Text

License Amendment Request (LAR)06-004 Revision to Technical Specification 5.0, Administrative Controls.
	ML060950650
Person / Time
Site:	Comanche Peak
Issue date:	03/31/2006
From:	Madden F; TXU Power
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	00236, CPSES-200600635, TXX-06063
	Download: ML060950650 (351)
	v • d • e

Power TXU Powrer Mike Blevins Ref: 10CFR50.90 Comnanche Peak Steam Senior Vice President &

Electic Station Chief Nuclear Off icer P. O. Box 1002 (EO1)

Glen Rose, TX 76043 Tel: 254 897 5209 Fax: 254 897 6652 mike.blevins@txu.com CPSES-200600635 Log # TXX-06063 File # 00236 March 31, 2006 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)06-004 REVISION TO TECHNICAL SPECIFICATION 5.0, "ADMINISTRATIVE CONTROLS"

Dear Sir or Madam:

Pursuant to IOCFR50.90, TXU Generation Company LP (TXU Power) hereby requests an amendment to the CPSES Unit I Operating License (NPF-87) and CPSES Unit 2 Operating License (NPF-89) by incorporating the attached change into the CPSES Unit I and 2 Technical Specifications (TS). This change request applies to both Units.

The proposed change will revise TS 5.0 entitled " ADMINISTRATIVE CONTROLS".

Specifically, the proposed change would delete the Vice President, Nuclear Operations as an alternative to the Plant Manager for certain functions. In addition, the entire CPSES Unit I and 2 Technical Specifications are being reprinted and reissued as a result of a change in the software application used by TXU Power to produce and maintain the Technical Specifications.

Attachment 1 provides a detailed description of the proposed changes, a technical analysis of the proposed changes, TXU 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 Technical Specification (TS) pages marked-up to reflect the proposed changes. Attachment 3 provides retyped Technical Specification pages which incorporate the requested changes. Attachment 4 provides marked-up pages of the Final Safety Analysis Report (for information only) to reflect the proposed changes to the FSAR. Enclosure I provides the reformatted CPSES Unit I and Unit 2 Technical Specifications in their entirety.

TXU Power requests approval of the proposed License Amendment by September 30, 2006, to be implemented within 120 days of the issuance of the license amendment.

A member of the STARS (Strategic Teaming and Resource Sharing) Alliance Callaway

Comanche Peak

Diablo Canyon

Palo Verde

South Texas Project

Wolf Creek DG2q

TXX-06063 Page 2 of 2 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.

In accordance with IOCFR50.91 (b), TXU 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 March 31, 2006.

Sincerely, TXU Generation Company LP By: TXU Generation Management Company LLC Its General Partner Mike Blevins By: A& 7iL

/Ired W. Madden Director, Regulatory Affairs RAS Attachments 1. Description and Assessment

2. Proposed Technical Specifications Changes

3. Retyped Technical Specification Pages

4. Proposed FSAR Changes (for information) . Reformatted CPSES Unit I and Unit 2 Technical Specifications c - B. S. Mallet, Region IV Ms. Alice K. Rogers Mohan Thadani, NRR Environmental & Consumer Safety Section Resident Inspectors, CPSES Texas Department of State Health Services 1100 West 49th Street Austin, Texas 78756-3189

Attachment I to TXX-06063 Page I of 7 ATTACHMENT I to TXX-06063 DESCRIPTION AND ASSESSMENT

Attachment I to TXX-06063 Page 2 of 7 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 REFERENCES

Attachment I to TXX-06063 Page 3 of 7

1.0 DESCRIPTION

By this letter, TXU Generation Company LP (TXU Power) requests an amendment to the CPSES Unit 1 Operating License (NPF-87) and CPSES Unit 2 Operating License (NPF-

89) by incorporating the attached change into the CPSES Unit I and 2 Technical Specifications (TS). Proposed change LAR 06-004 is a request to revise Technical Specifications 5.0, "ADMINISTRATIVE CONTROLS" for Comanche Peak Steam Electric Station (CPSES) Units I and 2. The proposed change would delete the Vice President, Nuclear Operations as an alternative to the Plant Manager for certain functions. In addition, the entire Technical Specifications are being reprinted and reissued as a result of a change in the software application used by TXU Power to produce and maintain the Technical Specifications.

2.0 PROPOSED CHANGE

The proposed change would revise TS 5.0, "ADMINISTRATIVE CONTROLS" to delete the Vice President, Nuclear Operations as all alternative to the Plant Manager for certain functions. TXU Power is also proposing to reissue the entire Technical Specifications as a result of a change in the software application used by TXU Power to produce and maintain the Technical Specifications.

