applicable while performing SR 3.1.4.2.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Control bank insertion limits A.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not met. provided in the COLR.

OR A.1.2 Initiate boration to restore SDM to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit.

AND A.2 Restore control bank(s) to within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months limits.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-12 Amendment No.

Control Bank Insertion Limits 3.1.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Control bank sequence or B.1.1 Verify SDM to be within the limits 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months overlap limits not met. provided in the COLR.

OR B.1.2 Initiate boration to restore SDM to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months within limit.

AND B.2 Restore control bank sequence and 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months overlap to within limits.

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 3.1.6.1 Verify estimated critical control bank position is within the Within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months prior limits specified in the COLR. to achieving criticality SR 3.1.6.2 Verify each control bank insertion is within the limits 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months specified in the COLR.

SR 3.1.6.3 Verify sequence and overlap limits specified in the COLR 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months are met for control banks not fully withdrawn from the core.

COMANCHE PEAK - UNITS 1 AND 2 3.1-13 Amendment No.

Rod Position Indication 3.1.7 3.1 REACTIVITY CONTROL SYSTEMS 3.1.7 Rod Position Indication LCO 3.1.7 The Digital Rod Position Indication (DRPI) System and the Demand Position Indication System shall be OPERABLE APPLICABILITY: MODES 1 and 2.

ACTIONS

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

Separate Condition entry is allowed for each inoperable rod position indicator and each demand position indicator per bank.

CONDITION REQUIRED ACTION COMPLETION TIME A. One DRPI per group A.1 Verify the position of the rods with Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable for one or more inoperable position indicators groups. indirectly by using core power distribution measurement information.

OR A.2 Reduce THERMAL POWER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

50% RTP.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-14 Amendment No.

Rod Position Indication 3.1.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. More than one DRPI per B.1 Place the control rods under manual Immediately group inoperable, control.

AND B.2 Monitor and record RCS Tavg. Once per 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND B.3 Verify the position of the rods with Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable position indicators indirectly by using core power distribution measurement information.

AND B.4 Restore inoperable position 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months indicators to OPERABLE status such that a maximum of one DRPI per group is inoperable.

C. One or more rods with C.1 Verify the position of the rods with 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months inoperable DRPIs have inoperable position indicators been moved in excess of indirectly by using core power 24 steps in one direction distribution measurement informtion.

since the last determination of the rod's position. OR C.2 Reduce THERMAL POWER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

50% RTP.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-15 Amendment No.

Rod Position Indication 3.1.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One demand position D.1.1 Verify by administrative means all Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months indicator per bank DRPIs for the affected banks are inoperable for one or more OPERABLE.

banks.

AND D.1.2 Verify the most withdrawn rod and Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months the least withdrawn rod of the affected banks are < 12 steps apart.

OR D.2 Reduce THERMAL POWER to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

50% RTP.

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.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.7.1 Verify each DRPI agrees within 12 steps of the group Once prior to demand position for the full indicated range of rod travel, criticality after each removal of the reactor vessel head.

COMANCHE PEAK - UNITS 1 AND 2 3.1-16 Amendment No.

PHYSICS TESTS Exceptions - MODE 2 3.1.8 3.1 REACTIVITY CONTROL SYSTEMS 3.1.8 PHYSICS TESTS Exceptions - MODE 2 LCO 3.1.8 During the performance of PHYSICS TESTS, the requirements of LCO 3.1.3, "Moderator Temperature Coefficient (MTC)";

LCO 3.1.4, "Rod Group Alignment Limits";

LCO 3.1.5, "ShutdownBank Insertion Limits";

LCO 3.1.6, "Control Bank Insertion Limits"; and LCO 3.4.2, "RCS Minimum Temperature for Criticality" may be suspended, provided:

a. RCS lowest operating loop average temperature is > 541 'F; and

b. SDM is within the limits provided in the COLR; and

c. THERMAL POWER is

5% RTP APPLICABILITY: MODE 2 during PHYSICS TESTS.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDM not within limit. A.1 Initiate boration to restore SDM to 15 minutes within limit.

AND A.2 Suspend PHYSICS TESTS 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months exceptions.

B. THERMAL POWER not B.1 Open reactor trip breakers. Immediately within limit.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-17 Amendment No.

PHYSICS TESTS Exceptions - MODE 2 3.1.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. RCS lowest operating loop C.1 Restore RCS lowest operating loop 15 minutes average temperature not average temperature to within limit.

within limit.

D. Required Action and D.1 Be in MODE 3. 15 minutes associated Completion Time of Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.8.1 Perform a CHANNEL OPERATIONAL TEST on power Prior to initiation of range and intermediate range channels per SR 3.3.1.7, SR PHYSICS TESTS 3.3.1.8, and Table 3.3.1-1.

SR 3.1.8.2 Verify the RCS lowest operating loop average temperature 30 minutes is >_541 OF.

SR 3.1.8.3 Verify THERMAL POWER is *5% RTP. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months SR 3.1.8.4 Verify SDM is within the limits provided in the COLR. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COMANCHE PEAK - UNITS 1 AND 2 '3.1-18 Amendment No.

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel (FQ(Z)) (RAOC-W(Z) Methodology)

LCO 3.2.1 FQ(Z), as approximated by FC(Z) and F w(Z), shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------- NOTE ---------------

Required Action A.4 shall be completed whenever this Condition is entered.

FC(Z) not within limit. A.1 Reduce THERMAL POWER > 1% 15 minutes after each RTP for each 1% F~c(Z) exceeds FC(Z) determination limit.

AND A.2 Reduce Power Range Neutron Flux-- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each High trip setpoints > 1% for each 1 % FC(Z) determination FQ(Z) exceeds limit.

AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-1 Amendment No.

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Reduce Overpower N-16 trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after each setpoints _ 1% for each 1% Fc(Z) FC(Z) determination exceeds limit.

AND A.4 Perform SR 3.2.1.1 and SR 3.2.1.2. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-2' Amendment No.

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. --------- NOTE--------

Required Action B.4 shall be completed whenever this Condtion is entered.

FW (Z) not within limits. B.1 Reduce AFD limits> 1% foreach 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months FQ(Z) exceeds limit.

AND B.2 Reduce Power Range Neutron Flux-- 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months High trip setpoints > 1% for each 1%

that the maximum allowable power of the AFD limits is reduced:

AND B.3 Reduce Overpower N-16 trip 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months setpoints > 1% for each 1% that the maximum allowable power of the AFD limits is reduced.

AND B.4 Perform SR 3.2.1.1 and SR 3.2.1.2. Prior to increasing THERMAL POWER above the maximum allowable power of the AFD limits.

C. Required Action and C.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

COMANCHE PEAK - UNITS 1 AND 2 3.2 Amendment No.

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS

ILj r---------------------------------------------------------------

During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved at which a power distribution measurement is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify FC(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions after exceeding, by

> 20% RTP, the THERMAL POWER at which Fc(Z) was last verified AND 31 EFPD thereafter (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-4 Amendment No.

1

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1.2 ----------------------- NOTES -----------------

If FC(Z) measurements indicate maximum over z [K(Z)]

has increased since the previous evaluation of FC(Z):

a. Increase FW(Z) by the appropriate factor specified in the COLR and reverify FW(Z) is within limits; or

b. Repeat SR 3.2.1.2 once per 7 EFPD until either a.

above is met or two successive power distribution FF (Z)]

measurements indicate maximum over z K(Z) has not increased.

Verify FQN(Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-5 Amendment No.

FQ(Z) (RAOC-W(Z) Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.1.2 (continued) Once within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving equilibrium conditions after exceeding, by

> 20% RTP, the THERMAL POWER at which FC(Z) was last verified AND 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.2-6 Amendment No.

N FAH 3.2.2 3.2 POWER DISTRIBUTION LIMITS 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FNH)

LCO 3.2.2 FNH shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------- NOTE-------

Required Actions A.2 and A.3 must be completed whenever Condition A.is entered.

N N FAH not within limit. A.1.1 Restore FAH to within limit. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months OR A.1.2.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

< 50% RTP.

AND A.1.2.2 Reduce Power Range Neutron 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Flux- High trip setpoints to < 55%

RTP.

AND A.2 Perform SR 3.2.2.1. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-7 Amendment No.

N FAH 3.2.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 ----------- NOTE-.------------------

THERMAL POWER does not have to be reduced to comply with this Required Action.

Perform SR 3.2.2.1. Prior to THERMAL POWER exceeding 50% RTP AND Prior to THERMAL POWER exceeding 75% RTP AND 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER reaching > 95% RTP B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met.

COMANCHE PEAK - UNITS 1 AND 2 3.2-8 Amendment No.

N FAH 3.2.2 SURVEILLANCE REQUIREMENTS

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

During power escalation following shutdown, THERMAL POWER may be increased until an equilibrium power level has been achieved at which a power distribution measurement is obtained.

SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FNH is within limits specified in the COLR. Once afterprior refueling eachto THERMAL POWER exceeding 75% RTP AND 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.2-9 Amendment No.

'"AFD (RAOC Methodology) 3.2.3 3.2 POWER DISTRIBUTION LIMITS 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Relaxed Axial Offset Control (RAOC) Methodology)

LCO 3.2.3 The AFD in % flux difference units shall be maintained within the limits specified'in the COLR.

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

The AFD shall be considered outside the target band when two or more OPERABLE excore channels indicate'AFD to be outside limits.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. AFD not within limits. A.1 Restore THERMAL POWER to < 30 minutes 50% RTP.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD is within limits for each OPERABLE excore 7 days channel.

COMANCHE PEAK - UNITS 1 AND 2 3.2-10 Amendment No.

QPTR 3.2.4 3.2 POWER DISTRIBUTION LIMITS 3.2.4 QUADRANT POWER TILT RATIO (QPTR)

LCO 3.2.4 The QPTR shall be < 1.02.

APPLICABILITY: MODE 1 with THERMAL POWER > 50% RTP ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. QPTR not within limit. A.1 Reduce THERMAL POWER > 3% 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months after each from RTP for each 1% of QPTR QPTR determination

>1.00.

AND A.2 Determine QPTR. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND A.3 Perform SR 3.2.1.1, SR 3.2.1.2 and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after achieving SR 3.2.2.1. equilibrium conditions from a THERMAL POWER reduction per Required Action A.1 AND Once per 7 days thereafter AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-11 Amendment No.

QPTR 3.2.4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.4 Reevaluate safety analyses and Prior to increasing confirm results remain valid for THERMAL POWER duration of operation under this above the limit of condition. Required Action A.1 AND A.5 ------------ NOTES -----------

1. Perform Required Action A.5 only after Required Action A.4 is completed.

2. Required action A.6 shall be completed whenever Required Action A.5 is performed.

Normalize excore detectors to restore Prior to increasing QPTR to within limit. THERMAL POWER above the limit of Required Action A.1 AND A.6 ------------- NOTE --------------------

Perform Required Action A.6 only after Required Action A.5 is completed.

Perform SR 3.2.1.1, SR 3.2.1.2 and Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SR 3.2.2.1. achieving equilibrium conditions at RTP not to exceed 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months after increasing THERMAL POWER above the limit of Required Actions A.1 B. Required Action and B.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months associated Completion *50% RTP.

Time not met.

COMANCHE PEAK - UNITS 1 AND 2 3.2-12 Amendment No.

QPTR 3.2.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY i

SR 3.2.4.1 --------------------- NOTES -----------------

1. With input from one Power Range Neutron Flux channel inoperable and THERMAL POWER < 75%.

RTP, the remaining three power range channels can be used for calculating QPTR.

2. SR 3.2.4.2 may be performed in lieu of this Surveillance.

Verify QPTR is within limit by calculation. 7 days SR 3.2.4.2 -- -------------------- NOTE ------------------------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after input from one or more Power Range Neutron Flux channels are inoperable with THERMAL POWER > 75% RTP.

Verify QPTR is within limit using the core power distribution 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months measurement information..

COMANCHE PEAK - UNITS 1 AND 2 3.2-13 Amendment No.

RTS Instrumentation 3.3.1 3.3 INSTRUMENTATION 3.3.1 Reactor Trip System (RTS) Instrumentation LCO 3.3.1 The RTS instrumentation for each Function in Table 3.3.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.1-1 ACTIONS

NOT r-----------------------------------------------------------------

Separate Condition entry is allowed for each Functii CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with A.1 Enter the Condition referenced in Immediately one or more required Table 3.3.1-1 for the channel(s) or channels or trains train(s).

inoperable.

B. One Manual Reactor Trip B.1 Restore channel to OPERABLE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months channel inoperable, status.

OR B.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------- NOTE-------

While this LCO is not met for Function 19, 20, or 21, in MODE 5, making the Rod Control System capable of rod withdrawal is not permitted.

One channel or train C.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR C.2.1 Initiate action to fully insert all rods. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months AND C.2.2 Place the Rod Control System in a 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months condition incapable of rod withdrawal.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-2 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One Power Range Neutron - ----------------------- NOTE------------

Flux - High channel One channel may be bypassed for up to inoperable. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing and setpoint adjustment.

D.1.1 ---------- NOTE ----------

Only required to be performed when the Power Range Neutron Flux input to QPTR is inoperable.

Perform SR 3.2.4.2. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery of THERMAL POWER >

75% RTP AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND D.1.2 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR D.2 Be in MODE 3 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-3 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One channel inoperable. --------------- NOTE ------------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

E.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months F. One Intermediate Range FA Reduce THERMAL POWER to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months Neutron Flux channel < P-6.

inoperable.

OR F.2 Increase THERMAL POWER to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

> P-10.

G. Two Intermediate Range G.1 ---------- NOTE ------------

Neutron Flux channels Limited boron concentration changes inoperable, associated with RCS inventory control or limited plant temperature changes are allowed.

Suspend operations involving Immediately positive reactivity additions.

AND G.2 Reduce THERMAL POWER to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months

< P-6.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-4 Amendment No.

(

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Not used.

1. One Source Range ------------------- NOTE ------------

Neutron Flux channel Limited boron concentration changes inoperable, associated with RCS inventory control or limited plant temperature changes are allowed.

1.1 Suspend operations involving Immediately positive reactivity additions.

J. Two Source Range Neutron J.1 Open reactor trip breakers (RTBs). Immediately Flux channels inoperable.

K. One Source Range K.1 Restore channel to OPERABLE 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months Neutron Flux channel status.

inoperable.

OR K.2.1 Initiate action to fully insert all rods. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months AND K.2.2 Place the Rod Control System in a 49 hours5.671296e-4 days 0.0136 hours 8.101852e-5 weeks 1.86445e-5 months condition incapable of rod withdrawal.

L. Not used.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-5 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME M. One channel inoperable. --------------- NOTE ------------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

M.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR M.2 Reduce THERMAL POWER to 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months

< P-7.

N. Not used.

0. One Low Fluid Oil pressure ------------- NOTE ------------

Turbine Trip channel One channel may be bypassed for up to inoperable. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

0.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 0.2 Reduce THERMAL POWER to 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months

< P-9.

P. One or more Turbine Stop P.1 Place channel(s) in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Valve Closure Turbine Trip channel(s) inoperable. OR P.2 Reduce THERMAL POWER to 76 hours8.796296e-4 days 0.0211 hours 1.256614e-4 weeks 2.8918e-5 months

< P-9.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-6 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME Q. One train inoperable. ------------------ NOTE ------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

Q.1 Restore train to OPERABLE status. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR Q.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months R. One RTB train inoperable. -------------- NOTE ------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing or maintenance, provided the other train is OPERABLE.

R.1 Restore train to OPERABLE status. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR R.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months S. One or more required S.1 Verify interlock is in required state for 1lhour channel(s) inoperable, existing unit conditions.

OR S.2 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-7 Amendment No.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME T. One or more required T.1 Verify interlock is in required state for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months channel(s) inoperable, existing unit conditions.

OR T.2 Be in MODE 2. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months U. One trip mechanism U.1 Restore inoperable trip mechanism to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable for one RTB. OPERABLE status.

OR U.2 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months V. Not used.

SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.1-1 to determine which SRs apply for each RTS Function.

SURVEILLANCE FREQUENCY SR 3.3.1.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-8 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2 ---------------------- NOTE -----------

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

Compare results of calorimetric heat balance calculation to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months NIS Power Range channel and N-16 Power Monitor channel outputs. Adjust NIS Power Range channel outputs if calorimetric heat balance calculation exceeds NIS Power Range channel outputs by more than +2% RTP. Adjust N-16 Power Monitor channel outputs if calorimetric heat balance calculation exceeds N-16 Power Monitor channel outputs by more than +2% RTP.

SR 3.3.1.3 ----------------------- NOTE ------------------

Not required to be performed until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after THERMAL POWER is Ž 50% RTP.

Compare results of the .core power distribution 31 effective full measurements to Nuclear Instrumentation System (NIS) power days (EFPD)

AFD. Adjust NIS channel if absolute difference is > 3%.

SR 3.3.1.4 ----------------------- NOTE ------------------

This Surveillance must be performed on the reactor trip bypass breaker for the local manual shunt trip only prior to placing the bypass breaker in service.

Perform TADOT. 62 days on a STAGGERED TEST BASIS (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-9 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.5 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.1.6 ----------------------- NOTE ------------------

Not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after achieving equilibrium conditions with THERMAL POWER _ 75%

RTP.

Calibrate excore channels to agree with core power 92 EFPD distribution measurements.

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

1. Not required to be performed for source range instrumentation prior to entering MODE 3 from MODE 2 until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after entry into MODE 3.

2. Source range instrumentation shall include verification that interlocks P-6 and P-1 0 are in their required state for existing unit conditions.

Perform COT. 184 days (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-10 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.8 -NOTE-This Surveillance shall include verification that interlocks P-6 and P-1 0 are in their required state for existing unit conditions.

Perform COT. .--------

NOTE ----------

Only required when not performed within previous 184 days Prior to reactor startup AND 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after reducing power below P-10 for power and intermediate instrumentation AND Four hours after reducing power below P-6 for source range instrumentation AND Every 184 days thereafter (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-11 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

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

Verification of setpoint is not required.

Perform TADOT. 92 days SR 3.3.1.10 --------------------- NOTES ------------------

1. N-16 detectors are excluded from CHANNEL CALIBRATION.

2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

3. Prior to entry into MODES 2 or 1, N-1 6 detector plateau verification is not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after achieving equilibrium conditions with THERMAL POWER Ž_90% RTP.

Perform CHANNEL CALIBRATION. 18 months SR 3.3.1.11 ---------------------- NOTES -----------------

1. Neutron detectors are excluded from CHANNEL CALIBRATION.

2. This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

3. Prior to entry into MODES 2 or 1, power and intermediate range detector plateau verification is not required to be performed until 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months after achieving equilibrium conditions with THERMAL POWER _>90%

RTP.

Perform CHANNEL CALIBRATION. 18 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-12 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.12 Not used.

SR 3.3.1.13 Perform COT. 18 months SR 3.3.1.14 ---------------------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.1.15 - -------------------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. Prior to exceeding the P-9 interlock whenever the unit has been in MODE 3, if not performed in previous 31 days SR 3.3.1.16 ---------------------- NOTE ------------------

Neutron and N-16 detectors are excluded from response time testing.

Verify RTS RESPONSE TIMES are within limits. 18 months on a STAGGERED TEST BASIS COMANCHE PEAK - UNITS 1 AND 2 3.3-13 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 6)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

1. Manual Reactor Trip 1,2 2 B SR 3.3.1.14 NA 3 (b), 4 (b), 5 (b) 2 C SR 3.3.1.14 NA

2. Power Range Neutron Flux

a. High 1,2 4 D SR 3.3.1.1 < 109.6% RTp(q)(r)

SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.11 SR 3.3.1.16

b. Low 1(c), 2 4 E SR 3.3.1.1 <25.6% RTP(q)(r)

SR 3.3.1.8 SR 3.3.1.11 SR 3.3.1.16

3. Power Range Neutron 1,2 4 E SR 3.3.1.7 <6.3% RTP Flux Rate High SR 3.3.1.11 with time constant Positive Rate > 2 sec

4. Intermediate Range 1 (c), 2 (d) 2 FG SR 3.3.1.1 < 31.5% RTP Neutron Flux SR 3.3.1.8 SR 3.3.1.11 (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(c) Below the P-1 0 (Power Range Neutron Flux) interlock.

(d) Above the P-6 (Intermediate Range Neutron Flux) interlock.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

COMANCHE PEAK - UNITS 1 AND 2 3.3-14 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 6)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Source Range Neutron 2 (e) 2 I,J SR 3.3.1.1 <1.4 E5 cps Flux SR 3.3.1.8 SR 3.3.1.11 3 (b), 4 (b) 5 (b) 2 J,K SR 3.3.1.1 :< 1.4 E5 cps SR 3.3.1.7 SR 3.3.1.11

6. Overtemperature 1,2 4 E SR 3.3.1.1 Referto Note 1(q)(r)

N-1 6 SR 3.3.1.2 SR 3.3.1.3 SR 3.3.1.6 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

7. Overpower N-16 1,2 4 E SR 3.3.1.1 _112.8% RTP SR 3.3.1.2 (q)(r)

SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

8. Pressurizer Pressure

a. Low 1 (g) 4 M SR 3.3.1.1 >1863.6 psig SR 3.3.1.7 (Unit 1)

SR 3.3.1.10 > 1865.2 psig SR 3.3.1.16 (Unit 2)

b. High 1,2 4 E SR 3.3.1.1 <2400.8 psig SR 3.3.1.7 (Unit 1)

SR 3.3.1.10 <2401.4 psig SR 3.3.1.16 (Unit 2)

(continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Control System capable of rod withdrawal or one or more rods not fully inserted.

(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.

(g) Above the P-7 (Low Power Reactor Trips Block) interlock.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

COMANCHE PEAK - UNITS 1 AND 2 3.3-15 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 3 of 6)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

9. PressurizerWaterLevel- l(g) 3 M SR 3.3.1.1 < 93.9% of High SR 3.3.1.7 instrument span SR 3.3.1.10

10. Reactor Coolant Flow - l(g) 3 per loop M SR 3.3.1.1 2!88.6% of indicated Low SR 3.3.1.7 loop flow (Unit 1)

SR 3.3.1.10 _>88.8% of indicated SR 3.3.1.16 loop flow (Unit 2)

11. Not Used

12. Undervoltage l(g) 1 per bus M SR 3.3.1.9 > 4753 V RCPs SR 3.3.1.10 SR 3.3.1.16

13. Underfrequency 1 (g) 1 per bus M SR 3.3.1.9 Ž 57.06 Hz RCPs SR 3.3.1.10 SR 3.3.1.16

14. Steam Generator (SG) 1, 2 4 per SG E SR 3.3.1.1 > 37.5% of narrow Water Level Low-Low (I) SR 3.3.1.7 range instrument SR 3.3.1.10 span SR 3.3.1.16 (Unit 1) (q)(r)

_>34.9% of narrow range instrument span (Unit 2 )(q)(r)

15. Not Used.

(continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(g) Above the P-7 (Low Power Reactor Trips Block) interlock.

(I) The applicable MODES for these channels in Table 3.3.2-1 are more restrictive.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

COMANCHE PEAK - UNITS 1 AND 2 3.3-16 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 6)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

16. Turbine Trip

a. Low Fluid Oil 10) 3 0 SR 3.3.1.10 > 46.6 psig Pressure SR 3.3.1.15 P SR 3.3.1.10

b. Turbine Stop Valve 10) 4 Ž1% open Closure SR 3.3.1.15

17. Safety Injection (SI) Input 1,2 2 trains Q SR 3.3.1.14 NA from Engineered Safety Feature Actuation System (ESFAS)

18. Reactor Trip System Interlocks

a. Intermediate Range (e) 2 S SR 3.3.1.11 > 6E-11 amp 2

Neutron Flux, P-6 SR 3.3.1.13

b. Low Power Reactor 1 per train T SR 3.3.1.5 NA Trips Block, P-7 c.. Power Range 1 4 T SR 3.3.1.11 <50.7% RTP Neutron Flux, P-8 SR 3.3.1.13 1

d. Power Range 4 T SR 3.3.1.11 < 52.7% RTP Neutron Flux, P-9 SR 3.3.1.13

e. Power Range 1,2 4 S SR 3.3.1.11 > 7.3% RTP and Neutron Flux, P-10 SR 3.3.1.13 <512.7% RTP

f. Turbine First Stage 2 T SR 3.3.1.10 < 12.7% turbine Pressure, P-13 SR 3.3.1.13 power

19. Reactor Trip 1,2 2 trains R SR 3.3.1.4 NA Breakers(RTBs)(k) 3 (b), 4 (b), 5 (b) 2 trains C SR 3.3.1.4 NA (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Contol System capable of rod withdrawal or one or more rods not fully inserted.

(e) Below the P-6 (Intermediate Range Neutron Flux) interlock.

(j) Above the P-9 (Power Range Neutron Flux) interlock.

(k) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

COMANCHE PEAK - UNITS 1 AND 2 3.3-17 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 5 of 6)

Reactor Trip System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

20. Reactor Trip Breaker 1,2 1 each per RTB U SR 3.3.1.4 NA Undervoltage and Shunt Trip Mechanisms(k) 3 (b), 4 (b), 5 (b) 1 each per RTB C SR 3.3.1.4 NA

21. Automatic Trip Logic 1,2 2 trains Q SR 3.3.1.5 NA 3 (b), 4 (b), 5 (b) 2 trains C SR 3.3.1.5 NA (continued)

(a) The Allowable Value defines the limiting safety system setting except for Trip Functions 2a, 2b, 6, 7, and 14 (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) With Rod Contol System capable of rod withdrawal or one or more rods not fully inserted.

(k) Including any reactor trip bypass breakers that are racked in and closed for bypassing an RTB.

COMANCHE PEAK - UNITS 1 AND 2 3.3-18 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 6 of 6)

Reactor Trip System Instrumentation Note 1: Overtemperature N-16 The Overtemperature N-16 Function Allowable Values shall not exceed the following setpoint by more than 0.5% N-16 span for N-1 6 input, 0.5% Tcold span for Tcold input, 0.5% pressure span for pressure input, and 0.5% Aq span for Aq input.

Qsetpoint K1 - K2[1 Tc- T] + K3 (Plp1) _fl(Aq)

Where:

Qsetpoint = Overtemperature N-1 6 trip setpoint, r K2 = '/OF K3 = */psig Tc = Measured cold leg temperature, °F T° c = Indicated reference Tc at RATED THERMALPOWER, *°F P = Measured pressurizer pressure, psig p1 psig (Nominal RCS operating pressure) s = the Laplace transform operator, sec-1 .

T1,T2 = Time constants utilized in lead-lag controller for Tc, r"l

sec, and "2 <

sec f,(Aq) = *{(qt - qb) + *%} when (qt - qb) < *% RTP 0% when *%RTP < (qt - qb) < *% RTP

(qt - qb) - *%} when (qt - qb) > *% RTP COMANCHE PEAK - UNITS 1 AND 2 3.3-19 Amendment No.

ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 Engineered Safety Feature Actuation System (ESFAS) Instrumentation LCO 3.3.2 The ESFAS instrumentation for each Function in Table 3.3.2-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2-1 ACTIONS

1,tj r7 -------------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with A.1 Enter the Condition referenced in Immediately one or more required Table 3.3.2-1 for the channel(s) or channels or trains train(s).

inoperable.

B. One channel or train B.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR B.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND B.2.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-20 Amendment No.

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One train inoperable. ----------------- NOTE------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

C.1 Restore train to OPERABLE status. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR C.2.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND C.2.2 Be in MODE 5. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months D. One channel inoperable. --------------- NOTE------------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

D.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR D.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND D.2.2 Be in MODE 4. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-21 Amendment No.

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Containment Pressure ------------- NOTE------------

channel inoperable. One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

E.1 Place channel in bypass. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR E.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND E.2.2 Be in MODE 4. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months F. One channel or train F.1 Restore channel or train to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months inoperable. OPERABLE status.

OR F.2.1 Be in MODE 3. 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months AND F.2.2 Be in MODE 4. 60 hours6.944444e-4 days 0.0167 hours 9.920635e-5 weeks 2.283e-5 months (continued)

A COMANCHE PEAK - UNITS 1 AND 2 8.3-22 Amendment No.

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

'G. One train inoperable. ----------------- NOTE------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

G.1 Restore train to OPERABLE status. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR G.2.1 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months AND G.2.2 Be in MODE 4. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months H. One train inoperable. ----------------- NOTE------------

One train may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other train is OPERABLE.

H.1 Restore train to OPERABLE status. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OR H.2 Be in MODE 3. 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-23 Amendment No.

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME I. One channel inoperable. --------------- NOTE------------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

1.1 Place channel in trip. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR 1.2 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months J. One Main Feedwater Pump J.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months trip channel inoperable.

OR J.2 Be in MODE 3. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months K. One channel inoperable. --------------- NOTE------------

One channel may be bypassed for up to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for surveillance testing.

K.1 Place channel in bypass. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR K.2.1 Be in MODE 3. 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND K.2.2 Be in MODE 5. 108 hours0.00125 days 0.03 hours 1.785714e-4 weeks 4.1094e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-24 Amendment No.

ESFAS Instrumentation 3.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME L. One or more required L.1 Verify interlock is in required state for 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months channel(s) inoperable, existing unit condition.

OR L.2.1 Be in MODE 3. 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND L.2.2 Be in MODE 4. 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months SURVEILLANCE REQUIREMENTS

NOTE --------------.7.-- -- -----------

Refer to Table 3.3.2-1 to determine which SRs apply for each ESFAS Function.

SURVEILLANCE FREQUENCY SR 3.3.2.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.2.2 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.2.3 Not Used.

SR 3.3.2.4 Perform MASTER RELAY TEST. 92 days on a STAGGERED TEST BASIS (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-25 Amendment No.

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.5 Perform COT. 184 days SR 3.3.2.6 Perform SLAVE RELAY TEST. 92 days OR 18 months for Westinghouse type AR relays with AC coils SR 3.3.2.7 ----------------------- NOTES ------------------

1. Verification of relay setpoints not required.

2. Actuation of final devices not included.

Perform TADOT. 31 days SR 3.3.2.8 ----------------------- NOTE ------------------

Verification of setpoint not required for manual initiation functions.

Perform TADOT. 18 months SR 3.3.2.9 ----------------------- NOTE ------------------

This Surveillance shall include verification that the time constants are adjusted to the prescribed values.

Perform CHANNEL CALIBRATION. 18 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-26 Amendment No.

ESFAS Instrumentation 3.3.2 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.2.10 - -------------------- NOTE ------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after SG pressure is _>532 psig.

Verify ESF RESPONSE TIMES are within limits. 18 months on a STAGGERED TEST BASIS SR 3.3.2.11 ----------------------- NOTE ------------------

Verification of setpoint not required.

Perform TADOT. 18 months COMANCHE PEAK - UNITS 1 AND 2 3.3-27 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 1 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

1. Safety Injection

a. Manual Initiation 1, 2, 3,4 2 B SR 3.3.2.8 NA

b. Automatic Actuation 1, 2, 3, 4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment 1,2, 3 3 D SR 3.3.2.1 < 3.8 psig Pressure -- High 1 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

d. PressurizerPressure 1, 2, 3 (b) 4 D SR 3.3.2.1 > 1803.6 psig

-- Low SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

e. Steam Line Pressure 1, 2, 3 (b) 3 per steam line D SR 3.3.2.1 > 594.0 psig(c)

Low SR 3.3.2.5 (Unit 1)

SR 3.3.2.9 >-578.4 psig(c)

SR 3.3.2.10 (nt2 (Unit 2)

2. Containment Spray

a. Manual Initiation 1, 2, 3, 4 2 per train, B SR 3.3.2.8 NA 2 trains

b. Automatic Actuation 1, 2, 3, 4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment 1,2,3 4 E SR 3.3.2.1 _<18.8 psig Pressure SR 3.3.2.5 High -- 3 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) interlock and below P-11, unless the Function is blocked.

(c) Time constants used in the lead/lag controller are T1 _>10 seconds and T2 *5 seconds.

COMANCHE PEAK - UNITS 1 AND 2 3.3-28 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 2 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS .CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

3. Containment Isolation

a. Phase A Isolation (1) Manual Initiation 1, 2, 3, 4 2 B SR 3.3.2.8 NA (2) Automatic 1, 2, 3, 4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (3) Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

b. Phase B Isolation (1) Manual Initiation 1,2, 3,4 2 per train, B SR 3.3.2.8 NA 2 trains (2) Automatic 1, 2, 3, 4 2 trains C SR 3.3.2.2 NA Actuation Logic SR 3.3.2.4 and Actuation SR 3.3.2.6 Relays (3). Containment 1,2,3 4 E SIR 3.3.2.1 <18.8 psig Pressure SR 3.3.2.5 High -- 3 SR 3.3.2.9 (continued)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

COMANCHE PEAK - UNITS 1 AND 2 3.3-29 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

4. Steam Line Isolation

a. Manual Initiation 1, 2 (i), 3 0i) 2 F SR 3.3.2.8 NA

b. Automatic Actuation 1, 2 (i), 3 (i) 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

c. Containment 1, 2 0i),3 0i) 3 D SR 3.3.2.1

6.8 psig Pressure -- High 2 SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10

d. Steam Line Pressure (1) Low 1, 2 (i), 3 (b)(i) 3 per steam line D SR 3.3.2.1 >594.0 psig(c)

SR 3.3.2.5 (Unit 1)

SR 3.3.2.9 > 578.4 psig(c)

SR 3.3.2.10 (Unit 2)

(2) Negative Rate - 3 (g)(i) 3 per steam line D SR 3.3.2.1 < 178.7 psi(h)

High SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.10 (continued)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-11, unless the Function is blocked.

(c) Time constants used in the lead/lag controller are T1 > 10 seconds and T2 < 5 seconds.

(g) Below the P-11 (Pressurizer Pressure) Interlock; however, may be blocked below P-1I when safety injection on steam line pressure-low is not blocked.

(h) Time constant utilized in the rate/lag controller is _>50 seconds. /

(i) Except when all MSIVs and their associated upstream drip pot isolation valves are closed and deactivated.

COMANCHE PEAK - UNITS 1 AND 2 3.3-30 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 4 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

5. Turbine Trip and Feedwater Isolation

a. Automatic Actuation 1,20) 2 trains H SR 3.32.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

b. SG Water Level -- 1,220) 3 per SG(p) I SR 3.3.2.1 _<84.5% of narrow High High (P-14) SR 3.3.2.5 range span SR 3.3.2.9 (Unit 1) (q)(r)

SR 3.3.2.10 <82.0% of narrow range span (Unit 2) (q)(r)

c. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

(continued)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(j) Except when all MFIVs and associated bypass valves are closed and de-activated or isolated by a closed manual valve.

(p) A channel selected for use as an input to the SG water level controller must be declared inoperable.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

COMANCHE PEAK - UNITS 1 AND 2 3.3-31 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 5 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

6. Auxiliary Feedwater

a. Automatic Actuation 1, 2, 3 2 trains G SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays (Solid State SR 3.3.2.6 Protection System)

b. Not Used.

c. SG Water Level 1,2, 3 4 per SG D SR 3.3.2.1 _37.5% of narrow Low-Low SR 3.3.2.5 range span SR 3.3.2.9 (Unit 1) (q)(r)

SR 3.3.2.10 _>34.9% of narrow range span (Unit 2) (q)(r)

d. Safety Injection Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

e. Loss of Offsite 1, 2, 3 1 per train F SR 3.3.2.7 NA Power SR 3.3.2.9 SR 3.3.2.10

f. Not Used.

g. Trip of all Main 1, 2 2 per AFW J SR 3.3.2.8 NA Feedwater Pumps pump

h. Not Used.

(continued)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

(q) If the as-found channel setpoint is conservative with respect to the Allowable Value but outside its predefined 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.

(r) The instrument channel setpoint shall be reset to a value that is within the as-left tolerance of the Nominal Trip Setpoint, or a value that is more conservative than the Trip Setpoint; otherwise, the channel shall be declared inoperable. The Nominal Trip Setpoint, the methodology used to determine the as-found tolerance and the methodology used to determine the as-left tolerance shall be specified in the Technical Specification Bases.

COMANCHE PEAK - UNITS 1 AND 2 3.3-32 Amendment No.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 6 of 6)

Engineered Safety Feature Actuation System Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS CONDITIONS REQUIREMENTS VALUE(a)

7. Automatic Switchover to Containment Sump

a. Automatic Actuation 1, 2, 3, 4 2 trains C SR 3.3.2.2 NA Logic and Actuation SR 3.3.2.4 Relays SR 3.3.2.6

b. Refueling Water 1,2,3,4 4 K SR 3.3.2.1 >31.9%

Storage Tank SR 3.3.2.5 instrument span (RWST) Level - Low SR 3.3.2.9 Low SR 3.3.2.10 Coincident with Refer to Function 1 (Safety Injection) for all initiation functions and requirements.

Safety Injection

8. ESFAS Interlocks

a. Reactor Trip, P-4 1,2,3 1 per train, 2 F SR 3.3.2.11 NA trains

b. Pressurizer 1,2, 3 3 L SR 3.3.2.5 <1975.2 psig Pressure, P-11 SR 3.3.2.9 (Unit 1)

<1976.4 psig (Unit 2)

(a) The Allowable Value defines the limiting safety system except for functions 5b and 6c (the Nominal Trip Setpoint defines the limiting safety system setting for these Trip Functions). See the Bases for the Nominal Trip Setpoints.

COMANCHE PEAK - UNITS 1 AND 2 3.3-33 Amendment No.

PAM Instrumentation 3.3.3 3.3 INSTRUMENTATION 3.3.3 Post Accident Monitoring (PAM) Instrumentation LCO 3.3.3 The PAM instrumentation for each Function in Table 3.3.3-1 shall be OPERABLE.

APPLICABILITY: MODES 1,2 and 3 ACTIONS

NOTE----

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with A.1 Restore required channel to 30 days one required channel OPERABLE status.

inoperable.

B. Required Action and B.1 Initiate action in accordance with Immediately associated Completion Specification 5.6.8.

Time of Condition A not met.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-34 Amendment No.

PAM Instrumentation 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more Functions C.1 Restore one channel to OPERABLE 7 days with two required status.

channels inoperable.

OR One required Thot channel and one required Core Exit Temperature channel inoperable.

OR One required Tcold channel and one required Steam Line Pressure channel for the associated loop inoperable.

D. Required Action and D.1 Enter the Condition referenced in Immediately associated Completion Table 3.3.3-1 for the channel.

Time of Condition C not met.

E. As required by Required E.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Action D.1 and referenced in Table 3.3.3-1. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months F. As required by Required F.1 Initiate action in accordance with Immediately Action D.1 and referenced Specification 5.6.8.

in Table 3.3.3-1.

COMANCHE PEAK - UNITS 1 AND 2 3.3-35 Amendment No.

PAM Instrumentation 3.3.3 SURVEILLANCE REQUIREMENTS

ILJ r--------------------------------------------------------------

SR 3.3.3.1 and SR 3.3.3.3 apply to each PAM instrumentation Function in Table 3.3.3-1.

SURVEILLANCE FREQUENCY SR 3.3.3.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.3.2 Deleted SR 3.3.3.3 Perform CHANNEL CALIBRATION. 18 months COMANCHE PEAK - UNITS 1 AND 2 3.3-36 Amendment No.

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CONDITION REFERENCED FROM CONDITION REFERENCED FROM FUNCTION REQUIRED CHANNELE3 REQUIRED ACTION E.1

1. Refueling Water Storage Tank Level 2 E

2. Subcooling Monitors 2 E

3. Reactor Coolant System (RCS) Hot Leg 1 per loop E Temperature (Wide Range) (That)

4. RCS Cold Leg Temperature (Wide Range) 1 per loop E (Tco.d)

5. RCS Pressure (Wide Range) 2 E

6. Reactor Vessel Water Level 2 (a) F

7. Containment Sump Water Level (Wide Range) 2 E

8. Containment Pressure (Intermediate Range) 2 E

9. Steam Line Pressure 2 per steam line E

10. Containment Area Radiation (High Range) 2 F

11. Deleted

12. Pressurizer Water Level 2 E

13. Steam Generator Water Level (Narrow Range) 2 per steam generator E

14. Condensate Storage Tank Level 2 E

15. Core Exit Temperature - Quadrant 1 2 (c) E

16. Core Exit Temperature - Quadrant 2 2 (c) E

17. Core Exit Temperature - Quadrant 3 2 (c) E

18. Core Exit Temperature - Quadrant 4 2 (c) E

19. Auxiliary Feedwater Flow

a. AFW Flow 2 per steam generator E OR

b. AFW Flow and Steam Generator Water 1 each per steam E Level (Wide Range) generator (a) A channel is eight sensors in a probe. A channel is OPERABLE if four or more sensors, one or more in the upper section and three or more in the lower section, are OPERABLE.

(b) Deleted (c) A channel consists of two core exit thermocouples (CETs).

COMANCHE PEAK - UNITS 1 AND 2 3.3-37 Amendment No.

Remote Shutdown System 3.3.4 3.3 INSTRUMENTATION 3.3.4 Remote Shutdown System LCO 3.3.4 The Remote Shutdown System Functions in Table 3.3.4-1 and the required hot shutdown panel (HSP) controls shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

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

Separate Condition entry is allowed for each Function and required HSP control.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Restore required Function and 30 days Functions inoperable, required HSP controls to OPERABLE status.

OR One or more required HSP controls inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.3-38 Amendment No.

Remote Shutdown System 3.3.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.4.1 Perform CHANNEL CHECK for each required 31 days instrumentation channel that is normally energized.

SR 3.3.4.2 Verify each required HSP power and control circuit and 18 months transfer switch is capable of performing the intended function.

SR 3.3.4.3 -- -------------------- NOTE ------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION foreach required 18 months instrumentation channel.

COMANCHE PEAK - UNITS 1 AND 2 3.3-39 Amendment No.

Remote Shutdown System 3.3.4 Table 3.3.4-1 (page 1 of.1)

Remote Shutdown System Functions FUNCTION REQUIRED CHANNELS

1. Neutron Flux Monitors 1

2. Pressurizer Pressure 1

3. RCS Hot Leg Temperature 1 per loop

4. RCS Cold Leg Temperature 1 per loop

5. Condensate Storage Tank Level 1

6. SG Pressure 1 per SG

7. SG Level 1 per SG

8. AFW Flow 1 per SG

9. Pressurizer Level 1 10.Charging Pump to CVCS Charging and RCP 1 Seals Flow Indication COMANCHE PEAK - UNITS 1 AND 2 3.3-40 Amendment No.

LOP DG Start Instrumentation 3.3.5 3.3 INSTRUMENTATION 3.3.5 Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation LCO 3.3.5 The Loss of Power Diesel Generator Start Instrumentation for each Function in Table 3.3.5-1 shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ki*! f*,"1-I'JL r II--I~-------------------------------------------------

Not applicable for 6.9 kV Preferred Offsite Source Undervoltage function when associated source breaker is open.

ACTIONS

NOTE-Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. --------- NOTE------

Not applicable to Automatic Actuation Logic and Actuation Relays Function One or more Functions with A.1 Place channel in trip. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months one channel per bus inoperable.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-41 Amendment No.

LOP DG Start Instrumentation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two channels per bus for B.1 Restore one channel per bus to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the Preferred offsite source OPERABLE status.

bus undervoltage function inoperable. OR B.2.1 Declare the Preferred offsite source 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable.

AND B.2.2 Open associated Preferred offsite 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months source bus breaker.

C. Two channels per bus for C.1 Restore one channel per bus to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the Alternate offsite source OPERABLE status.

bus undervoltage function inoperable. OR C.2.1 Declare the Alternate offsite source 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable.

AND C.2.2 Open associated Alternate offsite 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months source bus breaker.

D. Two channels per bus for D.1 Restore one channel per bus to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months the 6.9 kV bus loss of OPERABLE status.

voltage function inoperable.

OR D.2 Declare the affected A.C. emergency 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months buses inoperable.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-42 Amendment No.

LOP DG Start Instrumentation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Two channels per bus for E.1 Restore one channel per bus to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months one or more degraded OPERABLE status.

voltage or low grid undervoltage function OR inoperable E.2.1 Declare both offsite power source 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months buses inoperable.

AND E.2.2 Open offsite power source 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months breakers to the associated buses.

F. One or more Automatic F.1 Restore train(s) to OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Actuation Logic and status.

Actuation Relays trains inoperable.

G. Required Action and G.1 Enter applicable Condition(s) and Immediately associated Completion Required Action(s) for the associated Time not met. DG made inoperable by LOP DG start instrumentation.

COMANCHE PEAK - UNITS 1 AND 2 3.3-43 Amendment No.

LOP DG Start Instrumentation 3.3.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.5.1 Perform ACTUATION LOGIC TEST. Prior to entering MODE 4 when in MODE 5 for _>72 hours and if not performed in previous 92 days SR 3.3.5.2 -- -------------------- NOTE ------------------

-Setpoint verification is not applicable.

Perform TADOT. Prior to entering MODE 4 when in MODE 5 for _>72 hours and if not performed in previous 92 days SR 3.3.5.3 Perform CHANNEL CALIBRATION. 18 months SR 3.3.5.4 Verify LOP DG start ESF RESPONSE TIMES are within 18 months on a limits. STAGGERED TEST BASIS COMANCHE PEAK - UNITS 1 AND 2 3.3-44 Amendment No.

LOP DG Start Instrumentation 3.3.5 Table 3.3.5-1 (page 1 of 1)

Loss of Power (LOP) Diesel Generator (DG) Start Instrumentation REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CHANNELS REQUIREMENTS VALUE

1. Automatic Actuation Logic and 2 trains 3.3.5.1 NA Actuation Relays

2. Preferred offsite source bus 2 per bus 3.3.5.2 <5580 V and undervoltage 3.3.5.3 _>5040 V

3. Alternate offsite source bus 2 per bus 3.3.5.2 5580 V and undervoltage 3.3.5.3 > 5040 V

4. 6.9 kv Class 1E bus 2 per bus 3.3.5.2 <2115V undervoltage 3.3.5.3 3.3.5.4

5. 6.9 kv Class 1 E bus degraded 2 per bus 3.3.5.2 _ 6024 V voltage 3.3.5.3 3.3.5.4

6. 480 V Class 1E bus low grid 2 per bus 3.3.5.2 >439 V undervoltage 3.3.5.3 3.3.5.4

7. 480 V Class 1E bus degraded 2 per bus 3.3.5.2 >439 V voltage 3.3.5.3 3.3.5.4 COMANCHE PEAK - UNITS 1 AND 2 3.3-45 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 3.3 INSTRUMENTATION 3.3.6 Containment Ventilation Isolation Instrumentation LCO 3.3.6 The Containment Ventilation Isolation instrumentation for each Function in Table 3.3.6-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.6-1 ACTIONS kIr~tr I*%I- lit -------------------------------------------------------------

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One radiation monitoring A.1 Restore the affected channel to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months channel inoperable. OPERABLE status.

COMANCHE PEAK - UNITS 1 AND 2 3.3-46 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. -------- NOTE --------------------NOTE ------------

Only applicable in MODE For Required Action and associated 1,2, 3, or 4. Completion Time of Condition A not met,

the containment pressure relief valves may be opened in compliance with the gaseous effluent monitoring instrumentation requirements in Part I of the ODCM.

One or more Automatic B.1 Enter applicable Conditions and Immediately Actuation Logic and Required Actions of LCO 3.6.3, Actuation Relays trains "Containment Isolation Valves," for inoperable, containment ventilation isolation OR valves made inoperable by isolation instrumentation.

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

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-47 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------- NOTE ------- ------------- NOTE ------------------------

Only applicable during The containment pressure relief valves CORE ALTERATIONS or may be opened in compliance with the movement of irradiated fuel gaseous effluent monitoring assemblies within instrumentation requirements in Part I of containment, the ODCM.

Required Action and C.1 Place and maintain containment Immediately associated Completion ventilation valves in closed position.

Time for Condition A not met. OR J,

C.2 Enter applicable Conditions and Immediately Required Actions of LCO 3.9A, "Containment Penetrations," for containment ventilation isolation valves made inoperable by isolation instrumentation.

SURVEILLANCE REQUIREMENTS

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

7 Refer to Table 3.3.6-1 to determine which SRs apply for each Containment Ventilation Isolation Function.

SURVEILLANCE FREQUENCY SR 3.3.6.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-48 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.6.2 Perform ACTUATION LOGIC TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.6.3 Perform MASTER RELAY TEST. 92 days on a STAGGERED TEST BASIS SR 3.3.6.4 Perform COT. 92 days SR 3.3.6.5 Perform SLAVE RELAY TEST. 92 days OR 18 months for Westinghouse type AR relays with AC coils SR 3.3.6.6 Not Used.

SR 3.3.6.7 Perform CHANNEL CALIBRATION. 18 months COMANCHE PEAK - UNITS 1 AND 2 3.3-49 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)

Containment Ventilation Isolation Instrumentation APPLICABLE MODES OR OTHERSPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT

1. Manual Initiation 1, 2, 3, 4 Refer to LCO 3.3.2 "ESFAS Instrumentation,"

Functions 2.a and 3.a.1, respectively for all initiation functions and requirements.

2. Automatic Actuation 1, 2, 3, 4 2 trains SR 3.3.6.2 NA Logic and Actuation SR 3.3.6.3 Relays SR 3.3.6.5

3. Containment Radiation

a. Gaseous 1, 2, 3, 4, (b), (c) 1 SR 3.3.6.1 (a)

SR 3.3.6.4 SR 3.3.6.7

4. Containment Isolation - Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 3.a, for all Phase A initiation functions and requirements.

(a) Must satisfy Gaseous Effluent Dose Rate Requirements in Part I of the ODCM.

(b) During CORE ALTERATIONS.

(c) During movement of irradiated fuel assemblies within containment.

COMANCHE PEAK - UNITS 1 AND 2 3.3-50 Amendment No.

CREFS Actuation Instrumentation 3:3.7 3.3 INSTRUMENTATION 3.3.7 Control Room Emergency Filtration System (CREFS) Actuation Instrumentation LCO 3.3.7 The CREFS actuation instrumentation for each Function in Table 3.3.7-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.7-1 ACTIONS Ik IV-r I'J-- !

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more Functions with A.1 Place the affected CREFS train(s) in 7 days one channel or train emergency recirculation mode.

inoperable.

OR A.2 ----------- NOTE ---------------------

Applicable only to Functions 3a and 3b.