3.0 BACKGROUND

CPSES Technical Specifications 5.1.1, 5.2.1, 5.2.2, 5.5.1, and 5.5.17 contain provisions which allow either the Vice President, Nuclear Operations or the Plant Manager to perform certain designated duties and responsibilities. When either position is vacant, the other position fulfills the duties and responsibilities of both positions. When neither position is vacant, then the duties and responsibilities of each position are fulfilled by the respective incumbent. Since the CPSES operating organization has matured and TXU Power intends that the Plant Manager will be permanent, this organizational flexibility i!;

no longer necessary.

This change is a result of a change in organizational title for the Vice President, Nuclear Operations to Site Vice President. Organizationally, the position of Vice President, Nuclear Operations reported to the Senior Vice President and Chief Nuclear Officer. The organizational reporting relationship and responsibilities for the Site Vice President will remain the same as those previously assigned to the Vice President, Nuclear Operations.

This change in organizational title will facilitate better communications with other industry organizations, including the NRC, since the industry typically has an officer who functions or is titled as the Site Vice President.

Attachment I to TXX-06063 Page 4 of 7 In conjunction with this change, TXU Power has determined that the alternative to have the Site Vice President, formerly titled Vice President, Nuclear Operations, perform the functions of the Plant Manager may be eliminated since the Plant Manager is a penmanent position within the site organization with responsibilities as defined in TS 5. 1, "Responsibility" and 5.2, "Organization" and in Chapter 13 of the CPSES Final Safety Analysis Report.

Also, TXU Power has adopted the use of different software to produce and maintain the Technical Specifications. Previously, TXU Power has used Microsoft's "Word" software.

TXU 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 I 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 due to changes in location of page breaks, resulting in the renumbering of pages, and changes in the current format to be consistent with the guidelines in TSTF-RPT-01 and the example provided in NUREG-143I. "Standard Technical Specifications, Westinghouse Plants",

Revision 3.1.

4.0 TECHNICAL ANALYSIS

Currently, TS 5.1.1, 5.2.1, 5.2.2.d, 5.5.1.b, and 5.5.17 all specify that the Plant Manager is responsible for the designated functions described by the respective Specification with a Note stating these "Duties may be performed by the Vice President of Nuclear Operations if that organizational position is assigned." This Note is proposed to be deleted from the Technical Specifications. There are no changes to the prerequisite qualifications for the position, the assigned responsibilities, or the organizational reporting relationships for the Plant Manager or the Site Vice President, fonnerly the Vice President, Nuclear Operations. The deletion of this Note is an administrative change which will make the Technical Spefications more accurately reflect the current, and expected future, organizational structure at CPSES.

The adoption of different software to produce and maintain the CPSES Unit I and Unit 2 Technical Specifications has resulted in the need to reproduce and reissue the entire Technical Specifications in order to "re-baseline" the Technical Specifications and eliminate the potential for error in use and application of the Technical Specifications which could arise due to inconsistent application of the rules of usage caused by inadvertent differences in formatting from one page or section of the Technical Specifications to another.

Attachment I to TXX-06063 Page 5 of 7 In addition, the use of the FrameMaker application is expected to reduce the potential fir 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, header and footer content and formatting, page numbering, outlining, and Chapter, section and specification numbering and titling.

This proposed amendment contains no changes of a technical nature other than the above described changes to TS 5.1.1, 5.2.1, 5.2.2.d, 5.5.1.b, and 5.5.17.

5.0 REGULATORY ANALYSIS

5.1 No Significant Hazards Consideration TXU 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 IOCFR50.92, "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 involves organizational changes at the executive level and does not impact nor effect accident analysis assumptions. The method and tools used to maintain, and produce proposed changes to, the Technical Specifications has no bearing on any accident analysis assumptions. Therefore, these assumptions are preserved and there is no change in the probability or consequences of any previously evaluated accident.

Therefore, the proposed change does 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 involves an organizational change due to a change in title. There are no changes in existing reporting relationships or assigned responsibilities for safe operation of CPSES. The proposed re-issuance of the entire Technical Specifications stems from a change in the software utilized by TXU Power to produce and maintain the Technical Specifications. This software is not used to operate the plant nor is it used to establish any operational limits.

Attachment I to TXX-06063 Page 6 of 7 There are no hardware changes nor are there any changes in the method by which any safety-related plant system performs its safety function. The proposed change will not affect the normal method of plant operation. No performance requirements will be affected or eliminated. The proposed change wvill not result in physical alteration to any plant system nor wvill there be any change in the method by which any safety-related plant system performs its safety function.

No new accident scenarios, transient precursors, failure mechanisms, or limiting single failures are introduced as a result of this change. There will be no adverse effect or challenges imposed on any safety-related system as a result of these changes.

Therefore, the proposed change does 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 changes do not affect the acceptance criteria for any analyzed event nor is there a change to any Safety Analysis Limit (SAL).

There will be no effect on the manner in which safety limits, limiting safety system settings, or limiting conditions for operation are determined nor will there be any effect on those plant systems necessary to assure the accomplishment of protection functions.

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

Based on the above evaluations, TXU Power concludes that the proposed amendment(s) present no significant hazards under the standards set forth in IOCFR50.92(c) and, accordingly, a finding of"no significant hazards consideration" is justified.

5.2 Applicable Regulatory Requirements/Criteria IOCFR50.36(c)(5), "Administrative controls" requires that Technical Specifications include "...provisions relating to organization and management, procedures, recordkeeping, reviewv and audit, and reporting necessary to assure operation of the facility in a safe manner".

Attachment I to TXX-06063 Page 7 of 7 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 ir 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 ENVIRONMIENTAL CONSIDERATION The proposed amendment is confined to (i) changes to surety, insurance, and/or indemnity requirements, or (ii) changes to recordkeeping, reporting, or administrative procedures or requirements. Accordingly, the proposed amendment meets the eligibility criterion for categorical exclusion set forth in 10 CFR 51.22(c)(10). Therefore, pursuant to 10 CFR 51.22(b), no environmental impact statement or environmental assessment need be prepared in connection with the proposed amendment.

7.0. REFERENCES 7.1 TSTF-RPT-01, "Writer's Guide for Plant-Specific Improved Technical Specifications", June, 2005.

7.2 NUREG-1431, "Standard Technical Specifications, Westinghouse Plants",

Revision 3.1, 12/01/05.

to TXX-06063 Page I of 6 ATTACHMENT 2 to TXX-06063 PROPOSED TECHNICAL SPECIFICATION CHANGES (MARK-UP)

Pages 5.0-1 5.0-2 5.0-4 5.0-7 5.0-28 to TXX-06063 Responsibility Page 2 of6 5.1 5.0 ADMINISTRATIVE CONTROLS 5.1 Responsibility 5.1.1 The Plant Man

shall be responsible for overall unit operation and shall dele riting the succession to this responsibility during his absence.

TDhelete Pn a* 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.

Dutiesmay be performed by the Vice President of Nuclear Operations if that or bit g position i assignRed.

COMANCHE PEAK- UNITS 1AND 2 5.0-1 Amendment No. 64 to TXX-06063 Organization Page 3 of 6 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 e tthese Technical Specifications shall be documented in the FSAR;

b. The ant anr* shall be responsible for overall safe operation o1 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.

(continued)

Duties may be performed by the Vice President of Nuclear Operations if that organizatik. I position is assigned.

COMANCHE PEAK - UNITS 1 AND 2 5.0-2 Amendment No. 64 to TXX-06063 Organization Page 4 of 6 5.2 5.2 Organization 5.2.2 Unit Staff (continued) lDelete the"*"4 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 MODIE 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.

Dutics may be performed by the Vicc President of Nuclear Operations if that organizational I position is assigned.

COMANCHE PEAK - UNITS 1 AND 2 5.0-4 Amendment No. 64 to TXX-06063 Programs and Manuals Page 5 of 6 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.

Licensee initiated changes to the ODCM:

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

This documentation shall contain:

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

2. 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 1,and not adversely impact the accuracy or reliability of effluent, dose, or setpoint calculations; Fe-t, the" *"

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

Dutios may be performed by the Vice President of Nuclear Operations if that GrganiZatiGr4l I poesitin is assigned.

COMANCHE PEAK- UNITS 1AND 2 5.0-7 Amendment No. 64 to TXX-06063 Programs and Manuals Page 6 of 6 5.5 5.0 Programs and Manuals (continued) 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 CPSES. 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*

lDelete the " "

5.5!.18 Configuration Risk Mana ement 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 AMtion 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 contributor:;

such as Level 2 issues, and external events, qualitatively or quantitat vely.