Secure the Control Room makeup air 7 days supply fan from the affected air intake.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-51 Amendment No.

CREFS Actuation Instrumentation 3.3.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more Functions with B.1.1 Place one CREFS train in Immediately two channels or two trains emergency recirculation mode.

inoperable.

AND B.1.2 Enter applicable Conditions and Immediately Required Actions for one CREFS train made inoperable by inoperable CREFS actuation instrumentation OR B.2 ---------- NOTE ------------------

Applicable only to Functions 3a and 3b.

Secure the Control Room makeup air Immediately supply fan from the affected air intake.

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 for Condition A or B AND not met in MODE 1, 2, 3, or 4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Suspend CORE ALTERATIONS. immediately associated Completion.

Time for Condition A or B AND not met in MODE 5 or 6, or during movement of D.2 Suspend movement of irradiated fuel Immediately irradiated fuel assemblies, assemblies.

V COMANCHE PEAK - UNITS 1 AND 2 3.3-52 Amendment No.

CREFS Actuation Instrumentation 3.3.7 SURVEILLANCE REQUIREMENTS

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

Refer to Table 3.3.7-1 to determine which SRs apply for each CREFS Actuation Function.

SURVEILLANCE FREQUENCY SR 3.3.7.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.3.7.2 Perform COT. 92 days SR 3.3.7.3 Not Used.

SR 3.3.7.4 Not Used.

SR 3.3.7.5 Not Used.

SR 3.3.7.6 ----------------------- NOTE ------------------

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.7.7 Perform CHANNEL CALIBRATION. 18 mdnths COMANCHE PEAK - UNITS 1 AND 2 3.3-53 Amendment No'.

CREFS Actuation Instrumentation 3.3.7 Table 3.3.7-1 (page 1 of 1)

CREFS Actuation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT

1. Manual Initiation 1, 2, 3, 4, 5, and 6, (a) 2 trains SR 3.3.7.6 NA

2. Automatic Actuation Logic 1, 2, 3, 4, 5, and 6, (a) 2 trains SR 3.3.7.2 NA and Actuation Relays

3. Control Room Radiation

a. Control Room Air North 1,2,3,4,5, and 6, (a) 2 SR 3.3.7.1 1.4 x 10-4 Intake SR 3.3.7.2 pCi/ml SR 3.3.7.7

b. Control Room Air 1, 2, 3, 4, 5, and 6, (a) 2 SR 3.3.7.1 1.4 x 10-4 South Intake SR 3.3.7.2 pCi/ml SR 3.3.7.7

4. Safety Injection Refer to LCO 3.3.2, "ESFAS Instrumentation," Function 1, for all initiation functions and requirements.

(a) During movement of irradiated fuel assemblies.

COMANCHE PEAK - UNITS 1 AND 2 3.3-54 Amendment No.

RCS Pressure, Temperature, and Flow DNB Limits 3.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits LCO 3.4.1 RCS DNB parameters for pressurizer pressure, RCS average temperature, and RCS total flow rate shall be within the limits specified below:

a. Pressurizer pressure _ the limit specified in the COLR;

b. RCS average temperature < the limit specified in the COLR; and

c. RCS total flow rate _>389,700 gpm and >_the limit specified in the COLR.

APPLICABILITY: MODE 1

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

Pressurizer pressure limit does not apply during:

a. THERMAL POWER ramp > 5% RTP per minute; or

b. THERMAL POWER step > 10% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more RCS DNB A.1 Restore RCS DNB parameter(s) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months parameters not within limits, within limit.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-1 Amendment No.

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

CONDITION REQUIRED ACTION COMPLETION TIME B. -------- NOTE-------

Only applicable prior to exceeding 85% RTP after a refueling outage.

Measured RCS Flow not B.1 Maintain THERMAL POWER less Immediately within limits, than 85% RTP.

C. Required Action and C.1 Be in MODE 2. 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 3.4.1.1 Verify pressurizer pressure is > the limit specified in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COLR.

SR 3.4.1.2 Verify RCS average temperature is < the limit specified in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months the COLR.

SR 3.4.1.3 Verify RCS total flow rate is _>389,700 and _ the limit 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months specified in the COLR.

SR 3.4.1.4 -- -------------------- NOTE ------------------

Not required to be performed until after exceeding 85%

RTP after each refueling outage.

Verify by precision heat balance that RCS total flow rate is 18 months

> 389,700 and > the limit specified in the COLR.

COMANCHE PEAK - UNITS 1 AND 2 3.4-2 Amendment No.

RCS Minimum Temperature for Criticality 3.4.2 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each operating RCS loop average temperature (Tavg) shall be >_551'F.

APPLICABILITY: MODE 1, MODE 2 with keff > 1.0 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Tavg in one or more A.1 Be in MODE 2 with keff < 1.0. 30 minutes operating RCS loops not within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.2.1 Verify RCS Tavg in each operating loop > 551 OF. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.4-3 Amendment No.

RCS PIT Limits 3.4.3 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.3 RCS Pressure and Temperature (PIT) Limits LCO 3.4.3 RCS pressure, RCS temperature, and RCS heatup and cooldown rates shall be maintained within the limits specified in the PTLR.

APPLICABILITY: At all times ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -------- NOTE -------------

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

Requirements of LCO not A.1 Restore parameter(s) to within limits. 30 minutes met in MODE 1, 2, 3, or 4.

AND A.2 Determine RCS is acceptable for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months continued operation.

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

B.2 Be in MODE 5 with RCS pressure < 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months 500 psig.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 .3.4-4 Amendment No.

RCS P/T Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------- NOTE-------

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

Requirements of LCO not C.1 Initiate action to restore parameter(s) Immediately met any time in other than to within limits.

MODE 1, 2, 3, or 4.

AND C.2 Determine RCS is acceptable for Prior to entering continued operation. MODE 4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.3.1 ------------------------ NOTE ------------------

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

Verify RCS pressure, RCS temperature, and RCS heatup 30 minutes and cooldown rates are within the limits specified in the PTLR.

COMANCHE PEAK - UNITS 1 AND 2 3.4-5 Amendment No.

RCS Loops -- MODES 1 and 2 3.4.4 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.4 RCS Loops -- MODES 1 and 2 LCO 3.4.4 Four RCS loops shall be OPERABLE and in operation.

APPLICABILITY: MODES 1 and 2

ACTIONS, CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of LCO not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.4.1 Verify each RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.4-6 Amendment No.

RCS Loops -- MODE 3 3.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 RCS Loops -- MODE 3 LCO 3.4.5 Two RCS loops shall be OPERABLE, and either:

a. Two RCS loops shall be in operation when the Rod Control System is capable of rod withdrawal; or

b. One RCS loop shall be in operation when the Rod Control System is not capable of rod withdrawal.

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

All reactor coolant pumps may be removed from operation for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

APPLICABILITY: MODE 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required RCS loop A.1 Restore required RCS loop to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion Time of Condition A not met.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-7 Amendment No.

RCS Loops - MODE 3 3.4.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One required RCS loop not C.1 Restore required RCS loop to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in operation, with Rod operation.

Control System capable of rod withdrawal. OR C.2 Place the Rod Control System in a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months condition incapable of rod withdrawal.

D. Four RCS loops inoperable. D.1 Place the Rod Control System in a Immediately condition incapable of rod OR withdrawal.

No RCS loop in operation. AND D.2 Suspend operations that would Immediately cause introduction of coolant into the RCS with boron concentration less than required to meet SDM of LCO 3.1.1.

AND D.3 Initiate action to restore one RCS Immediately loop to OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.5.1 Verify required RCS loops are in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-8 Amendment No.

RCS Loops - MODE 3 3.4.5 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.5.2 Verify steam generator secondary side water levels are - 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 38% (Unit 1) and Ž!10% (Unit 2) for required RCS loops.

SR 3.4.5.3 Verify correct breaker alignment and indicated power are 7 days available to the required pump that is not in operation.

COMANCHE PEAK - UNITS 1 AND 2 3.4-9 Amendment No.

RCS Loops -- MODE 4 3.4.6 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.6 RCS Loops -- MODE 4 LCO 3.4.6 Two loops consisting of any combination of RCS loops and residual heat removal (RHR) loops shall be OPERABLE, and one loop shall be in operation.

I'jj r'.5 ----------------------------------------------

1. All reactor coolant pumps (RCPs) and RHR pumps may be removed from operation for _<1 hour per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature < 350'F unless the secondary side water temperature of each steam generator (SG) is < 50 0 F above each of the RCS cold leg temperatures.

APPLICABILITY: MODE 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required loop A.1 Initiate action to restore a second Immediately inoperable. loop to OPERABLE status.

AND A.2 ---------- NOTE ------------

Only required if one RHR loop is OPERABLE Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months f (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-10 Amendment No.

RCS Loops -- MODE 4 3.4.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Two required loops B.1 Suspend operations that would Immediately inoperable, cause introduction of coolant into the RCS with boron concentration less OR than required to meet SDM of LCO 3.1.1.

No RCS or RHR loop in operation. AND B.2 Initiate action to restore one loop to Immediately OPERABLE status and operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.6.1 Verify one RHR or RCS loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.6.2 Verify SG secondary side water levels are Ž38% (Unit 1) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and Ž!10% (Unit 2) for required RCS loops.

SR 3.4.6.3 Verify correct breaker alignment and indicated power are 7 days available to the required pump that is not in operation.

COMANCHE PEAK - UNITS 1 AND 2 3.4-11 Amendment No.

RCS Loops -- MODE 5, Loops Filled 3.4.7 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.7 RCS Loops -- MODE 5, Loops Filled LCO 3.4.7 One residual heat removal (RHR) loop shall be OPERABLE and in operation, and either:

a. One additional RHR loop shall be OPERABLE; or

b. The secondary side water level of at least two steam generators (SGs) shall be >38% (Unit 1) and >10% (Unit 2).

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

1. The RHR pump of the loop in operation may be removed from operation for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period provided:

a. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

b. Core outlet temperature is maintained at least 10°F below saturation temperature.

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

3. No reactor coolant pump shall be started with any RCS cold leg temperature < 350°F unless the secondary side water temperature of each SG is < 50°F above each of the RCS cold leg temperatures.

4. All RHR loops may be removed from operation during planned heatup to MODE 4 when at least one RCS loop is in operation.

APPLICABILITY: MODE 5 with RCS loops filled COMANCHE PEAK - UNITS 1 AND 2 3.4-12 Amendment No.

RCS Loops -- MODE 5, Loops Filled 3.4.7 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. -One RHR loop inoperable. A.1 Initiate action to restore a second Immediately RHR loop to OPERABLE status.

AND OR Required SGs secondary side water levels not within A.2 Initiate action to restore required SG Immediately limits, secondary side water levels to within limits.

B. Required RHR loops B.1 Suspend operations that would Immediately inoperable, cause introduction of coolant into the RCS with boron concentration less OR than required to meet SDM of LCO 3.1.1.

No RHR loop in operation.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.7.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.7.2 Verify SG secondary side water level is Ž38% (Unit 1) and 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months A10% (Unit 2) in required SGs.

SR 3.4.7.3 Verify correct breaker alignment and indicated power are 7 days available to the required RHR pump that is not in operation.

COMANCHE PEAK - UNITS 1 AND 2 3.4-13 Amendment No.

RCS Loops -- MODE 5, Loops Not Filled 3.4.8 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.8 RCS Loops -- MODE 5, Loops Not Filled LCO 3.4.8 Two residual heat removal (RHR) loops shall be OPERABLE and one RHR loop shall be in operation.

-NOTES

1. All RHR pumps may be removed from operation for *_1 hour provided:

a. The core outlet temperature is maintained at least 10'F below saturation temperature.

b. No operations are permitted that would cause introduction of coolant into the RCS with boron concentration less than required to meet the SDM of LCO 3.1.1; and

c. No draining operations to further reduce the RCS water volume are permitted.

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

APPLICABILITY: MODE 5 with RCS loops not filled

NOTE----

While this LCO is not met, entry into MODE 5, Loops Not Filled from MODE 5, Loops filled is not permitted.

COMANCHE PEAK - UNITS 1 AND 2 3.4-14 Amendment No.

RCS Loops -- MODE 5, Loops Not Filled 3.4.8 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One RHR loop inoperable. A.1 Initiate action to restore RHR loop to Immediately OPERABLE status.

B. Required RHR loops B.1 Suspend operations that would Immediately inoperable, cause introduction of coolant into the RCS with boron concentration less OR than required to meet SDM of LCO 3.1.1.

No RHR loop in operation.

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.8.1 Verify one RHR loop is in operation. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.8.2 Verify correct breaker alignment and indicated power are 7 days available to the required RHR pump that is not in operation.

COMANCHE PEAK- UNITS 1 AND 2 3.4-15 Amendment No.

Pressurizer 3.4.9 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.9 Pressurizer LCO 3.4.9 The pressurizer shall be OPERABLE with:

a. Pressurizer water level < 92%; and

b. Two groups of pressurizer heaters OPERABLE with the capacity of each group Ž 150 kW.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Pressurizer water level not A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months within limit.

AND A.2 Fully insert all rods. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND A.3 Place Rod Control System in a 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months condition incapable of rod withdrawal.

AND A.4 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months B. One required group of B.1 Restore required group of pressurizer 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months pressurizer heaters heaters to OPERABLE status.

inoperable.

(continued)

COMANCHE PEAK- UNITS 1 AND 2 3.4-16 Amendment No.

Pressurizer 3.4.9 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 of Condition B not AND met.

C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.9.1 Verify pressurizer water level is < 92%. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.4.9.2 Verify capacity of each required group of pressurizer 18 months heaters is _>150 kW.

COMANCHE PEAK - UNITS 1 AND 2 3.4-17 Amendment No.

Pressurizer Safety Valves 3.4.10 3.4 REACTOR COOLANT SYSTEM (RCS),

3.4.10 Pressurizer Safety Valves LCO 3.4.10 Three pressurizer safety valves shall be OPERABLE with lift settings _>2410 psig and < 2485 psig.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures > 320°F

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

The lift settings are not required to be within the LCO limits during MODES 3 and 4 for the purpose of setting the pressurizer safety valves under ambient (hot) conditions. This exception is allowed for 54 hours6.25e-4 days 0.015 hours 8.928571e-5 weeks 2.0547e-5 months following entry into MODE 3 provided a preliminary cold setting was made prior to heatup.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One pressurizer safety A.1 Restore valve to OPERABLE status. 15 minutes valve inoperable.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND OR B.2 Be in MODE 4 with any RCS cold leg 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months temperatures < 320°F.

Two or more pressurizer safety valves inoperable.

COMANCHE PEAK - UNITS 1 AND 2 3.4-18 Amendment No.

Pressurizer Safety Valves 3.4.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.10.1 Verify each pressurizer safety valve is OPERABLE in In accordance with accordance with the Inservice Testing Program. Following the Inservice testing, lift settings shall be within +/- 1%. Testing Program COMANCHE PEAK - UNITS 1 AND 2 3.4-19 Amendment No.

Pressurizer PORVs 3.4.11 3.4 REACTOR'COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORVs)

LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

NOTI= -------------------------------------------------------------

Separate Condition entry is allowed for each PORV CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain power to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable and capable of associated block valve.

being manually cycled.

B. One PORV inoperable and B.1 Close associated block valve. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not capable of being manually cycled. AND B.2 Remove power from associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months block valve.

AND B.3 Restore PORV to OPERABLE status. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-20 Amendment No.

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One block valve inoperable. ------------- NOTE------------

Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2.

C.1 Place associated PORV in manual 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control.

AND C.2 Restore block valve to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

D. Required Action and D.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 A, B, or C AND not met.

D.2 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two PORVs inoperable and E.1 Close associated block valves. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months not capable of being manually cycled. AND E.2 Remove power from associated 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months block valves.

AND E.3 Be in MODE 3 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months AND E.4 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-21 Amendment No.

Pressurizer PORVs 3.4.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. More than one block valve ------------- NOTE------------

inoperable, Required Actions do not apply when block valve is inoperable solely as a result of complying with Required Actions B.2 or E.2.

F.1 Place associated PORVs in manual 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months control' AND F.2 Restore one block valve to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months OPERABLE status G. Required.Action and G.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 F not AND met.

G.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 ---------------------- NOTES -----------------

1. Not required to be performed with block valve closed in accordance with the Required Action of this LCO.

2. Not required to be performed prior to entry into MODE 3.

Perform a complete cycle of each block valve. 92 days (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-22 Amendment No.

Pressurizer PORVs 3.4.11 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.11.2 -- -------------------- NOTE ------------------

Not required to be performed prior to entry into MODE 3.

Perform a complete cycle of each PORV. 18 months COMANCHE PEAK- UNITS 1 AND 2 3.4-23 Amendment No.

LTOP System 3.4.12 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Low Temperature Overpressure Protection (LTOP) System LCO 3.4.12 An LTOP System shall be OPERABLE with a maximum of zero safety injection pumps and two charging pumps capable of injecting into the RCS and the accumulators isolated and one of the following pressure relief capabilities:

a. Two power operated relief valves (PORVs) with lift settings within the limits specified in the PTLR, or

b. Two residual heat removal (RHR) suction relief valves with setpoints _

436.5 psig and < 463.5 psig, or

c. One PORV with a lift setting within the limits specified in the PTLR and one RHR suction relief valve with a setpoint > 436.5 psig and

463.5 psig, or

d. The RCS depressurized and an RCS vent of _> 2.98 square inches.

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

Accumulator may be unisolated when accumulator pressure is less than the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

APPLICABILITY: MODE 4, MODE 5, MODE 6 when the reactor vessel head is on k I #"*-I-*

-- ----------------------------- IVLJ It- ---------------------------------

The LCO is not applicable when all RCS cold leg temperatures are > 320°F and the following conditions are met:

a. At least one reactor coolant pump is in operation, and

b. Pressurizer level is < 92%, and

c. The plant heatup rate is limited to 60°F in any one hour period.

COMANCHE PEAK - UNITS 1 AND 2 3.4-24 Amendment No.

LTOP System 3.4.12 ACTIONS

NOTE--

LCO 3.0.4.b is not applicable when entering MODE 4.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safety A.1 Initiate action to verify a maximum of Immediately injection pumps capable of zero safety injection pumps are injecting into the RCS. capable of injecting into the RCS.

B. Three charging pumps B.1 Initiate action to verify a maximum of Immediately capable of injecting into the two charging pumps are capable of RCS. injecting into the RCS.

C. An accumulator not isolated C.1 Isolate affected accumulator. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months when the accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-25 Amendment No.

LTOP System 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Increase RCS cold leg temperature 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion to > 320 0 F.

Time of Condition C not met. AND Verify at least one reactor coolant pump is in operation.

AND Pressurizer level is < 92%.

AND The plant heatup rate is limited to 60°F in any one hour period.

OR D.2 Increase RCS average temperature 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months to > 350 0 F.

OR D.3 Depressurize affected accumulator to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months less than the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.

E. One required RCS relief E.1 Restore required RCS relief valve to 7 days valve inoperable in OPERABLE status.

MODE 4.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-26 Amendment No.

LTOP System 3.4.12 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. One required RCS relief F.1 Restore required RCS relief valve to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months valve inoperable in OPERABLE status.

MODE 5 or 6.

G. Two required RCS relief G.1 Depressurize RCS and establish 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months valves inoperable. RCS vent of _ 2.98 square inches.

OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met.

OR LTOP System inoperable for any reason other than Condition A, B, C, D, E, or F.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify a maximum of zero safety injection pumps are 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months capable of injecting into the RCS.

SR 3.4.12.2 Verify a maximum of two charging pumps are capable of 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months injecting into the RCS.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-27 Amendment No.

LTOP System 3.4.12 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.12.3 Verify each accumulator is isolated when accumulator 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months pressure is greater than or equal to the maximum RCS pressure for the existing RCS cold leg temperature allowed by the P/T limit curves provided in the PTLR.

SR 3.4.12.4 Verify RHR suction isolation valves are open for each 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months required RHR suction relief valve.

SR 3.4.12.5 Verify required RCS vent _ 2.98 square inches open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months for unlocked open vent valve(s)

AND 31 days for locked open vent valve(s)

SR 3.4.12.6 Verify PORV block valve is open for each required PORV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.12.7 Not Used.

SR 3.4.12.8 ---------------------- NOTE -----------------

Not required to be performed until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after decreasing any RCS cold leg temperature to < 3500F.

Perform a COT on each required PORV, excluding 31 days actuation.

SR 3.4.12.9 Perform CHANNEL CALIBRATION for each required 18 months PORV actuation channel.

COMANCHE PEAK - UNITS 1 AND 2 3.4-28 Amendment No.

RCS Operational LEAKAGE 3.4.13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS O.perational LEAKAGE LCO 3.4.13 RCS operational LEAKAGE shall be limited to:

a. No pressure boundary LEAKAGE;

b. 1 gpm unidentified LEAKAGE;

c. 10 gpm identified LEAKAGE; and

d. 150 gallons per day primary to secondary LEAKAGE through any one steam generator (SG).

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RCS operational LEAKAGE A.1 Reduce LEAKAGE to within limits. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months not within limits for reasons other than pressure boundary LEAKAGE or primary to secondary LEAKAGE.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR Pressure boundary LEAKAGE exists.

OR Primary to secondary LEAKAGE not within limits COMANCHE PEAK - UNITS 1 AND 2 3.4-29 Amendment No.

RCS Operational LEAKAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ---------------------- NOTES -----------------

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

2. Not applicable to primary to secondary LEAKAGE.

Verify RCS operational LEAKAGE is within limits by 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months performance of RCS water inventory balance.

SR 3.4.13.2 - -------------------- NOTE ------------------

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

Verify primary to secondary LEAKAGE is *150 gallons per 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months day through any one SG.

COMANCHE PEAK - UNITS 1 AND 2 3.4-30 Amendment No.

RCS PIV Leakage 3.4.14 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage LCO 3.4.14 Leakage from each RCS PIV shall be within limit.

APPLICABILITY: MODES 1, 2, and 3, MODE 4, except valves in the residual heat removal (RHR) flow path when in, or during the transition to or from, the RHR mode of operation ACTIONS 7--------------------------------- NOTES--------------------------------

1. Separate Condition entry is allowed for each flow path.

2. Enter applicable Conditions and Required Actions for systems made inoperable by an inoperable PIV.

COMANCHE PEAK - UNITS 1 AND 2 3.4-31 Amendment No.

RCS PIV Leakage 3.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

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

A. One or more flow paths with leakage from one or Each valve used to satisfy Required more RCS PIVs not within Action A.1 and Required Action A.2 must limit, have been verified to meet SR 3.4.14.1 and be in the reactor coolant pressure boundary or the high pressure portion of the system.

A.1 Isolate the high pressure portion of 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months the affected system from the low pressure portion by use of one closed manual, deactivated automatic, or check valve.

AND A.2.1 Isolate the high pressure portion of 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months the affected system from the low pressure portion by use of a second closed manual, deactivated automatic, or check valve.

OR A.2.2 Restore RCS PIV to within limits. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time for Condition A not AND met.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. RHR System interlock C.1 Isolate the affected penetration by 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months function inoperable, use of one closed manual or deactivated automatic valve.

COMANCHE PEAK - UNITS 1 AND 2 3.4-32 Amendment No.

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.14.1 -------------- NOTES -------------

1. Not required to be performed in MODES 3 and 4.

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

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

Verify leakage from each RCS PIV is equivalent to In accordance with

< 0.5 gpm per nominal inch of valve size up to a maximum the Inservice of 5 gpm at an RCS pressure >_2215 psig and

2255 psig. Testing Program, and 18 months AND Prior to entering MODE 2 whenever the unit has been in MODE 5 for 7 days or more, and if leakage testing has not been performed in the previous 9 months except for valves 8701A, 8701 B, 8702A and 8702B AND Within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months following check valve actuation due to flow through the valve (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-33 Amendment No.

RCS PIV Leakage 3.4.14 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.14.2 Verify RHR System interlock prevents the valves from being 18 months opened with a simulated or actual RCS pressure signal >_

442 psig, except when the valves are open to satisfy LCO 3.4.12.

COMANCHE PEAK - UNITS 1 AND 2 3.4-34 Amendment No.

RCS Leakage Detection Instrumentation 3.4.15 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.15 RCS Leakage Detection Instrumentation LCO 3.4.15 The following RCS leakage detection instrumentation shall be OPERABLE:

a. One Containment Sump Level and Flow Monitoring System;

b. One containment atmosphere particulate radioactivity monitor; and

c. One containment air cooler condensate flow rate monitor or one containment atmosphere radioactivity monitor (gaseous).

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required Containment A.1 ----------- NOTE ----------

Sump Level-and Flow Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after Monitoring System establishment of steady state inoperable. operation.

Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND A.2 Restore Containment Sump Level 30 days and Flow Monitoring System to OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-35 Amendment No.

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required containment B.1.1 Analyze grab samples of the Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere particulate containment atmosphere.

radioactivity monitor inoperable. OR B.1.2 ---------- NOTE ---------

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

Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND B.2 Restore required containment 30 days atmosphere particulate radioactivity monitor to OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-36 Amendment No.

RCS Leakage Detection Instrumentation 3.4.15 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C Required containment C.1.1 Analyzegrab samples of the Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months atmosphere gaseous containment atmosphere.

radioactivity monitor inoperable. OR AND C.1.2 ---------- NOTE ---------

Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after Required containment air establishment of steady state cooler condensate flow rate operation.

monitor inoperable.

Perform SR 3.4.13.1. Once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months AND C.2.1 Restore required containment 30 days atmosphere gaseous radioactivity monitor to OPERABLE status.

OR C.2.2 Restore required containment air 30 days cooler condensate flow rate monitor to OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. All required monitors E.1 Enter LCO 3.0.3. Immediately inoperable.

COMANCHE PEAK - UNITS 1 AND 2 3.4-37 Amendment No.

RCS Leakage Detection Instrumentation 3.4.15 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.15.1 Perform CHANNEL CHECK of the required containment 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months atmosphere particulate and gaseous radioactivity monitors.

SR 3.4.15.2 Perform COT of the required containment atmosphere 92 days particulate and gaseous radioactivity monitors.

SR 3.4.15.3 Perform CHANNEL CALIBRATION of the required 18 months Containment Sump Level and Flow Monitoring System.

SR 3.4.15.4 Perform CHANNEL CALIBRATION of the required 18 months containment atmosphere particulate and gaseous radioactivity monitors.

SR 3.4.15.5 Perform CHANNEL CALIBRATION of the required 18 months containment air cooler condensate flow rate monitor.

COMANCHE PEAK- UNITS 1 AND 2 3.4-38 Amendment No.

RCS Specific Activity 3.4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 RCS DOSE EQUIVALENT 1-131 and DOSE EQUIVALENT XE-133 specific activity shall be within limits.

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

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT 1-131 ------------- NOTE------------

not within limit. LCO 3.0.4.c is applicable.

A.1 Verify DOSE EQUIVALENT 1-131 Once per4 hours

<60 tCi/gm.

AND A.2 Restore DOSE EQUIVALENT 1-131 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months to within limit.

B. DOSE EQUIVALENT XE- B.1 ----------- NOTE -----------

133 not within limit. LCO 3.0.4.c is applicable.

Restore DOSE EQUIVALENT XE- 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months 133 to within limit.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-39 Amendment No.

RCS Specific Activity 3.4.16 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 of Condition A or B AND not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR DOSE EQUIVALENT 1-131

> 60 ICi/gm.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 - -------------------- NOTE ------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT XE-1 33 7 days specific activity < 500 ýtCi/gm (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-40 Amendment No.

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY Ik Irt*'"rr SR 3.4.16.2 -- ------------------------ L t-,I------------------------

Only required to be performed in MODE 1.

Verify reactor coolant DOSE EQUIVALENT 1-131 specific 14 days activity < 0.45 pCi/gm.

AND Between 2 and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after a THERMAL POWER change of Ž> 15%

RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period SR 3.4.16.3 DELETED DELETED COMANCHE PEAK - UNITS 1 AND 2 3.4-41 Amendment No.

SG Tube Integrity 3.4.17 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.17 Steam Generator (SG) Tube Integrity LCO 3.4.17 SG tube integrity shall be maintained.

AND All SG tubes satisfying the tube repair criteria shall be plugged or repaired in accordance with the Steam Generator Program.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS Separate Condition entry is allowed for each SG tube.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more SG tubes A.1 Verify tube integrity of the affected 7 days satisfying the tube repair tube(s) is maintained until the next criteria and not plugged or refueling outage or SG tube repaired in accordance with inspection.

the Steam Generator Program. AND A.2 Plug or repair the affected tube(s) in Prior to entering MODE accordance with the Steam 4 following the next Generator Program. refueling outage or SG tube inspection (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-42 Amendment No.

SG Tube Integrity 3.4.17 ACTIONS (continued)

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SG tube integrity not maintained.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.17.1 Verify SG tube integrity in accordance with the Steam In accordance with Generator Program. the Steam Generator Program SR 3.4.17.2 Verify that each inspected SG tube that satisfies the tube Prior to entering repair criteria is plugged or repaired in accordance witht he MODE 4 following a Steam Generator Program. SG tube inspection COMANCHE PEAK - UNITS 1 AND 2 3.4-43 Amendment No.

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO 3.5.1 Four ECCS accumulators shall be OPERABLE.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS pressure > 1000 psig.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One accumulator A.1 Restore boron concentration to within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable due to boron limits.

concentration not within limits.

B. One accumulator B.1 Restore accumulator to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable for reasons status.

other than Condition A.

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 A or B AND not met.

C.2 Reduce RCS pressure to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 1000

psig.

D. Two or more accumulators D.1 Enter LCO 3.0.3. Immediately inoperable.

COMANCHE PEAK - UNITS 1 AND 2 3.5-1 Amendment No.

Accumulators 3.5.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.1.1 Verify each accumulator isolation valve is fully open. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.5.1.2 Verify borated water volume in each accumulator is _ 6119 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months gallons and < 6597 gallons.

SR 3.5.1.3 Verify nitrogen cover pressure in each accumulator is > 623 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months psig and < 644 psig.

SR 3.5.1.4 Verify boron concentration in each accumulator is > 2300 31 days ppm and < 2600 ppm.

AND NOTE---------

Only required to be performed for affected accumulators Once within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months after each solution volume increase of

>_101 gallons that is not the result of addition from the refueling water storage tank SR 3.5.1.5 Verify power is removed from each accumulator isolation 31 days valve operator when RCS pressure is > 1000 psig.

COMANCHE PEAK - UNITS 1 AND 2 3.5-2 Amendment No.

ECCS -- Operating 3.5.2 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.2 ECCS -- Operating LCO 3.5.2 Two ECCS trains shall be OPERABLE.

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

1. In MODE 3, both safety injection (SI) pump flow paths may be isolated by closing the isolation valves for up to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months to perform pressure isolation valve testing per SR 3.4.14.1.

2. Operation in MODE 3 with ECCS pumps made incapable of injecting, pursuant to LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP) System," is allowed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or until the temperature of all RCS cold legs exceeds 375°F, whichever comes first.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One train inoperable A.1 Restore pump to OPERABLE status. 7 days because of the inoperability of a centrifugal charging pump.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.5-3 Amendment No.

ECCS -- Operating 3.5.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more trains B.1 Restore train(s) to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable for reasons status.

other than one inoperable centrifugal charging pump.

AND At least 100% of the ECCS flow equivalent to a single OPERABLE ECCS train available.

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. AND C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.2.1 Verify the following valves are in the listed position with 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months power to the valve operator removed.

Number Position Function 8802 A&B Closed SI Pump to Hot Legs 8809 A&B Open RHR to Cold Legs 8835 Open SI Pump to Cold Legs 8840 Closed RHR to Hot Legs 8806 Open SI Pump Suction from RWST 8813 Open SI Pump Miniflow Valve (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.5-4 Amendment No.

ECCS -- Operating 3.5.2 SURVEILLANCE REQUIREMENTS (continued)

SR 3.5.2.2 Verify each ECCS manual, power operated, and automatic 31 days valve in the flow path, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.5.2.3 Verify ECCS piping is full of water. Prior to entry into MODE 3 SR 3.5.2.4 Verify each ECCS pump's developed head at the test flow In accordance with point is greater than or equal to the required developed the Inservice head. Testing Program SR 3.5.2.5 Verify each ECCS automatic valve in the flow path that is 18 months not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.5.2.6 Verify each ECCS pump starts automatically on an actual 18 months or simulated actuation signal.

SR 3.5.2.7 Verify, for each ECCS throttle valve listed below, each 18 months mechanical position stop is in the correct position.

Valve Number 8810A 8816A 8822A 8810B 8816B 8822B 8810C 8816C 8822C 8810D 8816D 8822D SR 3.5.2.8 Verify, by visual inspection, each ECCS train containment 18 months sump suction inlet is not restricted by debris and the suction inlet strainers show no evidence of structural distress or abnormal corrosion.

COMANCHE PEAK - UNITS 1 AND 2 3.5-5 Amendment No.

ECCS -- Shutdown 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.3 ECCS -- Shutdown LCO 3.5.3 One ECCS train shall be OPERABLE.

- -- ----------------------------NO -----------------------------------------------

An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECCS mode of operation.

--APPLICABILITY: MODE 4 ACTIONS

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

LCO 3.0.4.b is not applicable to ECCS Centrifugal Pump subsystem.

CONDITION REQUIRED ACTION COMPLETION TIME A. Required ECCS residual A.1 Initiate action to restore required Immediately heat removal (RHR) ECCS RHR subsystem to subsystem inoperable. OPERABLE status.

B. Required ECCS Centrifugal B.1 Restore required ECCS Centrifugal 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months Charging Pump subsystem Charging Pump subsystem to inoperable. OPERABLE status.

/'

C. Required Action and C.1 Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months associated Completion Time of Condition B not met.

COMANCHE PEAK-UNITS 1 AND 2 3.5-6 Amendment No.

ECCS -- Shutdown 3.5.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.3.1 The following SRs are applicable for all equipment required In accordance with to be OPERABLE: applicable SRs SR 3.5.2.1 SR 3.5.2.4 SR 3.5.2.7 SR 3.5.2.8 COMANCHE PEAK - UNITS 1 AND 2 3.5-7 Amendment No.

RWST 3.5.4 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.4 Refueling Water Storage Tank (RWST)

LCO 3.5.4 The RWST shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RWST boron concentration A.1. Restore RWST to OPERABLE 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months not within limits, status.

OR RWST borated water temperature not within limits.

B. RWST inoperable for B.1 Restore RWST to OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months reasons other than status.

Condition A.

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. AND C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.5-8 Amendment No.

RWST 3.5.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.4.1 - --------------------- NOTE ------------------

Only required to be performed when ambient air temperature is < 40'F or > 120'F.

Verify RWST borated water temperature is > 40'F and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

< 120 0 F.

SR 3.5.4.2 Verify RWST borated water volume is >_473,731 gallons. 7 days SR 3.5.4.3 Verify RWST boron concentration is __2400 ppm and 7 days

< 2600 ppm.

COMANCHE PEAK - UNITS 1 AND 2 3.5-9 Amendment No.

Seal Injection Flow 3.5.5 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.5 Seal Injection Flow LCO 3.5.5 Reactor coolant pump seal injection flow shall be <ý40 gpm with RCS pressure

Ž2215 psig and

2255 psig and the charging flow control valve full open.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Seal injection flow not A.1 Adjust manual seal injection throttle 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months within limit. valves to give a flow within limit with RCS pressure > 2215 psig and <

2255 psig and the charging,flow control valve full open.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.5.5.1 ------------------------ NOTE ------------------

Not required to be performed until 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months after the Reactor Coolant System pressure stabilizes at >_2215 psig and <

2255 psig.

Verify manual seal injection throttle valves are adjusted to 31 days give a flow within limit with RCS pressure Ž 2215 psig and <

2255 psig and the charging flow control valve full open.

COMANCHE PEAK - UNITS, 1 AND 2 3.5-10 Amendment No.

Containment 3.6.1 3.6 CONTAINMENT SYSTEMS 3.6.1 Containment LCO 3.6.1 Containment shall be OPERABLE.

APPLICABILITY: MODES 1,2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment inoperable. A.1 Restore containment to OPERABLE 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months status!

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.1.1. Perform required visual examinations and leakage rate In accordance with testing except for containment air lock testing, in the Containment accordance with the Containment Leakage Rate Testing Leakage Rate Program. Testing Program COMANCHE PEAK - UNITS 1 AND 2 3.6-1 Amendment No.

Containment Air Locks 3.6.2 3.6 CONTAINMENT SYSTEM 3.6.2 Containment Air Locks LCO 3.6.2 Two containment air locks shall be OPERABLE.

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

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

1. Entry and exit is permissible to perform repairs on the affected air lock components.

2. Separate Condition entry is allowed for each air lock.

3. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when air lock leakage results in exceeding the overall containment leakage rate.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-2 Amendment No.

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment - ----------------------- NOTES -----------

air locks with one 1. Required Actions A.1, A.2, and A.3 containment air lock door are not applicable if both doors in the inoperable. same air lock are inoperable and Condition C is entered.

2. Entry and exit is permissible for 7 days under administrative controls if both air locks are inoperable.

A.1 Verify the OPERABLE door is closed 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in the affected air lock.

AND A.2 Lock the OPERABLE door closed in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the affected air lock.

AND A.3 ----------- NOTE -----------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify the OPERABLE door is locked Once per 31 days closed in the affected air lock.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-3 Amendment No.

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more containment - ----------------------- NOTES -----------

air locks with containment 1. Required Actions B.1, B.2, and B.3 are air lock interlock not applicable if both doors in the same mechanism inoperable. air lock are inoperable and Condition C is entered.

2. Entry and exit of containment is permissible under the control of a dedicated individual.

B.1 Verify an OPERABLE door is closed 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months in the affected air lock.

AND B.2 Lock an OPERABLE door closed in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months the affected air lock.

AND B.3 ------------ NOTE --------------------

Air lock doors in high radiation areas may be verified locked closed by administrative means.

Verify an OPERABLE door is locked Once per 31 days closed in the affected air lock.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-4 Amendment No.

Containment Air Locks 3.6.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more containment C.1 Initiate action to evaluate overall Immediately air locks inoperable for containment leakage rate per LCO reasons other than 3.6.1.

Condition A or B.

AND C.2 Verify a door is closed in the affected 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months air lock.

AND C.3 Restore air lock to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.6-5 Amendment No.

Containment Air Locks 3.6.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.2.1 --------------------- NOTES ----------------

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

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

Perform required air lock leakage rate testing in In accordance with accordance with the Containment Leakage Rate Testing the Containment Program. Leakage Rate Testing Program SR 3.6.2.2 Verify only one door in the air lock can be opened at a time. 24 months COMANCHE PEAK - UNITS 1 AND 2 3.6-6 Amendment No.

Containment Isolation Valves 3.6.3 3.6 CONTAINMENT SYSTEMS 3.6.3 Containment Isolation Valves LCO 3.6.3 Each containment isolation valve shall be OPERABLE.

-NOTE-Not applicable to Main Steam Safety Valves (MSSVs), Main Steam Isolation Valves (MSIVs), Feedwater Isolation Valves (FIVs) and Associated Bypass Valves, and Steam Generator Atmospheric Relief Valves (ARVs).

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

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

1. Penetration flow path(s) except for 48 inch containment and 12 inch hydrogen purge valve flow paths may be unisolated intermittently under administrative controls.

2. Separate Condition entry is allowed for each penetration flow path.

3. Enter applicable Conditions and Required Actions for systems made inoperable by containment isolation valves.

4. Enter applicable Conditions and Required Actions of LCO 3.6.1, "Containment," when isolation valve leakage results in exceeding the overall containment leakage rate acceptance criteria.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-7 Amendment No.

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. -------- NOTE------- A.1 Isolate the affected penetration flow 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months Only applicable to path by use of at least one closed penetration flow paths with and de-activated automatic valve, two containment isolation closed manual valve, blind flange, or valves. check valve with flow through the valve secured.

One or more penetration AND flow paths with one containment isolation valve inoperable except for A.2 ----------- NOTES ----------

containment purge, 1. Isolation devices in high radiation hydrogen purge or areas may be verified by use of containment pressure relief administrative means.

valve leakage not within limit. 2. Isolation devices that are locked, sealed or otherwise secured may be verified by administrative means.

Verify the affected penetration flow Once per 31 days for path is isolated. isolation devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment (continued)

COMANCHE PEAK- UNITS 1 AND 2 3.6-8 Amendment No.

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. --------- NOTE -------------

Only applicable to penetration flow paths with two containment isolation valves.

One or more penetration B.1 Isolate the affected penetration flow 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months flow paths with two path by use of at least one closed containment isolation and de-activated automatic valve, valves inoperable except closed manual valve, or blind flange.

for containment purge, hydrogen purge or containment pressure relief valve leakage not within limit.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-9 Amendment No.

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. -------- NOTE 1-------C Isolate the affected penetration flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months Only applicable to path by use of at least one closed penetration flow paths with and de-activated automatic valve, only one containment closed manual valve, or blind flange.

isolation valve and a closed system. AND One or more penetration C.2 ----------- NOTES ----------

flow paths with one 1. Isolation devices in high radiation containment isolation valve areas may be verified by use of inoperable. administrative means.

2. Isolation devices that are locked, sealed or otherwise secured may be verified by administrative means.

Verify the affected penetration flow Once per 31 days path is isolated.

D. One or more penetration D.1 Isolate the affected penetration flow 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months flow paths with one or more path by use of at least one closed containment purge, and de-activated automatic valve,

.hydrogen purge or closed manual valve, or blind flange.

containment pressure relief valves not within leakage AND limits.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-10 Amendment No.

Containment Isolation Valves 3.6.3 ACTIONS CONDITION IREQUIRED ACTION COMPLETION TIME D. (continued) D.2 ----------- NOTES ----------

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sealed or otherwise secured may be verified by administrative means.

Verify the affected penetration flow Once per 31 days for path is isolated. isolation devices outside containment AND Prior to entering MODE 4 from MODE 5 if not performed within the previous 92 days for isolation devices inside containment AND D.3 Perform SR 3.6.3.7 for the resilient. Once per 92 days seal purge valves closed to comply with Required Action D.1.

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. AND E.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.6-11 Amendment No.

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.3.1 Verify each 48 inch Containment Purge and 12 inch 31 days Hydrogen Purge valve is sealed closed, except for one purge valve in a penetration flow path while in Condition D of this LCO.

SR 3.6.3.2 Not used.

SR 3.6.3.3 ----------------------- NOTES -----------------

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

Verify each containment isolation manual valve and blind 31 days flange that is located outside containment and not locked, sealed, or otherwise secured and required to be closed during accident conditions is closed, except for containment isolation valves that are open under administrative controls.

SR 3.6.3.4 ----------------------- NOTES -----------------

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

2. The blind flange on the fuel transfer canal need not be verified closed except after each drainage of the canal.

Verify each containment isolation manual valve and blind Prior to entering flange that is located inside containment and not locked, MODE 4 from sealed, or otherwise secured and required to be closed MODE 5 if not during accident conditions is closed, except for performed within containment isolation valves that are open under the previous 92 administrative controls. days (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-12 Amendment No.

Containment Isolation Valves 3.6.3 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.3.5 Verify the isolation time of each automatic power operated In accordance containment isolation valve is within limits, with the Inservice Testing Program SR 3.6.3.6 Not used.

SR 3.6.3.7 ----------------------- NOTE -------------------

This surveillance is not required when the penetration flow path is isolated by a leak tested blank flange.

Perform leakage rate testing for containment purge, 18 months hydrogen purge and containment pressure relief valves with resilient seals.

SR 3.6.3.8 Verify each automatic containment isolation valve that is 18 months not locked, sealed or otherwise secured in position, actuates to the isolation position on an actual or simulated actuation signal.

SR 3.6.3.9 Not used.

SR 3.6.3.10 Not used.

SR 3.6.3.11 Not used.

SR 3.6.3.12 Not used.

SR 3.6.3.13 Not used.

-p COMANCHE PEAK - UNITS 1 AND 2 3.6-13 Amendment No.

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO 3.6.4 Containment pressure shall be > - 0.3 psig and < + 1.3 psig.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment pressure not A.1 Restore containment pressure to 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months within limits, within limits.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.4.1 Verify containment pressure is within limits. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.6-14 Amendment No.

Containment Air Temperature 3.6.5 3.6 CONTAINMENT SYSTEMS 3.6.5 Containment Air Temperature LCO 3.6.5 Containment average air temperature shall be < 120'F.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Containment average air A.1 Restore containment average air 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months temperature not within limit, temperature to within limit.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.5.1 Verify containment average air temperature is within limit. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.6-15 Amendment No.

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

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One containment spray A.1 Restore containment spray train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable. OPERABLE status.

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

B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months C. Two containment spray C.1 Enter LCO 3.0.3. Immediately trains inoperable.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.6.1 Verify each containment spray manual, power operated, 31 days and automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-16 Amendment No.

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.6.6.2 Not used.

SR 3.6.6.3 Not used.

SR 3.6.6.4 Verify each containment spray pump's developed head at In accordance with the flow test point is greater than or equal to the required the Inservice developed head. Testing Program SR 3.6.6.5 Verify each automatic containment spray valve in the flow 18 months path that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.6.6 Verify each containment spray pump starts automatically 18 months on an actual or simulated actuation signal.

SR 3.6.6.7 Not used.

SR 3.6.6.8 Verify each spray nozzle is unobstructed. Following maintenance which could result in nozzle blockage COMANCHE PEAK - UNITS 1 AND 2 3.6-17 Amendment No.

Spray Additive System 3.6.7 3.6 CONTAINMENT SYSTEMS 3.6.7 Spray Additive System LCO 3.6.7 The Spray Additive System shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Spray Additive System A.1 Restore Spray Additive System to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.6.7.1 Verify the spray additive system ensures an equilibrium In accordance with sump pH >_7.1 using NaOH. the Technical Requirements Manual COMANCHE PEAK - UNITS 1 AND 2 3.6-18 Amendment No.

MSSVs 3.7.1 3.7 PLANT SYSTEMS 3.7.1 Main Steam Safety Valves (MSSVs)

LCO 3.7.1 Five MSSVs per steam generator shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

NOTE.

Separate Condition entry is allowed for each MSSV.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more steam A.1 Reduce THERMAL POWER to *68% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months generators with one MSSV RTP.

inoperable and the Moderator Temperature Coefficient (MTC) zero or negative at all power levels.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-1 Amendment No.

MSSVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more steam B.1 Reduce Thermal Powerto less than 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months generators with two or more or equal to the Maximum Allowable MSSVs inoperable. % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

OR AND One or more steam generators with one MSSV B.2 ----------- NOTE -----------

inoperable and the MTC Only required in MODE 1.

positive at any power level.

Reduce the Power Range Neutron 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months Flux-High reactor trip setpoint to less than or equal to the Maximum Allowable % RTP specified in Table 3.7.1-1 for the number of OPERABLE MSSVs.

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. AND OR C.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months One or more steam generators with __4 MSSVs inoperable.

COMANCHE PEAK - UNITS 1 AND 2 3.7-2 Amendment No.

MSSVs 3:7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY' SR 3.7.1.1 ------------------------ NOTE ------------------

Only required to be performed in MODES 1 and 2.

Verify each required MSSV lift setpoint per Table 3.7.1-2 in In accordance with accordance with the Inservice Testing Program. Following the Inservice testing, lift setting shall be within +/- 1%. Testing Program COMANCHE PEAK - UNITS 1 AND 2 3.7-3 Amendment No.

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

OPERABLE Main Steam Safety Valves versus Maximum Allowable Power NUMBER OF OPERABLE MSSVs MAXIMUM ALLOWABLE POWER PER STEAM GENERATOR (% RTP) 4 *61 3 <43 2 *26 COMANCHE PEAK - UNITS 1 AND 2 3.7-4 Amendment No.

MSSVs 3.7.1 Table 3.7.1-2 (page 1 of 1)

Main Steam Safety Valve Lift Settings VALVE NUMBER LIFT SETTING STEAM GENERATOR (psig +/- 3%)

1 #2 #3 #4 MS-021 MS-058 MS-093 MS-129 1185 MS-022 MS-059 MS-094 MS-1 30 1195 MS-023 MS-060 MS-095 MS-131 1205 MS-024 MS-061 MS-096 MS-1 32 1215.

MS-025 MS-062 MS-097 MS-133 1235 COMANCHE PEAK - UNITS 1 AND 2 3.7-5 Amendment No.

MSIVs 3.7.2 3.7 PLANT SYSTEMS 3.7.2 Main Steam Isolation Valves (MSIVs)

LCO 3.7.2 Four MSIVs shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 except when all MSIVs are closed and deactivated.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One MSIV inoperable in A.1 Restore MSIV to OPERABLE status. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months MODE 1.

B. Required Action and B.1 Be in MODE 2. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met.

C. -------- NOTE --------------

Separate Condition entry is allowed for each MSIV.

One or more MSIV C.1 Close MSIV. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months inoperable in MODE 2 or 3.

AND C.2 Verify MSIV is closed. Once per 7 days D. Required Action and D.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 C not AND met.

D.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-6 Amendment No.

MSIVs 3.7.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.2.1 - --------------------- NOTE ------------------

Only required to be performed in MODES 1 and 2.

Verify the isolation time of each MSIV is < 5 seconds. In accordance with the Inservice Testing Program SR 3.7.2.2 - -------------------- NOTE ------------------

Only required to be performed in MODES 1 and 2.

Verify each MSIV actuates to the isolation position on an 18 months actual or simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-7 Amendment No.

FIVs and FCVs and Associated Bypass Valves 3.7.3 3.7 PLANT SYSTEMS 3.7.3 Feedwater Isolation Valves (FIVs) and Feedwater Control Valves (FCVs) and Associated Bypass Valves LCO 3.7.3 Four FIVs, four FCVs, and associated bypass valves shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 except when FIV, FCV or associated bypass valve is either closed and de-activated or isolated by a closed manual valve.

ACTIONS

-NOTE-Separate Condition entry is allowed for each valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more FIVs A.1 Close or isolate FIV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND A.2 Verify FIV is closed or isolated. Once per 7 days B. One or more FCVs B.1 Close or isolate FCV. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable.

AND B.2 Verify FCV is closed or isolated. Once per 7 days (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-8 Amendment No.

FIVs and FCVs and Associated Bypass Valves 3.7.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more FIV or FCV C.1 Close or isolate bypass valve. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months bypass valves inoperable.

AND C.2 Verify bypass valve is closed or Once per 7 days isolated.

D. Two valves in the same D.1 Isolate affected flow path. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months flowpath inoperable 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. AND E.2 Be in MODE 4. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.3.1 Verify the isolation time of each FIV, FCV, and associated In accordance with bypass valves is < 5 seconds. the Inservice Testing Program SR 3.7.3.2 Verify each FIV, FCV, and associated bypass valves 18 months actuates to the isolation position on an actual or simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-9 Amendment No.

ARVs 3.7.4 3.7 PLANT SYSTEMS 3.7.4 Steam Generator Atmospheric Relief Valves (ARVs)

LCO 3.7.4 Four ARV lines shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required ARV line A.1 Restore required ARV line to 7 days inoperable. OPERABLE status.

B. Two required ARV lines B.1 Restore at least one ARV line to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months inoperable. OPERABLE status.

C. Three or more required C.1 Restore at least two ARV lines to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ARV lines inoperable. OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-10 Amendment No.

ARVs 3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of each ARV. In accordance with the Inservice testing Program SR 3.7.4.2 Verify one complete cycle of each ARV block valve. In accordance with the Inservice testing Program COMANCHE PEAK - UNITS 1 AND 2 3.7-11 Amendment No.

AFW System 3.7.5 3.7 PLANT SYSTEMS 3.7.5 Auxiliary Feedwater (AFW) System LCO 3.7.5 Three AFW trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS

-NOTE-LCO 3.0.4.b is not applicable.

CONDITION REQUIRED ACTION COMPLETION TIME A. One steam supply to A.1 Restore steam supply to OPERABLE 7 days turbine driven AFW pump status.

inoperable.

B. One AFW train inoperable B.1 Restore AFW train to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months for reasons other than status.

Condition A.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-12 Amendment No.

AFW System 3.7.5 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 for Condition A or B AND not met.

C.2 Be in MODE 4. 18 hours2.083333e-4 days 0.005 hours 2.97619e-5 weeks 6.849e-6 months OR Two AFW trains inoperable.

D. Three AFW trains D.1 ----------- NOTE ----------

inoperable. LCO 3.0.3 and all other LCO Required Actions requiring MODE changes are suspended until one AFW train is restored to OPERABLE status.

Initiate action to restore one AFW Immediately train to OPERABLE status.

COMANCHE PEAK - UNITS 1 AND 2 3.7-13 Amendment No.

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY)

SR 3.7.5.1 ---------------------------------------- IM r:----------------------------------...

AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

Verify each AFW manual, power operated, and alutomatic 31 days valve in each water flow path, and in both steam supply flow paths to the steam turbine driven pump, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.5.2 -- -------------------- NOTE ------------------

Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 532 psig in the steam generator.

Verify the developed head of each AFW pump at the flow In accordance with test point is greater than or equal to the required developed the Inservice testing head. Program SR 3.7.5.3 ----------------------- NOTE ------------------

AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW mode of operation.

Verify each AFW automatic valve that is not locked, sealed, 18 months or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-14 Amendment No.

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS (continued)

SR 3.7.5.4 ---------------------- NOTES -----------------

1. Not required to be performed for the turbine driven AFW pump until 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months after > 532 psig in the steam generator.

2. AFW train(s) may be considered OPERABLE during alignment and operation for steam generator level control, if it is capable of being manually realigned to the AFW operation.

Verify each AFW pump starts automatically on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-15 Amendment No.

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

LCO 3.7.6 The CST level shall be _>53%.

APPLICABILITY: MODES 1, 2, and 3 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. CST level not within limit. A.1 Verify by administrative means 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months OPERABILITY of backup water supply. AND Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND A.2 Restore CST level to within limit. 7 days B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 4 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.6.1 Verify the CST level is _>53%. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-16 Amendment No.

CCW System 3.7.7 3.7 PLANT SYSTEMS 3.7.7 Component Cooling Water (CCW) System LCO 3.7.7 Two CCW trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CCW train inoperable. ------------- NOTE------------

Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops -

MODE 4," for residual heat removal loops made inoperable by CCW.

A.1 Restore CCW train to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.7-17 Amendment No.

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

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

Verify each CCW manual, power operated, and automatic 31 days valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.7.2 Verify each CCW automatic valve in the flow path that is 18 months not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.7.7.3 Verify each CCW pump starts automatically on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-18 Amendment No.

SSWS 3.7.8 3.7 PLANT SYSTEMS 3.7.8 Station Service Water System (SSWS)

LCO 3.7.8 Two SSWS trains and a SSW Pump on the opposite unit with its associated cross-connects shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required SSW Pump on A.1 Restore a SSW Pump on the 7 days the opposite unit or its opposite unit to OPERABLE status.

associated cross-connects inoperable. AND A.2 Restore associated cross-connects 7 days to OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-19. Amendment No.

SSWS 3.7.8 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One SSWS train B.1 ----------- NOTES ----------

inoperable. 1. Enter applicable Conditions and Required Actions of LCO 3.8.1, "AC Sources -- Operating," for emergency diesel generator made inoperable by SSWS.

2. Enter applicable Conditions and Required Actions of LCO 3.4.6, "RCS Loops.-- MODE 4," for residual heat removal loops made inoperable by SSWS.

Restore SSWS train to OPERABLE 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months status.

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 A or B AND not met.

C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.7-20 Amendment No.

SSWS 3.7.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.8.1 ------------------------ NOTE ------------------

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

Verify each SSWS manual, power operated, and automatic 31 days valve in the flow path servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.8.2 Verify one complete cycle of each required cross-connect 92 days valve that is not locked open.

SR 3.7.8.3 Verify each SSW pump starts automatically on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-21 Amendment No.

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

LCO 3.7.9 The Safe-Shutdown Impoundment (SSI) shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SSI level less than A.1 Restore SSI level to within limits. 7 days required.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months OR SSI inoperable for reasons other than Condition A.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.9.1 Verify water level of SSI is > 770 ft mean sea level. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months SR 3.7.9.2 Verify station service water intake temperature is < 102 0 F. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-22 Amendment No.

CREFS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Emergency Filtration/Pressurization System (CREFS)

LCO 3.7.10 Two CREFS trains shall be OPERABLE

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

The Control Room envelope (CRE) boundary may be opened. intermittently under administrative controls.

APPLICABILITY: MODES 1, 2, 3, 4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CREFS train A.1 Restore CREFS train to OPERABLE 7 days inoperable for reasons status.

other than Condition B.

B. One or more CREFS Trains B.1 Initiate action to implement mitigating Immediately inoperable due to actions.

inoperable CRE boundary in MODES 1, 2, 3, and 4. AND B.2 Verify mitigating actions to ensure 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months CRE occupant exposures to radiological, chemical, and smoke hazards will not exceed limits.

AND B.3 Restore CRE boundary to 90 days OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-23 Amendment No.

CREFS 3.7.10 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 of Condition A or B AND not met in MODE 1, 2, 3, or 4. C.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months D. Required Action and D.1 Place OPERABLE CREFS train in Immediately associated Completion emergency recirculation mode.

Time of Condition A not met in MODE 5 or 6, or during OR movement of irradiated fuel assemblies. D.2.1 Suspend CORE ALTERATIONS. Immediately AND D.2.2 Suspend movement of irradiated Immediately fuel assemblies.

E. Two CREFS trains E.1 Suspend CORE ALTERATIONS. Immediately inoperable in MODE 5 or 6, or during movement of AND irradiated fuel assemblies.

E.2 Suspend movement of irradiated fuel Immediately OR assemblies.

One or more CREFS trains inoperable due to an inoperable CRE boundary in MODE 5 or 6, or during movement of irradiated fuel assemblies.

F. Two CREFS trains F.1 Enter LCO 3.0.3. Immediately inoperable in MODE 1, 2, 3, or 4 for reasons other than Condition B.

COMANCHE PEAK- UNITS 1 AND 2 3.7-24 Amendment No.

CREFS 3.7.10 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.10.1 Operate each CREFS train's Emergency Pressurization 31 days Unit for >_10 continuous hours with the heaters operating and Emergency Filtration Unit >_15 minutes.

SR 3.7.10.2 Perform required CREFS testing in accordance with the In accordance with Ventilation Filter Testing Program (VFTP). the VFTP SR 3.7.10.3 Verify each CREFS train actuates on an actual or simulated 18 months actuation signal.

SR 3.7.10.4 Perform required CRE unfiltered air inleakage testing in In accordance with accordance with the Control Room Envelope Habitability the Control Room Program. Envelope Habitability Program COMANCHE PEAK - UNITS 1 AND 2 3.7-25 Amendment No.

CRACS 3.7.11 3.7 PLANT SYSTEMS 3.7.11 Control Room Air Conditioning System (CRACS)

LCO 3.7.11 Two CRACS trains shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3,4, 5, and 6, During movement of irradiated fuel assemblies.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One CRACS train A.1 Restore CRACS train to OPERABLE 30 days inoperable, status.

B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met AND in MODE 1, 2, 3, or 4.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Required Action and C.1 Place OPERABLE CRACS train in Immediately associated Completion operation.

Time of Condition A not met in MODE 5, or 6, or during OR movement of irradiated fuel assemblies. C.2.1 Suspend CORE ALTERATIONS. Immediately AND C.2.2 Suspend movement of irradiated Immediately fuel assemblies.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-26 Amendment No.

CRACS 3.7.11 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Two CRACS trains D.1.1 Verify at least 100% of the required Immediately inoperable in MODE 5 or 6, heat removal capability equivalent or during movement of to a single OPERABLE train irradiated fuel assemblies, available.

AND D.1.2 Restore the CRACS trains to 30 days OPERABLE status.

OR D.2.1 Suspend CORE ALTERATIONS. Immediately AND D.2.2 Suspend movement of irradiated Immediately fuel assemblies.

E. Two CRACS trains E.1.1 Verify at least 100% of the required Immediately inoperable in MODE 1, 2, 3, heat removal capability equivalent or 4. to a single OPERABLE train available.

AND E.1.2 Restore one CRACS train to 30 days OPERABLE status.

OR E.2 Enter LCO 3.0.3. Immediately COMANCHE PEAK - UNITS 1 AND 2 3.7-27 Amendment No.

CRACS 3.7.11 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.11.1 Verify each CRACS train has the capability to remove the 18 months assumed heat load.

COMANCHE PEAK - UNITS 1 AND 2 3.7-28 Amendment No.

PPVS - ESF Filtration Trains 3.7.12 3.7 PLANT SYSTEMS 3.7.12 Primary Plant Ventilation System (PPVS) - ESF Filtration Trains LCO 3.7.12 Two PPVS trains shall be OPERABLE APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. With one or more PPVS A.1 Restore PPVS trains to OPERABLE 30 days trains unable to maintain a status.

negative pressure envelope in the Auxiliary, Safeguards, and Fuel Buildings _> 0.05 inch water gauge.

B. With one or more PPVS B.1 Restore ability of PPVS trains to 7 days trains'unable to maintain a maintain a negative pressure negative pressure envelope envelope of _> 0.01 inch water gauge in the Auxiliary, pressure.

Safeguards, and Fuel Buildings _> 0.01 inch water gauge.

C. One PPVS train inoperable C.1 Restore PPVS train to OPERABLE 7 days for any reason except status.

Conditions A or B.

D. Required Actions and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Times not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK- UNITS 1 AND 2 3.7-29 Amendment No.

PPVS - ESF Filtration Trains 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ESF Filtration train for > 10 continuous hours 31 days with the heaters operating.

SR 3.7.12.2 Perform required ESF Filtration Unit filter testing in In accordance with accordance with the Ventilation Filter Testing Program the VFTP (VFTP).

SR 3.7.12.3 Verify each PPVS train actuates on an actual or simulated 18 months actuation signal.

SR 3.7.12.4 Verify one PPVS train can maintain a pressure 18 months on a

< -0.05 inches water gauge relative to atmospheric STAGGERED pressure during the post accident mode of operation. TEST BASIS SR 3.7.12.5 Not used.

SR 3.7.12.6 Verify each PPVS non-ESF fan stops on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-30 Amendment No.

FBACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Fuel Building Air Cleanup System (FBACS)

NOT USED COMANCHE PEAK - UNITS 1 AND 2 3.7-31 Amendment No.

PREACS 3.7.14 3.7 PLANT SYSTEMS 3.7.14 Penetration Room Exhaust Air Cleanup System (PREACS)

NOT USED COMANCHE PEAK - UNITS 1 AND 2 3.7-32 Amendment No.

Fuel Storage Area Water Level 3.7.15 3.7 PLANT SYSTEMS 3.7.15 Fuel Storage Area Water Level LCO 3.7.15 The fuel storage area water level shall be _> 23 ft over the top of the storage racks APPLICABILITY: During movement of irradiated fuel assemblies in a spent fuel storage area.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel-storage area water A.1 ---------- NOTE -------------------

level not within limit. LCO 3.0.3 is not applicable.

Suspend movement of irradiated fuel Immediately assemblies in the fuel storage area.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.15.1 Verify the fuel storage area water level is Ž23 ft above the 7 days top of the storage racks.

COMANCHE PEAK - UNITS 1 AND 2 3.7-33 Amendment No.

Fuel Storage Pool Boron Concentration 3.7.16 3.7 PLANT SYSTEMS 3.7.16 Fuel Storage Pool Boron Concentration LCO 3.7.16 The fuel storage pool boron concentration shall be >_2000 ppm.

APPLICABILITY: When fuel assemblies are stored in the fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron -------- NOTE concentration not within LCO 3.0.3 is not applicable.

limit. ------------------

A.1 Suspend movement of fuel Immediately assemblies in the fuel storage pool AND A.2 Initiate action to restore fuel storage Immediately pool boron concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.16.1 Verify the fuel storage pool boron concentration is within 7 days limit.

COMANCHE PEAK - UNITS 1 AND 2 3.7-34 Amendment No.

Spent Fuel Assembly Storage 3.7.17 3.7 PLANT SYSTEMS 3.7.17 Spent Fuel Assembly Storage LCO 3.7.17 The combination of initial enrichment, burnup and decay time of each spent fuel assembly stored in Region II racks shall be within either (1) the "acceptable" domain of Figure 3.7.17-1 in a 4 out of 4 configuration, (2) the "acceptable" domain of Figure 3.7.17-2 in a 3 out of 4 configuration, (3) the "acceptable" domain of Figure 3.7.17-3 in a 2 out of 4 configuration, or (4) shall be stored in a 1 out of 4 configuration. The acceptable storage configurations are shown in Figure 3.7.17-4.

APPLICABILITY: Whenever any fuel assembly is stored in Region II racks of the spent fuel storage pool.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Requirements of the LCO A.1 ---------- NOTE ----------

not met. LCO 3.0.3 is not applicable.

Initiate action to move the Immediately noncomplying fuel assembly to an acceptable storage location.

COMANCHE PEAK - UNITS 1 AND 2 3.7-35 Amendment No.

Spent Fuel Assembly Storage 3.7.17 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.17.1 Verify by administrative means the initial enrichment, Prior to storing the burnup and decay time of the fuel assembly is in fuel assembly in accordance with either (1) the "acceptable" domain of Region II racks Figure 3.7.17-1 in a 4 out of 4 configuration, (2) the "acceptable" domain of Figure 3.7.17-2 in a 3 out of 4 configuration, (3) the "acceptable" domain of Figure 3.7.17-3 in a 2 out of 4 configuration, or (4) a 1 out of 4 configuration. The acceptable storage configurations are shown in Figure 3.7.17-4.

COMANCHE PEAK - UNITS 1 AND 2 3.7-36 Amendment No.

Spent Fuel Assembly Storage 3.7.17 Decay 65000 Time:

0 Years' 60000 55000 50000 45000 40000 CL 35000 30000

.0 E

(0 25000 4L 20000 15000 10000 UNACCEPTABLE 5000 0

11.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (wlo)

Figure 3.7.17-1 (page 1 of 1)

Fuel Assembly Burnup vs. U-235 Enrichments vs. Decay Time Limits For a 4 out of 4 Storage Configuration in Region 11Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-37 Amendment No.

Spent Fuel Assembly Storage 3.7.17 45000 I I I I I I Decay II I I I I Time:

I I I I 0 Years 40000 CCPTABLE4 35000 30000 7P 25000 E UNCCPTBL M 20000 /

E 7/

~L/

= 15000 LL 10000 5000 0

1.0 2.0 3.0 4.0 5.0 Initial U-235 Enrichment (w/o)

Figure 3.7.17-2 (page 1 of 1)

Minimum Burnup vs. Initial U-235 Enrichment vs. Decay Time For a 3 out of 4 Storage Configuration in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-38 Amendment No.

Spent Fuel Assembly Storage 3.7.17 20000

-1 ! i ! i --i- i I Ii -- -- --

15000 I--

I ACCEPTABLE CL n

F a.

2%

m ME

-=

" 10000 LIMIUM1= E 21 ýýiýTp.

E

()

i i i I I i! I I I i! I i ! I I --I1--I-I- ----

--I-----I IV I --I is-- ! ! ! I ! I ! I I I Ii I U)

LL a)

U-5000 UNACCEPTABLE F-0 2.8 3.0 3.2 3.4 3.6 3.8 4.0 4.2 4.4 4.6 4.8 5.0 Initial U-235 Enrichment (w/o)

Figure 3.7.17-3 (page 1 of 1)

Minimum Burnup vs. Initial U-235 Enrichment For a 2 out of 4 Storage Configuration in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-39 Amendment No.

Spent Fuel Assembly Storage 3.7.17 A A A A A A B B B A A A A A A B B B B B B AAAAAA B B B A A A A A A B B B B B B A A A A A A B B B A A A A A A B B B BB C C C C C C D D D C C C C C C D D D C C C C C C D D D A Region 11 (4/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-1.

B Region 11 (3/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-2.

C Region 11 (2/4), new or partially spent fuel assemblies in the "acceptable" domain of Figure 3.7.17-3.

D Region 11 (1/4), new or partially spent fuel assemblies which are stored in an expanded checkerboard (1 out of 4).

El - empty Note: All possible 2 by 2 matrices containing Region II rack cells shall comply with at least one of the following: (1) within the "acceptable" domain of Figure 3.7.17-1 in a 4 out of 4 configuration, (2) within the "acceptable" domain of Figure 3.7.17-2 in a 3 out of 4 configuration, (3) within the "acceptable" domain of Figure 3.7.17-3 in a 2 out of 4 configuration, or (4) a 1 out of 4 configuration.

Region I and Region II interface restrictions: The Region Il 1 out of 4 configuration shall be oriented such that the single fuel assembly resides in the internal row with the empty cells facing Region I. There are no interface restrictions between the Region 11 (2/4, 3/4, 4/4) and Region I configurations.

Figure 3.7.17-4 (page 1 of 1)

Storage Configurations (4/4, 3/4, 2/4, 1/4) in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-40 Amendment No.

Secondary Specific Activity 3.7.18 3.7 PLANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3.7.18 The specific activity of the secondary coolant shall be <! 0. 10 pCi/gm DOSE EQUIVALENT 1-131 APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Specific activity not within A.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months limit.

AND A.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SIR 3.7.18.1 Verify the specific activity of the secondary coolant is

0.10 31 days pCi/gm DOSE EQUIVALENT 1-131.

COMANCHE PEAK - UNITS 1 AND 2 3.7-41 Amendment No.

Safety Chilled Water 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Safety Chilled Water LCO 3.7.19 Two safety chilled water trains shall be OPERABLE APPLICABILITY: MODES 1, 2, 3, and 4.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One safety chilled water A.1 Restore safety chilled water train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months train inoperable. OPERABLE status.

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

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months V

COMANCHE PEAK - UNITS 1 AND 2 3.7-42 Amendment No.

Safety Chilled Water 3.7.19 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.19.1 ---------------------- NOTE -----------------------------------

Isolation of safety chilled water flow to individual components does not render the safety chilled water system inoperable.

Verify each safety chilled water manual, power operated, 31 days and automatic valve servicing safety related equipment, that is not locked, sealed, or otherwise secured in position, is in the correct position.

SR 3.7.19.2 Verify each safety chilled water pump and chiller starts on 18 months an actual or simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-43 Amendment No.

UPS HVAC System 3.7.20 3.7 PLANT SYSTEMS 3.7.20 UPS HVAC System LCO 3.7.20 Two UPS HVAC System Trains shall be OPERABLE APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS "

CONDITION REQUIRED ACTION COMPLETION TIME A. One UPS HVAC System A.1 Verify the affected UPS & Distribution Immediately train inoperable. Room is supported by an OPERABLE UPS A/C Train.

AND A.2 Restore the inoperable UPS HVAC 30 days train to OPERABLE status.

B. Two UPS HVAC System ' B.1 Verify air circulation is maintained by Immediately trains inoperable, at least one UPS A/C Train.

OR AND Required Action A.1 and B.2 Verify the air temperature in the 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months associated Completion affected UPS & Distribution Room(s)

Time not met. does not exceed the maximum AND temperature limit for the room(s).

Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter AND B.3 Restore UPS HVAC System train to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-44 Amendment No.

UPS HVAC System 3.7.20 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action B.1 and C.1 Restore the required support. 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months associated Completion Time not met.

D. Required Action and D.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 Required Action AND A.2, B.2, B.3 or C.1 not met. D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months COMANCHE PEAK - UNITS 1 AND 2 3.7-45 Amendment No.

UPS HVAC System 3.7.20 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.20.1 Verify each required UPS & Distribution Room Fan Coil 31 days Unit operates _>1 continuous hour.

SR 3.7.20.2 Verify each required UPS A/C train operates for >_1 31 days continuous hour.

SR 3.7.20.3 Verify each required UPS A/C train actuates on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-46 Amendment No.

AC Sources -- Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources -- Operating LCO 3.8.1 The following AC electrical sources shall be OPERABLE:

a. Two qualified circuits between the offsite transmission network and the onsite Class 1E AC Electrical Power Distribution System;

b. Two diesel generators (DGS) capable of supplying the onsite Class 1 E power distribution subsystem(s); and

c. Automatic load sequencers for Train A and Train B.

APPLICABILITY: MODES 1, 2, 3, and 4

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

One DG may be synchronized with the offsite power source under administrative controls for the purpose of surveillance testing.

COMANCHE PEAK - UNITS 1 AND 2 3.8-1 Amendment No.

AC Sources -- Operating 3.8.1 ACTIONS

-NOTE-LCO 3.0.4.b is not applicable to DGs.

CONDITION REQUIRIED ACTION COMPLETION TIME A. One required offsite circuit A.1 Perform SR 3.8.1.1 for required 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months inoperable. OPERABLE offsite circuit.

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND A.2 ----------- NOTE ----------

In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

Declare required feature(s) with no 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months from discovery offsite power available inoperable of no offsite power to when its redundant required one train concurrent feature(s) is inoperable, with inoperability of redundant required feature(s)

AND A.3 Restore required offsite circuit to 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-2 . Amendment No.

AC Sources -- Operating 3.8.1 ACTIONS (continued)

CONDITION E REQUIRED ACTION COMPLETION TIME B. One DG inoperable. B.1 Perform SR 3.8.1.1 for the required 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months offsite circuit(s).

AND Once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter AND B.2 ------------ NOTE --------------------

In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

Declare required feature(s) 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months from discovery supported by the inoperable DG of Condition B inoperable when its required concurrent with redundant feature(s) is inoperable. inoperability of redundant required feature(s)

AND B.3.1 Determine OPERABLE DG(s) is 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months not inoperable due to common cause failure.

OR B.3.2 ----------- NOTE ----------

The SR need not be performed if the DG is already operating and loaded.

Perform SR 3.8.1.2 for OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months DG(s).

(continued)

COMANCHE PEAK- UNITS 1 AND 2 3.8-3 Amendment No.

AC Sources -- Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. (continued) AND B.4 Restore DG to OPERABLE status. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months C. Two required offsite circuits C.1 ------------ NOTE ----------

inoperable. In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

Declare required feature(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months from discovery inoperable when its redundant of Condition C required feature(s)'is inoperable, concurrent with inoperability of redundant required features AND C.2 Restore one required offsite circuit to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months OPERABLE status.

(continued) 4 COMANCHE PEAK - UNITS 1 AND 2 3.8-4 Amendment No.

AC Sources -- Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One required offsite circuit ------------- NOTE------------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution AND, Systems - Operating," when Condition D is entered with no AC power source to any One DG inoperable, train.

D.1 Restore required offsite circuit to 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months OPERABLE status.

OR D.2 Restore DG to OPERABLE status. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months E. Two DGs inoperable. E.1 Restore one DG to OPERABLE 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months status.

F. One SI sequencer F.1 ----------- NOTE ---------------------

inoperable. One required SI sequencer channel may be bypassed for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months for surveillance testing provided the other channel is operable.

Restore SI sequencer to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months status.

G. Required Action and G.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 A, B, C, AND D, E, or F not met.

G.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-5 Amendment No.

AC Sources -- Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Three or more required AC H.1 Enter LCO 3.0.3. Immediately sources inoperable.

I. One Blackout Sequencer 1.1 Declare associated DG inoperable Immediately inoperable SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.1.1 Verify correct breaker alignment and indicated power 7 days availability for each required offsite circuit.

SR 3.8.1.2 ----------------------- NOTES ------------------

1. Performance of SR 3.8.1.7 satisfies this SR.

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

3. A modified DG start involving idling and gradual acceleration to synchronous speed may be used for this SR as recommended by the manufacturer. When modified start procedures are not used, the time, voltage, and frequency tolerances of SR 3.8.1.7 must be met.

Verify each DG starts from standby conditions and 31 days achieves steady state voltage > 6480 V and

7150 V, and frequency >_58.8 Hz and _< 61.2 Hz.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-6 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.3 --------------------- NOTES -----------------

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

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

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

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

Verify each DG is synchronized and loaded and operates 31 days for >_60 minutes at a load _> 6300 kW and < 7000 kW.

SR 3.8.1.4 Verify each day tank contains _>1440 gal of fuel oil. 31 days SR 3.8.1.5 Check for and remove accumulated water from each day 31 days tank.

SR 3.8.1.6 Verify the fuel oil transfer system operates to automatically 92 days transfer fuel oil from storage tank to the day tank.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-7, Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY i

SR 3.8.1.7 ---------------------- NOTE All DG starts may be preceded by an engine prelube period.

Verify each DG starts from standby condition and achieves: 1184 days

a. in

10 seconds, voltage Ž>6480 V and frequency _

58.8 Hz; and

b. steady state, voltage > 6480 V and < 7150V, and frequency _>58.8 Hz and < 61.2 Hz.

SR 3.8.1.8 ---------------------- NOTE ------------------

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

Verify automatic and manual transfer of AC power sources 18 months from the normal offsite circuit to each alternate required offsite circuit.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-8 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY S R 3.8.1.9 -- --------------------

Ik I#* *r'lr Iv-- t-. -----------------------------------

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

Verify each DG rejects a load greater than or equal to its 18 months associated single largest post-accident load, and:

a. Following load rejection, the frequency is < 66.75 Hz; and

b. Within 3 seconds following load rejection, the voltage is Ž_6480 V and < 7150 V.

SR 3.8.1.10 Verify each DG does not trip and voltage is maintained < 18 months 8280 V during and following a load rejection of _Ž6300 kW and < 7000 kW.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-9 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 ---------------------- NOTES -----------------

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

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

Verify on an actual or simulated loss of offsite power signal: 18 months

a. De-energization of emergency buses;

b. Load shedding from emergency buses;

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in

10 seconds,

2. energizes auto-connected shutdown loads through automatic load sequencer,

3. maintains steady state voltage Ž>6480 V and

<7150 V,

4. maintains steady state frequency _ 58.8 Hz and *61.2 Hz, and

5. supplies permanently connected and auto-connected shutdown loads for

_ 5 minutes.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-10 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 -- -------------------- NOTE ------------------

All DG starts may be preceded by prelube period.

Verify on an actual or simulated Safety Injection (SI) 18 months actuation signal each DG auto-starts from standby condition and;

a. in < 10 seconds after auto-start and during tests, achieves voltage _> 6480 V and frequency

> 58.8 Hz;

b. Achieves steady state voltage > 6480 V and < 7150 V and frequency > 58.8 Hz and < 61.2 Hz;

c. Operates for _>5 minutes; SR 3.8.1.13 ----------------------- NOTE ------------------

For Unit 2, testing need only be performed for LOOP concurrent with SI until startup following 2RFO5.

Verify each DG's automatic trips are bypassed on actual or 18 months simulated (i) loss of voltage signal on the emergency bus, and (ii) SI actuation signal, except:

a. Engine overspeed; and

b. Generator differential current.

(continued)

COMANCHE PEAK- UNITS 1 AND 2 3.8-11 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE'REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 Momentary transients outside the load and power factor ranges do not invalidate this test.

Verify each DG operates for > 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: 18 months

a. For _ 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded > 6900 kW and < 7700 kW; and

b. For the remaining hours of the test loaded _ 6300 kW and < 7000 kW.

SR 3.8.1.15 NOTES --------------------

1. This Surveillance shall be performed within 5 minutes of shutting down the DG after the DG has operated > 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded > 6300 kW and < 7000 kW. Momentary transients outside of load range do not invalidate this test.

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

Verify each.DG starts and achieves: 18 months

a. in

10 seconds, voltage Ž6480 V and frequency >

58.8 Hz; and

b. steady state, voltage Ž6480 V and < 7150 V and frequency >_58.8 Hz and < 61.2 Hz.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-12 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16 ---------------------- NOTE ------------------

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

Verify each DG: 18 months

a. Synchronizes with offsite power source while loaded with emergency loads upon a simulated restoration of offsite power;

b. Transfers loads to offsite power source; and

c. Returns to ready-to-load operation.

SR 3.8.1.17 ---------------------- NOTE ------------------

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

Verify, with a DG operating in test mode and connected to 18 months its bus, an actual or simulated SI actuation signal overrides the test mode by:

a. Returning DG to ready-to-load operation; and

b. Automatically energizing the emergency load from offsite power.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-13 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.18 ---------------------- NOTE ------------------

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

Verify interval between each sequenced load block is within 18 months

+/- 10% of design interval for each automatic load sequencer.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-14 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

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

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

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

Verify on an actual or simulated loss of offsite power signal 18 months in conjunction with an actual or simulated SI actuation signal:

a. De-energization of emergency buses;

b. Load shedding from emergency buses; and

c. DG auto-starts from standby condition and:

1. energizes permanently connected loads in <

10 seconds,

2. energizes auto-connected emergency loads through load sequencer,

3. achieves steady state voltage _>6480 V and

<7150 V,

4. achieves steady state frequency > 58.8 Hz and

61.2 Hz, and

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

> 5 minutes.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-15 Amendment No.

AC Sources -- Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.20 ----------- ---------- NOTE ....... :---------------------------

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

Verify when started simultaneously from standby condition, 10 years each DG achieves:

a. in < 10 seconds, voltage > 6480,V and frequency _

58.8 Hz, and

b. steady state, voltage > 6480 V, and <7150 V and frequency _>58.8 Hz and < 61.2 Hz.

SR 3.8.1.21 Calibrate BO sequencers. 18 months SR 3.8.1.22 ---------------------- NOTES -----------------

1. Verification of setpoint is not required.

2. Actuation of final devices is not included.

Perform TADOT for SI and BO sequencers. 31 days on a STAGGERED TEST BASIS.

COMANCHE PEAK - UNITS 1 AND 2 3.8-16 Amendment No.

AC Sources -- Shutdown 3.8.2 3.8 ELECTRICAL POWER SYSTEMS 3.8.2 AC Sources -- Shutdown LCO 3.8.2 The following AC electrical power sources shall be OPERABLE:

a. One qualified circuit between the offsite transmission network and the onsite Class 1 E AC electrical power distribution subsystem required by LCO 3.8.10, "Distribution Systems -- Shutdown"; and

b. One diesel generator (DG) capable of supplying one train of the onsite Class 1 E AC electrical power distribution subsystems required by LCO 3.8.10.

APPLICABILITY: MODES 5 and 6 COMANCHE PEAK - UNITS 1 AND 2 3.8-17 Amendment No.

AC Sources -- Shutdown 3.8.2 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit - ------------------------ NOTE ------------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.10, with the required train de-energized as a result of Condition A.

A.1 Declare affected required feature(s) Immediately with no offsite power available inoperable.

OR A.2.1 Suspend CORE ALTERATIONS. Immediately AND A.2.2 Suspend movement of irradiated Immediately fuel assemblies.

AND A.2.3 Suspend operations involving Immediately positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.4 Initiate action to restore required Immediately offsite power circuit to OPERABLE status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-18 Amendment No.

AC Sources -- Shutdown 3.8.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One required DG B.1 Suspend CORE ALTERATIONS. Immediately inoperable.

AND B.2 Suspend movement of irradiated fuel Immediately assemblies.

AND B.3 Suspend operations involving Immediately positive reactivity additions that could result in loss of required SDM or boron concentration.

AND B.4 Initiate action to restore required'DG Immediately to OPERABLE status.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

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

The following SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.9 through SR 3.8.1.11, SR 3.8.1.14, SR 3.8.1.15, and SR 3.8.1.16.

SR 3.8.2.1 For AC sources required to be OPERABLE, the following In accordance with SRs are applicable: applicable SRs SR 3.8.1.1 SR 3.8.1.5 SR 3.8.1.10 SR 3.8.1.2 SR 3.8.1.6 SR 3.8.1.11 (except c.2)

SR 3.8.1.3 SR 3.8.1.7 SR 3.8.1.14 SR 3.8.1.4 SR 3.8.1.9 SR 3.8.1.15 SR 3.8.1.16 COMANCHE PEAK - UNITS 1 AND 2 3.8-19 Amendment No.

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 3.8 ELECTRICAL POWER SYSTEMS 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air LCO 3.8.3 The stored diesel fuel oil, lube oil, and starting air subsystem shall be within limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

--------------------------------------------- ,1t. tLJ I------------------------------------------

li I"-

Separate Condition entry is allowed for each DG.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more DGs with fuel A.1 Restore fuel oil level to within limits. 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months level between 74,600 and 86,000 gal in MODES 1-4 or between 65,600 and 75,000 in MODES 5 & 6 in storage tank.

B. One or more DGs with lube B.1 Restore lube oil inventory to within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months oil inventory less than a limits.

level 1.75" below the low static level but greater than a level 5.5" below the low static level of the lube oil dipstick.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-20 Amendment No.

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more DGs with C.1 Restore fuel oil total particulates 7 days stored fuel oil total within limit.

particulates not within limit.

D. One or more DGs with new D.1 Restore stored fuel oil properties to 30 days fuel oil properties not within within limits.

limits.

E. Required Action and E.1 Declare associated DG inoperable. Immediately associated Completion Time not met.

OR One or more DGs diesel fuel oil, lube oil, or starting air subsystem not within limits for reasons other than Condition A, B, C or D.

COMANCHE PEAK - UNITS 1 AND 2 3.8-21 Amendment No.

Diesel Fuel Oil, Lube Oil, and Starting Air 3.8.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.3.1 Verify each fuel oil storage tank contains > 86,000 gal 31 days (MODES 1-4) or 75,000 gal (MODES 5 & 6) of fuel.

SR 3.8.3.2 ----------------------- NOTE ------------------

Not required to be performed until the engine has been shutdown for> 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months .

Verify lubricating oil inventory is __a level 1.75" below the 31 days low static level on the lube oil dipstick.

SR 3.8.3.3 Verify fuel oil properties of new and stored fuel oil are In accordance with tested in accordance with, and maintained within the limits the Diesel Fuel Oil of, the Diesel Fuel Oil Testing Program. Testing Program SR 3.8.3.4 Verify each required DG air start receiver pressure is >_180 31 days psig.

SR 3.8.3.5 Check for and remove accumulated water from each fuel oil 31 days storage tank.

COMANCHE PEAK - UNITS 1 AND 2 3.8-22 Amendment No.

DC Sources - Operating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC Sources - Operating LCO 3.8.4 The Train A and Train B DC electrical power subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or two required battery A.1 Restore affected battery(ies) terminal 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months chargers on one train voltage to greater than or equal to the inoperable, minimum established float voltage.

AND A.2 Verify affected battery(ies) float Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months current

2 amps.

AND A.3 Restore required battery charger(s) 7 days to OPERABLE status.

B. One or two batteries on one B.1 Restore affected battery(ies) to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months train inoperable. OPERABLE status.

C. One DC electrical power C.1 Restore DC electrical power 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystem inoperable for subsystem to OPERABLE status.

reasons other than Condition A or B.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-23 Amendment No.

DC Sources - Operating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months Associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.4.1 Verify battery terminal voltage is greater than or equal to 7 days the minimum established float voltage.

SR 3.8.4.2 Verify each battery charger supplies > 300 amps at greater 18 months than or equal to the minimum established charger test voltage for >_8 hours.

OR Verify each battery charger can recharge the battery to the fully charged state within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months while supplying the largest combined demands of the various continuous steady state loads, after a battery discharge to the bounding design basis event discharge state.

(continued)

COMANCHE PEAK- UNITS 1 AND 2 3.8-24 Amendment No.

DC Sources - Operating 3.8.4 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.4.3 ----------------------- NOTES ------------------

1. The modified performance discharge test in SR 3.8.6.6 may be performed in lieu of SR 3.8.4.3.

/

2. Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

Verify battery capacity is adequate to supply, and maintain 18 months in OPERABLE status, the required emergency loads for the design duty cycle when subjected to a battery service test.

COMANCHE PEAK - UNITS 1 AND 2 3.8-25 Amendment No.

DC Sources -- Shutdown 3.8.5 3.8 ELECTRICAL POWER SYSTEMS 3.8.5 DC Sources -- Shutdown LCO 3.8.5 The Train A or Train B DC electrical power subsystem shall be OPERABLE to support one train of the DC electrical power distribution subsystems required by LCO 3.8.10, "Distribution Systems - Shutdown."

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required DC electrical A.1 Declare affected required feature(s) Immediately power subsystems inoperable.

inoperable.

OR A.2.1 Suspend CORE ALTERATIONS. Immediately AND A.2.2 Suspend movement of irradiated Immediately fuel assemblies.

AND A.2.3 Suspend operations involving Immediately positive reactivity additions that could result in loss of required SDM

.or boron concentration.

AND A.2.4 Initiate action to restore required Immediately DC electrical power subsystem to OPERABLE status.

COMANCHE PEAK - UNITS 1 AND 2 3.8-26 Amendment No.

DC Sources -- Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY K IT~

SR 3.8.5.1 - - - - - - -- - - - - - - - -INUI ---

C:-----------------------------------

The following SRs are not required to be performed: SR 3.8.4.2 and SR 3.8.4.3.

For DC sources required to be OPERABLE, the following In accordance with SRs are applicable: applicable SRs SR 3.8.4.1 SR 3.8.4.2 SR 3.8.4.3.

COMANCHE PEAK - UNITS 1 AND 2 3.8-27 Amendment No.

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.8.6 Battery parameters for Train A and Train B batteries shall be within limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS

NOTE-Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One ortwo batteries on one A.1 Perform SR 3.8.4.1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months train with one or more battery cells float voltage AND

< 2.07 V.

A.2 Perform SR 3.8.6.1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months AND A.3 Restore affected cell(s) float voltage 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

>2.07 V.

B. One ortwo batterieson one B.1 Perform SR 3.8.4.1 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months train with float current

> 2 amps. AND B.2 Restore affected battery(ies) float 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months current to < 2 amps.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-28 Amendment No.

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. --------- NOTE -------------------- NOTE.

Required Action C.2 shall Required Actions C.1 and C.2 are only be completed if electrolyte applicable if electrolyte level was below level was below the top of the top of plates.

plates.

One or two batteries on one C.1 Restore affected cell(s) electrolyte 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months train with one or more cells level to above the top of the plates.

electrolyte level less than minimum established AND design limits.

C.2 Verify no evidence of leakage. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months AND C.3 Restore affected cell(s) electrolyte 31 days level to greater than or equal to minimum established design limits.

D. One ortwo batteries on one D.1 Restore battery pilot cell(s) 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months train with pilot cell electrolyte temperature to greater electrolyte temperature less than or equal to minimum established than minimum established design limits.

design limits.

E. One or more batteries in E.1 Restore battery parameters for 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months redundant trains with batteries in one train to within limits.

battery parameters not within limits.

(continued)

COMANCHE PEAK - UNITS 1 AND 2, 3.8-29 Amendment No.

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME F. Required Action and F.1 Declare associated battery(ies) Immediately associated Completion inoperable.

Time of Condition A, B, C, D, or E not met.

OR One or two batteries on one train with one or more battery cells float voltage

< 2.07 V and float current

> 2 amps.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.6.1 -- --------------------- NOTE ------------------

Not required to be met when battery terminal voltage is less than the minimum established float voltage of SR 3.8.4.1 Verify each battery float current is < 2 amps. 7 days SR 3.8.6.2 Verify each battery pilot cell voltage is > 2.07 V. 31 days SR 3.8.6.3 Verify each battery connected cell electrolyte level is 31 days greater than or equal to minimum established design limits.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-30 Amendment No.

Battery Parameters 3.8.6 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.6.4 Verify each battery pilot cell temperature is greater than or- 31 days equal to minimum established design limits.

SR 3.8.6.5 Verify each battery connected cell voltage is > 2.07 V. 92 days SR 3.8.6.6 - --------------------- NOTE ------------

Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

Verify battery capacity is _>80 % of the manufacturer's 60 months rating when subjected to a performance discharge test or a modified performance discharge test. AND 18 months when battery shows degradation or has reached 85% of expected life with capacity < 100% of manufacturer's rating AND 24 months when battery has reached 85% of the expected life with capacity

> 100% of manufacturer's rating COMANCHE PEAK - UNITS 1 AND 2 3.8-31 Amendment No.

Inverters -- Operating 3.8.7 3.8 ELECTRICAL POWER SYSTEMS 3.8.7 Inverters -- Operating LCO 3.8.7 The required Train A and Train B inverters shall be OPERABLE.

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

Inverters may be disconnected from one DC bus for < 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to perform an equalizing charge on their associated common battery, provided:

a. The associated AC vital bus(es) are energized; and

b. All other AC vital buses are energized from their OPERABLE inverters.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required inverter A.1 ------------ NOTE ----------

inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.9, "Distribution Systems - Operating" with any vital bus de-energized.

Restore inverter to OPERABLE 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months status.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-32 Amendment No.

Inverters -- Operating 3.8.7 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months , SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, and alignment to required 7 days AC vital buses.

COMANCHE PEAK - UNITS 1 AND 2 3.8-33 Amendment No.

Inverters -- Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters -- Shutdown LCO 3.8.8 The Train A or Train B inverters shall be OPERABLE to support one train of the onsite Class 1E AC vital bus electrical power distribution subsystems required by LCO 3.8.10, "Distribution Systems-Shutdown."

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required A.1 Declare affected required feature(s) Immediately inverters inoperable, inoperable:

OR A.2.1 Suspend CORE ALTERATIONS. Immediately AND A.2.2 Suspend movement of irradiated Immediately fuel assemblies.

AND A.2.3 Suspend operations involving Immediately positive reactivity additions that could result in loss of required SDM or boron concentration.

AND A.2.4 Initiate action to restore required Immediately inverters to OPERABLE status.

COMANCHE PEAK - UNITS 1 AND 2 3.8-34 Amendment No.

Inverters -- Shutdown 3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.8.1 Verify correct inverter voltage and alignments to required 7 days AC vital buses.

COMANCHE PEAK - UNITS 1 AND 2 3.8-35 Amendment No.

Distribution Systems -- Operating 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems -- Operating LCO 3.8.9 Train A and Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE.

APPLICABILITY: MODES 1, 2, 3, and 4 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One AC electrical power A.1 Restore AC electrical power 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months distribution subsystem distribution subsystem to inoperable. OPERABLE status.

B. One AC vital bus B.1 Restore AC vital bus subsystem to 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months subsystem inoperable. OPERABLE status.

C. One DC electrical power C.1 Restore DC electrical power 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months distribution subsystem distribution subsystem to inoperable. OPERABLE status.

D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time not met. AND D.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months E. Two trains with inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.

COMANCHE PEAK - UNITS 1 AND 2 3.8-36 Amendment No.

I

Distribution Systems -- Operating 3.8.9 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.9.1 Verify correct breaker alignments and voltage to required 7 days AC, DC, and AC vital bus electrical power distribution subsystems.

COMANCHE PEAK - UNITS 1 AND 2 3.8-37 Amendment No.

Distribution Systems -- Shutdown 3.8.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems -- Shutdown LCO 3.8.10 The necessary portion of the Train A or Train B AC, DC, and AC vital bus electrical power distribution subsystems shall be OPERABLE to support one train of equipment required to be OPERABLE.

APPLICABILITY: MODES 5 and 6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more required AC, A.1 Declare associated supported Immediately DC, or AC vital bus required feature(s) inoperable.

electrical power distribution subsystems inoperable. OR A.2.1 Suspend CORE ALTERATIONS. Immediately AND A.2.2 Suspend movement of irradiated Immediately fuel assemblies.

AND A.2.3 Suspend operations involving Immediately positive reactivity additions that could result in loss of required SDM or boron concentration.

AND (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-38 Amendment No.

Distribution Systems -- Shutdown 3.8.10 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.2.4 Initiate actions to restore required Immediately AC, DC, and AC vital bus electrical power distribution subsystems to OPERABLE status.

AND A.2.5 Declare associated required Immediately residual heat removal subsystem(s) inoperable and not in operation.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.10.1 Verify correct breaker alignments and voltage to required 7 days AC, DC, and AC vital bus electrical power distribution subsystems.

COMANCHE PEAK - UNITS 1 AND 2 3.8-39 Amendment No.

Boron Concentration 3.9.1 3.9 REFUELING OPERATIONS 3.9.1 Boron Concentration LCO 3.9.1 Boron concentrations of all filled portions of the Reactor Coolant System, the refueling canal, and the refueling cavity, that have direct access to the reactor vessel, shall be maintained within the limit specified in the COLR.

While this LCO is not met, entry into MODE.6 from MODE 5 is not permitted.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME

A. Boron concentration not A.1 Suspend CORE ALTERATIONS. Immediately within limit.

AND A.2 Suspend positive reactivity additions. Immediately AND A.3 Initiate action to restore boron Immediately concentration to within limit.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.1.1 Verify boron concentration is within the limit specified in the 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months COLR COMANCHE PEAK - UNITS 1 AND 2 3.9-1 Amendment No.

Unborated Water Source Isolation Valves 3.9.2 3.9 REFUELING OPERATIONS 3.9.2 Unborated Water Source Isolation Valves LCO 3.9.2 Each valve used to isolate unborated water sources shall be secured in the closed position.

APPLICABILITY: MODE 6.

ACTIONS

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

Separate Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIME A. -------- NOTE-------

Required Action A.4 must be completed whenever Condition A is entered.

One or more valves not A.1 Suspend CORE ALTERATIONS. Immediately secured in closed position.

AND A.2 Suspend positive reactivity addition. Immediately AND A.3 Initiate actions to secure valve in Immediately closed position.

AND A.4 Perform SR 3.9.1.1. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.9-2 Amendment No.

Unborated Water Source Isolation Valves 3.9.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.2.1 Verify each valve that isolates unborated water sources is 31 days secured in the closed position.

COMANCHE PEAK - UNITS 1 AND 2 3.9-3 Amendment No.

Nuclear Instrumentation 3.9.3 3.9 REFUELING OPERATIONS 3.9.3 Nuclear Instrumentation LCO 3.9.3 Two source range neutron flux monitors shall be OPERABLE.

APPLICABILITY: MODE 6.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One required source range A.1 Suspend CORE ALTERATIONS. Immediately neutron flux monitor inoperable. AND A.2 Suspend operations that would Immediately cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

B. Two required source range B.1 Initiate action to restore one source Immediately neutron flux monitors range neutron flux monitor to inoperable. OPERABLE status.

AND B.2 Perform SR 3.9.1.1. Once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.9-4 Amendment No.

Nuclear Instrumentation 3.9.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.3.1 Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months SR 3.9.3.2 ------------------------- NOTE-- ------------------------------

Neutron detectors are excluded from CHANNEL CALIBRATION.

Perform CHANNEL CALIBRATION. 18 months COMANCHE PEAK - UNITS 1 AND 2 3.9-5 Amendment No.

Containment Penetrations 3.9.4 3.9 REFUELING OPERATIONS 3.9.4 Containment Penetrations LCO 3.9.4 The containment penetrations shall be in the following status:

a. The equipment hatch closed and held in place by four bolts, or if open, capable of being closed;

b. One door in the emergency air lock closed and one door in the personnel airlock capable of being closed; and

c. Each penetration providing direct access from the containment atmosphere to the outside atmosphere either:

1. closed by a manual or automatic isolation valve, blind flange, or equivalent, or

2. capable of being closed by an OPERABLE containment ventilation isolation valve.

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

Penetration flow path(s) providing direct access from the containment atmosphere to the outside atmosphere may be unisolated under administrative controls.

APPLICABILITY: During CORE ALTERATIONS, During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One or more containment A.1 Suspend-CORE ALTERATIONS. Immediately penetrations not in required status. AND A.2 Suspend movement of irradiated fuel Immediately assemblies within containment.

COMANCHE PEAK - UNITS 1 AND 2 3.9-6 Amendment No.

Containment Penetrations 3.9.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.4.1 Verify each required containment penetration is in the 7 days required status.

SR 3.9.4.2 ------------------------ NOTE -----------------

Only required for an open equipment hatch Verify the capability to install the equipment hatch. 7 days SIR 3.9.4.3 Verify each required containment ventilation isolation 18 months valve actuates to the isolation position on an actual or simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.9-7 Amendment No.

RHR and Coolant Circulation -- High Water Level 3.9.5 3.9 REFUELING OPERATIONS 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation -- High Water Level LCO 3.9.5 One RHR loop shall be OPERABLE and in operation.

-----------------------------,IjI r,- - - - - - - - - - -- - - - - - - - - - - -

The required RHR loop may be removed from operation for < 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months per 8 hour9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months period, provided no operations are permitted that would cause introduction of coolant into the Reactor Coolant System with boron concentration less than that required to meet the minimum required boron concentration of LCO 3.9.1.

APPLICABILITY: MODE 6 with the water level Ž_23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. RHR loop requirements not A.1 Suspend operations that would Immediately met. cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

AND A.2 Suspend loading irradiated fuel Immediately assemblies in the core.

AND A.3 Initiate action to satisfy RHR loop Immediately requirements.

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

COMANCHE PEAK - UNITS 1 AND 2 3.9-8 Amendment No.

RHR and Coolant Circulation -- High Water Level 3.9.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.5.1 Verify one RHR loop is in operation and circulating reactor 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months coolant at a flow rate of >_3800 gpm.

COMANCHE PEAK - UNITS 1 AND 2 3.9-9 Amendment No.

RHR and Coolant Circulation -- Low Water Level 3.9.6 3.9 REFUELING OPERATIONS 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation -- Low Water Level LCO 3.9.6 Two RHR loops shall be OPERABLE, and one RHR loop shall be in operation.

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

While this LCO is not met, entry into a MODE or other specified condition in the Applicability is not permitted.

APPLICABILITY: MODE 6 with the water level < 23 ft above the top of reactor vessel flange.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Less than the required A.1 Initiate action to restore required Immediately number of RHR loops RHR loops to OPERABLE status.

OPERABLE.

OR A.2 Initiate action to establish _>23 ft Immediately of water above the top of reactor vessel flange.

(continued)

COMANCHE PEAK-UNITS 1 AND 2 3.9-10 Amendment No.

RHR and Coolant Circulation -- Low Water Level 3.9.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. No RHR loop in operation. B.1 Suspend operations that would Immediately cause introduction of coolant into the RCS with boron concentration less than required to meet the boron concentration of LCO 3.9.1.

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

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

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.6.1 Verify one RHR loop is in operation and circulating reactor 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months coolant at a flow rate of > 1000 gpm.

SR 3.9.6.2 Verify correct breaker alignment and indicated power 7 days available to the required RHR pump that is not in operation.

COMANCHE PEAK - UNITS 1 AND 2 3.9-11 Amendment No.

Refueling Cavity Water Level 3.9.7 3.9 REFUELING OPERATIONS 3.9.7 Refueling Cavity Water Level LCO 3.9.7 Refueling cavity water level shall be maintained _> 23 ft above the top of reactor vessel flange.

APPLICABILITY: During movement of irradiated fuel assemblies within containment.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Refueling cavity water level A.1 Suspend movement of irradiated fuel Immediately not within limit, assemblies within containment.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.9.7.1 Verify refueling cavity water level is _ 23 ft above the top of 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months reactor vessel flange.

COMANCHE PEAK - UNITS 1 AND 2 3.9-12 Amendment No.

Design Features 4.0 4.0 DESIGN FEATURES 4.1 Site Location The site area is approximately 7,700 acres located in Somervell County in North Central Texas.

Squaw Creek Reservoir (SCR), established for station cooling, extends into Hood County. The site is situated along Squaw Creek, a tributary of the Paluxy River, which is a tributary of the Brazos River. The site is over 30 miles southwest of the nearest portion of Fort Worth and approximately 4.5 miles north-northwest of Glen Rose, the nearest community.

4.2 Reactor Core 4.2.1 Fuel Assemblies The reactor shall contain 193 fuel assemblies. Each assembly shall consist of a matrix of Zircaloy or ZIRLOTM clad fuel rods with an initial composition of natural or slightly enriched uranium dioxide (U0 2 ) as fuel material. Limited substitutions of zirconium alloy or stainless steel filler rods for fuel rods, in accordance with approved applications of fuel rod configurations, may be used. Fuel assemblies shall be limited to those fuel designs that have been analyzed with applicable NRC staff approved codes and methods and shown by tests or analyses to comply with all fuel safety design bases. A limited number of lead test assemblies that have not completed representative testing or that contain Westinghouse ZIRLOTM fuel rod cladding may be placed in non-limiting core regions.

4.2.2 Control Rod Assemblies The reactor core shall contain 53 control rod assemblies. The control material shall be silver-indium-cadmium as approved by the NRC.

COMANCHE PEAK - UNITS 1 AND 2 4.0-1 Amendment No.

Design Features 4.0 4.0 DESIGN FEATURES (continued) 4.3 Fuel Storage 4.3.1 Criticality 4.3.1.1 The spent fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. keff < 1.0 when fully flooded with unborated water which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

c. keff < 0.95 if fully flooded with water borated to 800 ppm, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

d. A nominal 9 inch center to center distance between fuel storage locations in Region II storage racks;

e. A nominal 10.6 inch by nominal 11 inch center to center distance between fuel assemblies placed in Region I fuel storage racks;

f. New or partially spent fuel assemblies may be allowed restricted storage in a 1 out of 4 configuration in Region II fuel storage racks (as shown in Figure 3.7.17-4) or unrestricted storage in Region I fuel storage racks;

g. New or partially spent fuel assemblies with a discharge burnup in the "acceptable" domain of Figure 3.7.17-1 may be allowed unrestricted storage in a 4out of 4 configuration in Region II fuel storage racks as shown in Figure 3.7.17-4;

h. New or partially spent fuel assemblies with a discharge burnup in the "acceptable" domain of Figure 3.7.17-2 may be allowed restricted storage in a 3 out of 4 configuration in Region II fuel storage racks as shown in Figure 3.7.17-4; and New or partially spent fuel assemblies with a discharge burnup in the "acceptable" domain of Figure 3.7.17-3 may be allowed restricted storage in a 2 out of 4 configuration in Region II fuel storage racks as shown in Figure 3.7.17-4.

COMANCHE PEAK - UNITS 1 AND 2 4.0-2 Amendment No.

Design Features 4.0 4.0 DESIGN FEATURES 4.3 Fuel Storage (continued) 4.3.1.2 The new fuel storage racks are designed and shall be maintained with:

a. Fuel assemblies having a maximum U-235 enrichment of 5.0 weight percent;

b. keff < 0.95 if fully flooded with unborated water, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR;

c. keff < 0.98 if moderated by aqueous foam, which includes an allowance for uncertainties as described in Section 4.3 of the FSAR; and

d. A nominal 21 inch center to center distance between fuel assemblies placed in the storage racks.

4.3.2 Drainage The spent fuel storage pools are designed and shall be maintained to prevent inadvertent draining of the pool below elevation 854 ft.

4.3.3 Capacity The spent fuel storage pools are designed and shall be maintained with a storage capacity limited to no more than 3373 fuel assemblies.

COMANCHE PEAK - UNITS 1 AND 2 4.0-3 Amendment No.

Responsibility 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Plant Manager shall be responsible for overall unit operation and shall delegate in writing the succession to this responsibility during hisabsence.

The Plant Manager or his designee shall approve, prior to implementation, each proposed test, experiment or modification to systems or equipment that affect nuclear safety.

5.1.2 The Shift Manager shall be responsible for the control room command function.

During any absence of the Shift Manager from the control room while the unit is in MODE 1, 2, 3, or 4, an individual with an active Senior Reactor Operator (SRO) license shall be designated to assume the control room command function. During any absence of the Shift Manager from the control room while the unit is in MODE 5 or 6, an individual with an active SRO license or Reactor Operator license shall be designated to assume the control room command function.

COMANCHE PEAK - UNITS 1 AND 2 5.1-1 Amendment No.

Organization 5.2 5.0 ADMINISTRATIVE CONTROLS 5.2 Organization 5.2.1 Onsite and Offsite Organizations Onsite and offsite organizations shall be established for unit operation and corporate management, respectively. The onsite and offsite organizations shall include the positions for activities affecting safety of the nuclear power plant.

a. Lines of authority, responsibility, and communication shall be defined and established throughout highest management levels, intermediate levels, and all operating organization positions. These relationships shall be documented and updated, as appropriate, in organization charts, functional descriptions of departmental responsibilities and relationships, and job descriptions for key personnel positions, or in equivalent forms of documentation. These requirements including the plant-specific titles of those personnel fulfilling the responsibilities of the positions delineated in these Technical Specifications shall be documented in the FSAR;

b. The Plant Manager shall be responsible for overall safe operation of the plant and shall have control over those onsite activities necessary for safe operation and maintenance of the plant;

c. A specified corporate officer shall have corporate responsibility for overall plant nuclear safety and shall take any measures needed to ensure acceptable performance of the staff in operating, maintaining, and providing technical support to the plant to ensure nuclear safety; and

d. The individuals who train the operating staff, carry out health physics, or perform quality assurance functions may report to the appropriate onsite manager; however, these individuals shall have sufficient organizational freedom to ensure their independence from operating pressures.

5.2.2 Unit Staff The unit staff organization shall include the following:

a. A non-licensed operator shall be assigned to each reactor containing fuel and an additional non-licensed operator shall be assigned ifeither unit is operating in MODES 1, 2, 3, or 4.

With both units shutdown or defueled, a total of three non-licensed operators for the two units is required.

COMANCHE PEAK - UNITS 1 AND 2 5.2-1 Amendment No.

Organization 5.2 5.2 Organization 5.2.2 Unit Staff (continued)

b. Shift crew composition may be one less than the minimum requirement of 10 CFR 50.54(m)(2)(i) and 5.2.2.a and 5.2.2.f for a period of time not to exceed 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months in order to accommodate unexpected absence of on-duty shift crew members provided immediate action is taken to restore the shift crew composition to within the minimum requirements.

c. - --------------------------- NOTE -------------------------

A single Radiation Protection Technician and a single Chemistry Technician may fulfill the requirements for both units.

A Radiation Protection Technician and Chemistry Technician shall be on site when fuel is in the reactor. The positions may be vacant for not more than 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , in order to provide for unexpected absence, provided immediate action is taken to fill the required positions.

d. Administrative procedures shall be developed and implemented to limit the working hours of personnel who perform safety related functions (e.g.,

licensed Senior Reactor Operators (SROs), licensed Reactor Operators (ROs), Radiation Protection Technicians, auxiliary operators, and key maintenance personnel).

The controls shall include guidelines on working hours that ensure adequate shift coverage shall be maintained without routine heavy use of overtime. Any deviation from the above guidelines shall be authorized in advance by the Plant Manager or the Plant Manager's designee, in accordance with approved administrative procedures, and with documentation of the basis for granting the deviation. Routine deviation from the working hour guidelines shall not be authorized. Controls shall be included in the procedures to require a periodic independent review be conducted to ensure that excessive hours have not been assigned.

e. The Shift Operations Manager shall hold an SRO license.

f. An individual shall provide advisory technical support to the unit operations shift crew in the areas of thermal hydraulics, reactor engineering, and plant analysis with regard to the safe operation of the unit. This shall be assigned to both units when either unit is in MODE 1, 2, 3, or 4. The STA position may be filled by the shift manager or an on-shift SRO providing the individuals meet the dual role qualifications specified by the Commission Policy Statement on Engineering Expertise on.Shift.

COMANCHE PEAK - UNITS 1 AND 2 5.2-2 Amendment No.

Unit Staff Qualifications 5.3 5.0 ADMINISTRATIVE CONTROLS 5.3 Unit Staff Qualifications 5.3.1 Each member of the unit staff, with the exception of licensed Senior Reactor Operators (SRO) and licensed Reactor Operators (RO),ý shall meet or exceed the minimum qualifications of Regulatory Guide 1.8, Revision 2, 1987.

5.3.2 Licensed Senior Reactor Operators (SRO) and licensed Reactor Operators (RO) shall meet or exceed the minimum qualifications of Regulatory Guide 1.8, Revision 3, May 2000.

5.3.3 For the purposes of 10CFR55.4, a licensed Senior Reactor Operator (SRO) and a licensed reactor operator (RO) are those individuals who, in addition to meeting the requirements of TS 5.3.2, perform the functions described in 10CFR50.54(m).

COMANCHE PEAK - UNITS 1 AND 2 5.3-1 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 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.

COMANCHE PEAK - UNITS 1 AND 2 5.4-1 Amendment No.

Programs and Manuals 5.5 5.0 ADMINISTRATIVE CONTROLS 5.5 Programs and Manuals The following programs shall be established, implemented, and maintained.

5.5.1 Offsite Dose Calculation Manual (ODCM)

a. The ODCM shall contain the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring alarm and trip setpoints, and in the conduct of the radiological environmental monitoring program; and

b. The ODCM shall also contain the radioactive effluent controls and radiological environmental monitoring activities, and descriptions of the information that should be included in the Annual Radiological Environmental Operating, and Radioactive Effluent Release Report required by Specification 5.6.2 and Specification 5.6.3.

c. Licensee initiated changes to the ODCM:

1. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

sufficient information to support the change(s) together with the appropriate analyses or evaluations justifying the change(s),

and ii. a determination that the change(s) maintain the levels of radioactive effluent control required by 10 CFR 20.1302, 40 CFR 190, 10 CFR 50.36a, and 10 CFR 50, Appendix I, and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations;

2. Shall become effective after the approval of the Plant Manager; and

3. Shall be submitted to the NRC in the form of a complete, legible copy of the entire ODCM as a part of or concurrent with the Radioactive Effluent Release Report for the period of the report in which any change in the ODCM was made. Each change shall be identified by markings in the margin of the affected pages, clearly indicating the area of the page that was changed, and shall indicate the date (i.e.,

month and year) the change was implemented.

COMANCHE PEAK - UNITS 1 AND 2 5.5-1 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.2 Primary Coolant Sources Outside Containment This program provides controls to minimize leakage from those portions of systems outside containment that could contain highly radioactive fluids during a serious transient or accident to levels as low as practicable. The systems include the post accident recirculation portion of the Containment Spray System, Safety Injection System, Chemical and Volume Control System, RHR System and RCS Sampling System (Post Accident Sampling System portion only until such time as a modification eliminates the PASS penetration as a potential leakage path). The program shall include the following:

a. Preventive maintenance and periodic visual inspection requirements; and

b. Integrated leak test requirements for each system at refueling cycle intervals or less.

5.5.3 Not Used 5.5.4 Radioactive Effluent Controls Program This program conforms to 10 CFR 50.36a for the control of radioactive effluents and for maintaining the doses to members of the public from radioactive effluents as low as reasonably achievable. The program shall be contained in the ODCM, shall be implemented by procedures, and shall include remedial actions to be taken whenever the program limits are exceeded. The program shall include the following elements:

a. Limitations on the functional capability of radioactive liquid and gaseous monitoring instrumentation including surveillance tests and setpoint determination in accordance with the methodology in the ODCM;

b. Limitations on the concentrations of radioactive material released in liquid effluents to unrestricted areas, conforming to 10 times the concentration values in Appendix B, Table 2, Column 2, to 10 CFR 20.1001 - 20.2402;

c. Monitoring, sampling, and analysis of radioactive liquid and gaseous effluents in accordance with 10 CFR 20.1302 and with the methodology and parameters in the ODCM;

d. Limitations on the annual and quarterly doses or dose commitment to a member of the public from radioactive materials in liquid effluents released from each unit to unrestricted areas, conforming to 10 CFR 50, Appendix I;

e. Determination of cumulative and projected dose contributions from radioactive effluents for the current calendar quarter and current calendar year in accordance with the methodology and parameters in the ODCM at least every 31 days; COMANCHE PEAK - UNITS 1 AND 2 5.5-2 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.4 Radioactive Effluent Controls Program (continued)

f. Limitations on the functional capability and use of the liquid and gaseous effluent treatment systems to ensure that appropriate portions of these systems are used to reduce releases of radioactivity when the projected doses in a period of 31 days would exceed 2% of the guidelines for the annual dose or dose commitment, conforming to 10 CFR 50, Appendix I;

g. Limitations on the dose rate resulting from radioactive material released in gaseous effluents from the site to areas at or beyond the site boundary shall be in accordance with the following:

1. For noble gases: a dose rate of < 500 mrem/yr to the total body and a dose rate of < 3000 mrem/yr to the skin, and

2. For iodine-1 31, for iodine-1 33, for tritium, and for all radionuclides in particulate form with half lives greater than 8 days: a dose rate < 1500 mrem/yr to any organ.

h. Limitations on the annual and quarterly air doses resulting from noble gases released in gaseous effluents from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; Limitations on the annual and quarterly doses to a member of the public, beyond the site boundary, from iodine-1 31, iodine-1 33, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluents released from each unit to areas beyond the site boundary, conforming to 10 CFR 50, Appendix I; and'

j. Limitations on the annual dose or dose commitment to any member of the public due to releases of radioactivity and to radiation from uranium fuel cycle sources, conforming to 40 CFR 190.

k. The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Radioactive Effluent Controls program surveillance frequency.

5.5.5 Component Cyclic or Transient Limit This program provides controls to track the FSAR, Section 3.9N, cyclic and transient occurrences to ensure that components are maintained within the design limits.

5.5.6 Not used COMANCHE PEAK - UNITS 1 AND 2 5.5-3 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.7 Reactor Coolant Pump Flywheel Inspection Proaram This program shall provide for the inspection of each reactor coolant pump flywheel per the recommendations of Regulatory Position C.4.b of Regulatory Guide 1.14, Revision 1, August 1975. In lieu of Position C.4.b(1) and C.4.b(2), a qualified in-place UT examination over the volume from the inner bore of the flywheel to the circle one-half of the outer radius or a surface examination (MT and/or PT) of exposed surfaces of the removed flywheels may be conducted at 20 year intervals.

5.5.8 Inservice Testing Program This program provides controls for inservice testing of ASME Code Class 1, 2, and 3 components. The program shall include the following:

a. Testing frequencies applicable to the ASME Code for Operations and Maintenance of Nuclear Power Plants (ASME OM Code) and applicable Addenda as follows:

Required Frequencies for ASME OM Code and applicable Addenda performing inservice testing terminology for inservice testing activities activities Weekly At least once per 7 days Monthly At least once per 31 days Quarterly or every 3 months At least once per 92 days Semiannually or every 6 months At least once per 184 days Every 9 months At least once per 276 days Yearly or annually At least once per 366 days Biennially or, every 2 years At least once per 731 days

b. The provisions of SR 3.0.2 are applicable to the above required Frequencies and to other normal and accelerated Frequencies specified as 2 years or less in the Inservice Testing Program for performing inservice testing activities;

c. The provisions of SR 3.0.3 are applicable to inservice testing activities; and

d. Nothing in the ASME OM Code shall be construed to supersede the requirements of any TS.

COMANCHE PEAK - UNITS 1 AND 2 5.5-4 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.9 Unit 1 Model D76 and Unit 2 Model D5 Steam Generator (SG) Program A Steam Generator Program shall be established and implemented to ensure that SG tube integrity is maintained. In addition, the Steam Generator Program shall include the following provisions:

a. Provisions for condition monitoring assessments. Condition monitoring assessment means an evaluation of the "as found" condition of the tubing with respect to the performance criteria for structural integrity and accident induced leakage. The "as-found" condition refers to the condition of the tubing during an SG inspection outage, as determined from the inservice inspection results or by other means, prior to the plugging of tubes. Condition monitoring assessments shall be conducted during each outage during which the SG.

tubes are inspected or plugged to confirm that the performance criteria are being met.

b. Performance criteria for SG tube integrity. SG tube integrity shall be maintained, by meeting the performance criteria for tube structural integrity, accident induced leakage, and operational LEAKAGE.

1. Structural integrity performance criterion: All in-service steam generator tubes shall retain structural integrity over the full range of normal operating conditions (including startup, operation in the power range, hot standby, and cool down and all anticipated transients included in the design specification) and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary-to-secondary pressure differential and a safety factor of 1.4 against burst applied to the design basis accident primary-to-secondary pressure differentials. Apart from the above requirements, additional loading conditions associated with the design basis accidents, or combination of accidents in accordance with the design and licensing basis, shall also be evaluated to determine if the associated loads contribute significantly to burst or collapse. In the assessment of tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with the loads due to pressure with a safety factor of 1.2 on the combined primary loads and 1.0 on axial secondary loads.

2. Accident induced leakage performance criterion: The primary to secondary accident induced leakage rate for any design basis accident, other than a SG tube rupture, 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 1 gpm per SG.

3. The operational LEAKAGE performance criterion is specified in LCO 3.4.13, "RCS Operational LEAKAGE."

COMANCHE PEAK - UNITS 1 AND 2 555AmnetNo 5.5-5 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Unit 1 Model D76 and Unit 2 Model D5 Steam Generator (SG) Program (continued)

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 below, the inspection scope, inspection methods and inspection interals 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. For the Unit 2 model D5 steam generators (Alloy 600 thermally treated) inspect 100% of the tubes at sequential periods of 120, 90, 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 48 effective full power months or two refueling outages (whichever is less) without being inspected.

3. For the Unit 1 model Delta-76 steam generators (Alloy 690 thermally treated) 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.

4. If crack indications are found in any SG tube, then the next inspection for each SG for the degradation mechanism that caused the crack indications shall not exceed 24 effective full power months or one refueling outage (whichever is less). If definitive information, such as COMANCHE PEAK- UNITS 1 AND 2 5.5-6 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Unit 1 Model D76 and Unit 2 Model D5 Steam Generator (SG) Program (continued) 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.

5.5.10 Secondary Water Chemistry Program This program provides controls for monitoring secondary water chemistry to inhibit SG tube degradation and low pressure turbine disc stress corrosion cracking. The program shall include:

a. Identification of a sampling schedule for the critical variables and control points for these variables;

b. Identification of the procedures used to measure the values of the critical variables;

c. Identification of process sampling points, which shall include monitoring the discharge of the condensate pumps for evidence of condenser in leakage;

d. Procedures for the recording and management of data;

e. Procedures defining corrective actions for all off control point chemistry conditions; and

f. A procedure identifying the authority responsible for the interpretation of the data and the sequence and timing of administrative events, which is required to initiate corrective action.,

COMANCHE PEAK - UNITS 1 AND 2 5.5-7 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testing Program (VFTP)

A program shall be established to implement the following required testing of Engineered Safety Feature (ESF) filter ventilation systems at the frequencies specified in Regulatory Guide 1.52, Revision 2 and in accordance with Regulatory Guide 1.52, Revision 2, ANSI/ASME N509-1980, ANSI/ASME N510-1980, and ASTM D3803-1989.

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

ANSI/ASME N510-1980, ANSI/ASME N509-1980, and ASTM D3803-1989 shall be used in place of ANSI 510-1975, ANSI/ASME N509-1976, and ASTM D3803-1979 respectively in complying with Regulatory Guide 1.52, Revision 2.

a. Demonstrate for each of the ESF systems that an inplace test of the high efficiency particulate air (HEPA) filters shows a penetration and system bypass < 1.0% for Primary Plant Ventilation System - ESF Filtration units and

< 0.05% for all other units when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI/ASME N510-1980 at the system flowrate specified.

below +/- 10%.

ESF Ventilation System Flowrate Control Room Emergency filtration unit 8,000 CFM Control Room Emergency pressurization unit 800 CFM Primary Plant Ventilation System - ESF 15,000 CFM filtration unit

b. Demonstrate for each of the ESF systems that an inplace test of the charcoal adsorber shows a penetration and system bypass < 1.0% for Primary Plant Ventilation System - ESF Filtration units and < 0.05% for all other units when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI/

ASME N510-1980 at the system flowrate specified below + 10%.

ESF Ventilation System Flowrate Control Room Emergency filtration unit 8,000 CFM Control Room Emergency pressurization unit 800 CFM Primary Plant Ventilation System - ESF 15,000 CFM filtration unit COMANCHE PEAK - UNITS 1 AND 2 5.5-8 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.11 Ventilation Filter Testing Program (VFTP) (continued)

c. Demonstrate for each of the ESF systems that a laboratory test of a sample of the charcoal adsorber, when obtained as described in Regulatory Guide 1.52, Revision 2, shows the methyl iodide penetration less than the value specified below when tested in accordance with ASTM D3803-1989 at a temperature of

< 300C and greater than or equal to the relative humidity specified below.

ESF Ventilation Systems Penetration RH Control Room Emergency filtration unit 0.5% 70%

Control Room Emergency pressurization unit 0.5% 70%

Primary Plant Ventilation System - ESF 2.5% 70%

filtration unit

d. Demonstrate at least once per 18 months for each of the ESF systems that the pressure drop across the combined HEPA filters, the prefilters, and the charcoal adsorbers is less than the value specified below when tested in accordance with Regulatory Guide 1.52, Revision 2, and ANSI/ASME N510-1980 at the system flowrate specified below + 10%

ESF Ventilation System Delta P Flowrate Control Room Emergency filtration unit 8.0 in WG .8000 CFM Control Room Emergency pressurization unit 9.5 in WG 800 CFM Primary Plant Ventilation System - ESF 8.5 in WG 15000 CFM filtration unit.

e. Demonstrate at least once per 18 months that the heaters for each of the ESF systems dissipate the value specified below when tested in accordance with ANSI/ASME N510-1980.

ESF Ventilation System Wattage Control Room Emergency pressurization unit 10 +/- 1 kW Primary Plant Ventilation System - ESF filtration unit 100 +/- 5 kW The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the VFTP test frequencies.

COMANCHE PEAK - UNITS 1 AND 2 5.5-9. Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.12 Explosive Gas and Storage Tank Radioactivity Monitoring Program This program provides controls for potentially explosive gas mixtures contained in the Gaseous Waste Processing System, the quantity of radioactivity contained in each Gas Decay Tank, and the quantity of radioactivity contained in unprotected outdoor liquid storage tanks.

The gaseous radioactivity quantities shall be determined following the methodology in Branch Technical Position (BTP) ETSB 11-5, "Postulated Radioactive Release due to Waste Gas System Leak or Failure," Revision 0, July 1981. The liquid radwaste quantities shall be determined in accordance with Standard Review Plan, Section 15.7.3, "Postulated Radioactive Release due to Tank Failures," Revision 2, July 1981.

The program shall include:

a. The limits .for concentrations of hydrogen and oxygen in the Gaseous Waste Processing System and a surveillance program to ensure the limits are maintained. Such limits shall be appropriate to the system's design criteria (i.e., whether or not the system is designed to withstand a hydrogen explosion);

b. A surveillance program to ensure that the quantity of radioactivity contained in each Gas Decay Tank is less than the amount that would result in a whole body exposure of _>0.5 rem to any individual in an unrestricted area, in the event of an uncontrolled release of the tanks' contents; and

c. A-surveillance program to ensure that the quantity of radioactivity contained in all outdoor liquid radwaste tanks that are not surrounded by liners, dikes, or walls, capable of holding the tanks' contents and that do not have tank overflows and surrounding area drains connected to the Liquid Radwaste Treatment System is less than the amount that would result in concentrations less than the limits of 10 CFR 20, Appendix B, Table 2, Column 2 to 10 CFR 20.1001 - 20.2402, at the nearest potable water supply and the nearest surface water supply in an unrestricted area, in the event of an uncontrolled release of the tanks' contents.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Explosive Gas and Storage Tank Radioactivity Monitoring Program surveillance frequencies.

COMANCHE PEAK - UNITS 1 AND 2 5.5-10 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.13 Diesel Fuel Oil Testing Program A diesel fuel oil testing program to implement required testing of both new fuel oil and stored fuel oil shall be established. The program shall include sampling and testing requirements, and acceptance criteria, all in accordance with applicable ASTM Standards. The purpose of the program is to establish the following:

a. Acceptability of new fuel oil for use prior to addition to storage tanks by determining that the fuel oil has:

1. an API gravity or an absolute specific gravity within limits,

2. a flash point and kinematic viscosity within limits for ASTM 2D fuel oil, and

3. a clear and bright appearance with proper color; or water and sediment content within limits.

b. Within 31 days following addition of the new fuel oil to the storage tanks, verify that the properties of the new fuel oil, other than those addressed in a., above, are within limits for ASTM 2D fuel oil, and

c. Total particulate concentration of the fuel oil is < 10 mg/I when tested every 31 days.

The provisions of SR 3.0.2 and SR 3.0.3 are applicable to the Diesel Fuel Oil Testing Program.

5.5.14 Technical Specifications (TS) Bases Control Program-This program provides a means for processing changes to the Bases of these Technical Specifications.

a. Changes to the Bases of the TS shall be made under appropriate administrative controls and reviews.

b. Licensees may make changes to Bases without prior NRC approval provided the changes do not require either-of the following:

1. a change in the TS incorporated in the license; or

2. a change to the updated FSAR or Bases that requires NRC approval pursuant to 10 CFR 50.59.

c. The Bases Control Program shall contain provisions to ensure that the Bases are maintained consistent with the FSAR.

COMANCHE PEAK --UNITS 1 AND 2 5.5-11 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.14 Technical Specifications (TS) Bases Control Program (continued)

d. Proposed changes that meet the criteria of Specification 5.5.14b above shall be reviewed and approved by the NRC prior to implementation. Changes to the Bases implemented without prior NRC approval shall be provided to the NRC on a frequency consistent with 10 CFR 50.71(e) and exemptions thereto.

5.5.15 Safety Function Determination Program (SFDP)

a. This program ensures loss of safety function is detected and appropriate actions taken. Upon'entry into LCO 3.0.6, an evaluation shall be made to determine if loss of safety function exists. Additionally, other appropriate actions may be taken as a result of the support system inoperability and corresponding exception to entering supported system Condition and Required Actions. This program implements the requirements of LCO 3.0.6.

The SFDP shall contain the following:

1. Provisions for cross train checks to ensure a loss of the capability to perform the safety function assumed in the accident analysis does not go undetected;

2. Provisions for ensuring the plant is maintained in a safe condition if a loss of function condition exists;

3. Provisions to ensure that an inoperable supported system's Completion Time is not inappropriately extended as a result of multiple support system inoperabilities; and

4. Other appropriate limitations and remedial or compensatory actions.

b. A loss of safety function exists when, assuming no concurrent single failure, a safety function assumed in the accident analysis cannot be performed. For the purpose of this program, a loss of safety function may exist when a support system is inoperable, and:

1. A required system redundant to the system(s) supported by the inoperable support system is also inoperable; or

2. A required system redundant to the system(s) in turn supported by the inoperable supported system is also inoperable; or

3. A required system redundant to the support system(s) for the supported systems (a) and (b).above is also inoperable.

c. The SFDP identifies where a loss of safety function exists. If a loss of safety function is determined to exist by this program, the appropriate Conditions and Required Actions of the LCO in which the loss of safety function exists are required to be entered.

COMANCHE PEAK - UNITS 1 AND 2 5.5-12 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Containment Leakage Rate Testing Program

a. A program shall be established to implement the leakage rate testing of the containment as required by 10 CFR 50.54(o) and 10 CFR 50, Appendix J, Option B, as modified by approved exemptions. This program shall be in accordance with the guidelines contained in Regulatory Guide 1.163, "Performance-Based Containment Leak-Test Program, dated September, 1995" as modified by the following exceptions:

1. The visual examination of containment concrete surfaces intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B testing, will be performed in accordance with the requirements of and frequency specified by the ASME Section XI Code, Subsection IWL, except where relief has been authorized by the NRC.

2. The visual examination of the steel liner plate inside containment intended to fulfill the requirements of 10 CFR 50, Appendix J, Option B, will be performed in accordance with the requirements of and frequency specified by the ASME Section Xl Code, Subsection IWE, except where relief has been authorized by the NRC.

3. NEI 94 1995, Section 9.2.3: The first Type A Test performed after the December 7, 1993 Type A Test (Unit 1) and the December 1, 1997 Type A Test (Unit 2) shall be performed no later than December 15, 2008 (Unit 1) and December 9, 2012 (Unit 2)."

b.. The peak calculated containment internal pressure for the design basis loss of coolant accident, Pa, is 48.3 psig.

c. The maximum allowable containment leakage rate, La, at Pa, shall be 0.10%

of containment air weight per day.

d. Leakage rate acceptance criteria are:

1. Containment leakage rate acceptance criteria is < 1.0 La. During the first unit startup following testing in accordance with this program, the leakage rate acceptance criteria are < 0.60 La for the Type B and Type C tests and < 0.75 La for Type A tests;

2. Air lock testing acceptance criteria are:

Overall air lock leakage rate is < 0.05 La when tested at Pa-ii. For each door, leakage rate is *0.01 La when pressurized to

>Pa COMANCHE PEAK - UNITS 1 AND 2 5.5-13 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.16 Containment Leakage Rate Testing Program (continued)

e. The provision of SR 3.0.2 do not apply to the test frequencies specified in the Containment Leakage Rate Testing Program, with the exception of the containment ventilation isolation valves.

f. The provisions of SR 3.0.3 are applicable to the Containment Leakage Rate Testing Program.

5.5.17 Technical Requirements Manual (TRM)

The TRM contains selected requirements which do not meet the criteria for inclusion in the Technical Specification but are important to the operation of CPNPP. Much of the information in the TRM was relocated from the TS.

Changes to the TRM shall be made under appropriate administrative controls and reviews. Changes may be made to the TRM without prior NRC approval provided the changes do not require either a change to the TS or NRC approval pursuant to 10 CFR 50.59. TRM changes require approval of the Plant Manager.

5.5.18 Configuration Risk Management Program (CRMP)

The Configuration Risk Management Program (CRMP) provides a proceduralized risk-informed assessment to manage the risk associated with equipment inoperability.

The program applies to technical specification structures, systems, or components for which a risk-informed Completion Time has been granted. The program shall include the following elements:

a. Provisions for the control and implementation of a Level 1, at-power, internal events PRA-informed methodology. The assessment shall be capable of evaluating the applicable plant configuration.

b. Provisions for performing an assessment prior to entering the LCO Action for preplanned activities.

c. Provisions for performing an assessment after entering the LCO Action for unplanned entry into the LCO Action.

d. Provisions for assessing the need for additional actions after the discovery of additional equipment out of service conditions while in the LCO Action.

e. Provisions for considering other applicable risk significant contributors such as Level 2 issues, and external events, qualitatively or quantitatively.

COMANCHE PEAK - UNITS 1 AND 2 5.5-14 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.19 Battery Monitoring and Maintenance Program This Program provides for restoration and maintenance, based on the recommendations of IEEE Standard 450, "IEEE Recommended Practice for Maintenance, Testing, and Replacement of Vented Lead-Acid Batteries for Stationary Applications," or of the battery manufacturer for the following:

a. Actions to restore battery cells with float voltage < 2.13 V, and

b. Actions to equalize and test battery cells that had been discovered with electrolyte level below the top of the plates.

5.5.20 Control Room Envelope Habitability Program A Control Room Envelope (CRE) Habitability Program shall be established and implemented to ensure that CRE habitability is maintained such that, with an OPERABLE Control Room Emergency Filtration System (CREFS), CRE occupants can control the reactor safety under normal conditions and maintain it in a safe condition following a radiological event, hazardous chemical release, or a smoke challenge. The program shall ensure that adequate radiation protection is provided to permit access and occupancy of the CRE under design basis accident (DBA) conditions without personnel receiving radiation exposures in excess of 5 rem whole body or its equivalent to any part of the body for the duration of the accident. The program shall include the following elements:

a. The definition of the CRE and the CRE boundary.

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

c. Requirements for (i) determining the unfiltered air inleakage past the CRE boundary into the CRE in accordance with the testing methods and at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, "Demonstrating Control Room Envelope Integrity at Nuclear Power Reactors,"

Revision 0, May 2003, and (ii) assessing CRE habitability at the Frequencies specified in Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0.

The following are exceptions to Sections C.1 and C.2 of Regulatory Guide 1.197, Revision 0:

1. C. - Section 4.3.2 "Periodic CRH Assessment" from NEI 99-03 Revision 1 will be used as input to a site specific Self Assessment procedure.

2. C.1.2 - No peer'reviews are required to be performed.

COMANCHE PEAK - UNITS 1 AND 2 5.5-15 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals (continued) 5.5.20 Control Room Envelope Habitability Program (continued)

d. Measurement, at designated locations, of the CRE pressure relative to all external areas adjacent to the CRE boundary during the pressurization mode of operations by one train of the CREFS, operating at the flow rate required by the VFTP, at a Frequency of 18 months on a STAGGERED TEST BASIS.

The results shall be trended and used as part of the 18 month assessment of the CRE boundary.

e. The quantitative limits on unfiltered air inleakage into the CRE. These limits shall be stated in a manner to allow direct comparison to the unfiltered air inleakage measured by the testing described in paragraph c. The unfiltered air inleakage limit for radiological challenges is the inleakage flow rate assumed in the licensing basis analyses of DBA consequences. Unfiltered air inleakage limits for hazardous chemicals must ensure that exposure of CRE occupants to these hazards will be within the assumptions in the licensing basis.

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

COMANCHE PEAK - UNITS 1 AND 2 5.5-16 Amendment No.

Reporting Requirements 5.6 5.0 ADMINISTRATIVE CONTROLS 5.6 Reporting Requirements The following reports shall be submitted in accordance with 10 CFR 50.4.

5.6.1 Deleted 5.6.2 Annual Radiological Environmental Operating Report

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

A single submittal may be made for a multiple unit station. The submittal should combine sections common to all units at the station.

The Annual Radiological Environmental Operating Report covering the operation of the unit during the previous calendar year shall be submitted by May 1 of each year.

The report shall include summaries, interpretations, and analyses of trends of the results of the radiological environmental monitoring program for the reporting period.

The material provided shall be consistent with the objectives outlined in the Offsite Dose Calculation Manual (ODCM), and in 10 CFR 50, Appendix I, Sections IV.B.2, IV.B.3, and IV.C.

The Annual Radiological Environmental Operating Report shall include the results of analyses of all radiological environmental samples and of all environmental radiation measurements taken during the period pursuant to the locations specified in the table and figures in the ODCM, as well as summarized and tabulated results of these analyses and measurements in a format similar to the table in the Radiological Assessment Branch Technical Position, Revision 1, November 1979. In the event that some individual results are not available for inclusion with the report, the report shall be submitted noting and explaining the reasons for the missing results. The missing data shall be submitted in a supplementary report as soon as possible.

5.6.3 Radioactive Effluent Release Report

NOTE ------------------------------------- 7--------------

A single submittal may be made for a multiple unit station. The submittal shall combine sections common to all units at the station; however, for units with separate radwaste systems, the submittal shall specify the releases of radioactive material from each unit.

The Radioactive Effluent Release Report covering the operation of the unit during the previous year shall be submitted prior to May 1 of each year in accordance with 10 CFR 50.36a. The report shall include a summary of the quantities of radioactive liquid and gaseous effluents and solid waste released from the unit. The material provided shall be consistent with the objectives outlined in the ODCM and Process Control Program and in conformance with 10 CFR 50.36a and 10 CFR Part 50, Appendix I, Section IV.B.1.

5.6.4 Deleted COMANCHE PEAK - UNITS 1 AND 2 5.6-1 Amendment No.

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. Moderator temperature coefficient limits for Specification 3.1.3,

2. Shutdown Rod Insertion Limit for Specification 3.1.5,

3. Control Rod Insertion Limits for Specification 3.1.6,

4. AXIAL FLUX DIFFERENCE Limits and target band for Specification 3.2.3, RTPc

5. Heat Flux Hot Channel Factor, K(Z), W(Z), FQ 0 , and the FQc(Z) allowances for Specification 3.2.1,

6. Nuclear Enthalpy Rise Hot Channel Factor Limit and the Power Factor Multiplier for Specification 3.2.2.

7. SHUTDOWN MARGIN values in Specifications 3.1.1, 3.1.4, 3.1.5, 3.1.6 and 3.1.8.

8. Refueling Boron Concentration limits in Specification 3.9.1.

9. Overtemperature N-1 6 Trip Setpoint in Specification 3.3.1.

10. Reactor Coolant System pressure, temperature, and flow in Specification 3.4.1.

11. Reactor Core Safety Limit (Safety Limit 2.1.1).

b. The analytical methods used to determine the core operating limits shall be those previously reviewed and approved by the NRC. When an initital assumed power level of 102 percent of rated power is specified in a previously approved method, 100.6 percent of rated power may be used only when feedwater flow measurement (used as input for reactor thermal power measurement) is provided by the leading edge flowmeter (LEFM\') as described in document number 20 listed below. When feedwater flow measurements from the LEFM4 are not available, the originally approved initial power level of 102 percent of rated thermal power shall be used.

COMANCHE PEAK - UNITS 1 AND 2 5.6-2 Amendment No.

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

Future revisions of approved analytical methods listed in this technical specification that currently assume 102 percent of rated power shall include the condition given above allowing use of 100.6 percent of rated power in safety analysis methodology when the LEFM4 is used for feedwater flow measurement.

The approved analytical methods are described in the following documents:

1. WCAP-9272-P-A, "WESTINGHOUSE RELOAD SAFETY EVALUATION METHODOLOGY," July 1985 (W Proprietary).

2. WCAP-10216-P-A, Revision 1A, "RELAXATION OF CONSTANT AXIAL OFFSET CONTROL FQ SURVEILLANCE TECHNICAL SPECIFICATION," February 1994 (W Proprietary).

3. Caldon, Inc. Engineering Report-80P, "Improving Thermal Power Accuracy and Plant Safety While Increasing Operating Power level Using the LEFM4 System," Revision 0, March 1997 and Caldon Engineering Report - 160P, "Supplement to Topical Report ER-80P; Basis for a Power Uprate With the LEFM*/tm System," Revision 0, May 2000.

4. WCAP-10444-P-A, "Reference Core Report VANTAGE 5 Fuel Assembly," September1985.

5. WCAP-15025-P-A, "Modified WRB-2 Correlation, WRB-2M, for Predicting Critical Heat Flux in 17xi7 Rod Bundles for Modified LPD Mixing Vane Grids," April 1999.

6. WCAP-1 0360-P-A, "Westinghouse Fuel Assembly Reconstitution Evaluation Methodology," July, 1993.

7. WCAP-1 1397-P-A, "Revised Thermal Design Procedure," April 1989.

8. WCAP-8745-P-A, "Design Bases for the Thermal Overpower AT and Thermal Overtemperature AT Trip Functions," September 1986.

9. WCAP-14565-P-A, "VIPRE-01 Modeling and Qualification for Pressurized Water Reactor Non-LOCA Thermal-Hydraulic Safety Analysis," October 1999.

10. WCAP-14882-P-A, "RETRAN-02 Modeling and Qualification for Westinghouse Pressurized Water Reactor Non-LOCA Safety Analyses," April 1999.

COMANCHE PEAK - UNITS 1 AND 2 5.6-3 Amendment No.

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

11. WCAP-10054-P-A, "Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code," August 1985.

12. WCAP-10054-P-A, Addendum 2, Revision 1, "Addendum to the Westinghouse Small Break ECCS Evaluation Model Using the NOTRUMP Code: Safety Injection into the Broken Loop and COSI Condensation Model," July 1997.

13. WCAP-1 0079-P-A, "NOTRUMP, A Nodal Transient Small Break and General Network Code," August 1985.

14. WCAP-16009-P-A, "Realistic Large-Break LOCA Evaluation Methodology Using the Automated Statistical Treatment of Uncertainty Method (ASTRUM)," January 2005.

15. WCAP-12472-P-A, "BEACON Core Monitoring and Operations Support System," August 1994.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emergency Core Cooling Systems (ECCS) limits, nuclear limits such as SDM, transient analysis limits, and accident analysis limits) of the safety analysis are met.

d. The COLR, including any midcycle revisions or supplements, shall be provided upon issuance for each reload cycle to the NRC.

5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR)

a. RCS pressure and temperature limits for heat up, cooldown, low temperature operation, criticality, and hydrostatic testing, and PORV lift settings as well as heatup and cooldown rates shall be established and documented in the PTLR for the following:

1. Specification 3.4.3, "RCS Pressure and Temperature (P/T) Limits," and

2. Specification 3.4.12, "Low Temperature Overpressure Protection (LTOP) System."

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

COMANCHE PEAK - UNITS 1 AND 2 5.6-4 Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.6 Reactor Coolant System (RCS) PRESSURE AND TEMPERATURE LIMITS REPORT (PTLR) (continued)

1. WCAP-14040-NP-A; "Methodology used to Develop Cold Overpressure Mitigating System Setpoints and RCS Heatup and Cooldown Limit Curves."

c. The PTLR shall be provided to the NRC upon issuance for each reactor vessel fluence period and for any revision or supplement thereto.

5.6.7 Not used 5.6.8 PAM Report When a report is required by the required actions of LCO 3.3.3, "Post Accident Monitoring (PAM) Instrumentation," a report shall be submitted within the following 14 days. The report shall outline the preplanned alternate method of monitoring, the cause of the inoperability, and the plans and schedule for restoring the instrumentation channels of the Function to OPERABLE status.

5.6.9 Unit 1 Model D76 and Unit 2 Model D5 Steam Generator Tube Inspection Report A report shall be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Specification 5.5.9.2, Steam Generator (SG) Program. The report shall include:

a. The scope of inspections performed on each SG,

b. Active degradation mechanisms found,

c. Nondestructive examination techniques utilized for each degradation mechanism,

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications,

e. Number of tubes plugged [or repaired] during the inspection outage for each active degradation mechanism,

f. Total number and percentage of tubes plugged to date, and

g. The results of condition monitoring, including the results of tube pulls and in-situ testing, COMANCHE PEAK - UNITS 1 AND 2 5.6-5 Amendment No.

High Radiation Area 5.7 5.0 ADMINISTRATIVE CONTROLS 5.7 High Radiation Area As provided in paragraph 20.1601(c) of 10 CFR Part 20, the following controls shall be applied to high radiation areas in place of the controls required by paragraph 20.1601 (a) and (b) of 10 CFR Part 20:

5.7.1 High Radiation Areas With Dose Rates Not Exceeding 1.0 rem/hour At 30 Centimeters From The Radiation Source Or From Any Surface Penetrated By The Radiation:

a. Each entryway to such an area shall be barricaded and conspicuously posted as a high radiation area. Such barricades may be opened as necessary to permit entry or exit of personnel or equipment.

b. Access to, and activities in, each such area shall be controlled by means of Radiation Work Permit (RWP) or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures and personnel continuously escorted by such individuals may be exempted from the requirement for an RWP or equivalent while performing their assigned duties provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously displays radiation dose rates in the area; or

2. A radiation monitoring device that continuously integrates the radiation dose rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or

3. A radiation monitoring device that continuously, transmits dose rate information and cumulative dose to a remote receiver monitored by radiation protection personnel responsible for controlling personnel radiation exposure with the area, or

4. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and,

i. Be under the surveillance, as specified in the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or COMANCHE PEAK - UNITS 1 AND 2 5.7-1 Amendment No.

High Radiation Area 5.7 5.7 High Radiation Area 5.7.1 High Radiation Areas With Dose Rates Not Exceeding 1.0 rem/hour At 30 Centimeters From The Radiation Source Or From Any Surface Penetrated By The Radiation (continued) ii. Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with individuals in the area who are covered by such surveillance.

e. Except for individuals qualified in radiation protection procedures, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them.

5.7.2 High Radiation Areas With Dose Rates Greater Than 1.0 rem/hour At 30 Centimeters From The Radiation Source Or From Any Surface Penetrated By The Radiation, But Less Than 500 rads/hour At 1 Meter From The Radiation Source Or From Any Surface Penetrated By The Radiation:

a. Each entryway to such an area shall be conspicuously posted as a high radiation area and shall be provided with a locked or continuously guarded door or gate that prevents unauthorized entry, and, in addition:

1.- All such door and gate keys shall be maintained under the.

administrative control of the [shift manager], or his or her designee.

2. Doors and gates shall remain locked except during periods of personnel or equipment entry or exit.

b. Access to, and activities in, each such area shall be controlled by means of an RWP or equivalent that includes specification of radiation dose rates in the immediate work area(s) and other appropriate radiation protection equipment and measures.

c. Individuals qualified in radiation protection procedures may be exempted from the requirement for an RWP or equivalent while performing radiation surveys in such areas provided that they are otherwise following plant radiation protection procedures for entry to, exit from, and work in such areas.

d. Each individual or group entering such an area shall possess:

1. A radiation monitoring device that continuously integrates the radiation rates in the area and alarms when the device's dose alarm setpoint is reached, with an appropriate alarm setpoint, or COMANCHE PEAK - UNITS 1 AND 2 5.7-2 Amendment No.

High Radiation Area 5.7 5.7 High Radiation Area 5.7.2 High Radiation Areas With Dose Rates Greater Than 1.0 rem/hour At 30 Centimeters-From The Radiation Source Or From Any Surface Penetrated By The Radiation, But Less Than 500 rads/hour At 1 Meter From The Radiation Source Or From Any Surface Penetrated By The Radiation: (continued)

2. A radiation monitoring device that continuously transmits dose rate and cumulative dose information to a remote receiver 'monitored by radiation protection personnel responsible for controlling personnel radiation exposure within the area with the means to communicate with and control every individual in the area, or

3. A self-reading dosimeter (e.g., pocket ionization chamber or electronic dosimeter) and,

i. Be under the surveillance, as specified, in,the RWP or equivalent, while in the area, of an individual qualified in radiation protection procedures, equipped with a radiation monitoring device that continuously displays radiation dose rates in the area; who is responsible for controlling personnel exposure within the area, or ii. Be under the surveillance as specified in the RWP or equivalent, while in the area, by means of closed circuit television, of personnel qualified in radiation protection procedures, responsible for controlling personnel radiation exposure in the area, and with the means to communicate with and control every individual in the area.

4. In those cases where options (2) and (3), above, are impractical or determined to be inconsistent with the Low As is Reasonably Achievable" principle, a radiation monitoring device that continuously displays radiation dose rates in the area.

e. Except for individuals qualified in radiation protection procedures or personnel continuously escorted by such individuals, entry into such areas shall be made only after dose rates in the area have been determined and entry personnel are knowledgeable of them.

f. Such individual areas that are within a larger area , such as PWR containment, where no enclosure exists for the purpose of locking and where no enclosure\can reasonably be constructed around the individual area need not be controlled by a locked door or gate nor continuously guarded, but shall be barricaded, conspicuously posted, and a clearly visible flashing light shall be activated at the area as a warning device.

COMANCHE PEAK - UNITS 1 AND 2 5.7-3 Amendment No.

CP-200900262, License Amendment Request (LAR) 09-001, Administrative Revision to Operating Licenses and Technical Specifications

Contents

Text

SUBJECT:

Dear Sir or Madam:

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

6.0 ENVIRONMENTAL CONSIDERATION

8.0 REFERENCES

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

6.0 ENVIRONMENTAL CONSIDERATION

8.0 REFERENCES

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CP-200900262, License Amendment Request (LAR) 09-001, Administrative Revision to Operating Licenses and Technical Specifications

Text

SUBJECT:

Dear Sir or Madam:

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

6.0 ENVIRONMENTAL CONSIDERATION

8.0 REFERENCES

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

6.0 ENVIRONMENTAL CONSIDERATION

8.0 REFERENCES

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