(contirued)

Duties may be pcerformed by the Viec President of Nuclear Operations if that organizationa4 position is assigned. I COMANCHE PEAK - UNITS 1 AND 2 5.0-28 Amendment No. 94

Attacrhment 3 to TXX-06063 Page I of6 ATTACHMENT 3 to TXX-06063 RETYPED TECHNICAL SPECIFICATION PAGES Pages 5.0-1 5.0-2 5.0-4 5.0-7 5.0-28 to TXX-06063 Responsibility Page 2 of 6 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 his absence.

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 5.0-1 Amendment No. &I to TXX-06063 Organization Page 3 of 6 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.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-2 Amendment No. 64 to TXX-06063 Organization Page 4 of 6 5.2 5.2 Organization 5.2.2 Unit Staff (continued) 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 MODIE 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 Expeitise on Shift.

COMANCHE PEAK - UNITS 1 AND 2 5.0-4 Amendment No. &t to TXX-06063 Programs and Menuals Page :5 of 6 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.

Licensee initiated changes to the ODCM:

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

This documentation shall contain:

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

2. 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, cr setpoint calculations;

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

COMANCHE PEAK - UNITS 1 AND 2 5.0-7 Amendment No. &4 to TXX-06063 Programs and Manuals Page 6 of 6 5.5 5.5 Programs and Manuals (continued) 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 CPSES. 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. I 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.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 5.0-28 Amendment Nc..

to TXX-06063 Page 1 of 4 ATTACHMENT 4 to TXX-06063 PROPOSED FSAR CHANGES Pages 13.1-3 17.2-1 17.2-2 to TXX-06063 CPSES/FSAR Page,2of 4 13.1.1.1.1 Organization - Nuclear Operations Sil:e Vice President, Nuciear Ocprations aid.for Plant Manager To providei fexibility with respect to future organizational changes, the resPon'Sibilities, listed below. as-wAell as Hose identified l.. ewhere in;the FSAR andotlher *CP2SES Lieensinge Basis Dou t e4Te3tve oar the Mzto-fntrcreand oher whert thSitePresident, ie Nu calant 1

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are:pnil the VienPrsiden Prenidentage tdirectly too Site & Ce Nuclear O3.1in.1. abMveaneis

~3.- CPE4prtinare duiscussedanenne Platopiesdractions beow.eOfraios mreypanng0aito iet AMENDMEN responsuiblers tile s rlant and an thc rsponndbLity for security of thet plant.; S131- dc AMENDM is-tOO ed in Nrtingoraniti to TXX-06063 CPSES/FSAR Page :3 of 4 17.2 QUALITY ASSURANCE DURING THE OPERATIONS PHASE 17.2.1 ORGANIZATION 17.2.1.1 Organizational Structure TXU Generation Company LP (TXU Power), as the licensee, has overall responsibility for the operation of the Comanche Peak Steam Electric Station (CPSES). The Nuclear Generation Group (NG) has been designated by TXU Powver to coordinate the design, construction and operation of CPSES. The organizational structure of TXU Power and the Nuclear Generation Group are described in Section 13. 1.

The following paragraphs amplify upon Section 13.1 with regard to establishment and execution of the quality assurance program for the operation of CPSES. Figure -17.2 1 Figure 13.1-2 shows the structure and relationships of those elements of Nuclear Generation Group which function under the control of the QA program. Figure 17.22 Figure 13.1-3 shows the CPSES Nuclear Operations organizational structure.

TXU Power may, from time to time, assign responsibility for executing certain portions of the program to qualified consultants and contractors. However, TXU Power, retains ultimate responsibility for the CPSES operations quality assurance program.

17.2.1.1.1 Senior Vice President & Chief Nuclear Officer The Senior Vice President & Chief Nuclear Officer is responsible for the overall management of Nuclear Generation operations, including operation of CPSES, and for the establishment of company policies related to Nuclear Generation. He has the overall responsibility for the establishment and execution of the quality assurance program for the operation of CPSES.

The Senior Vice President & Chief Nuclear Officer has assigned to the Site Vice President Plat Managef (see Sectioen 13.I.1.2.1) the overall responsibility for operation of CPSES and for implementation of the quality assurance program for the Nuclear Operations function at CPSES.

The Senior Vice President & Chief Nuclear Officer has assigned to the Vice President, Nuclear Engineering and Support the overall responsibility for engineering and support of CPSES, and for implementation of the quality assurance program for the Nuclear Engineering function at CPSES.

17.2.1.1.2 Site Vice President (See Section 13.1..21 PlantManageF The Site Vice President is responsible to the Senior Vice President & Chief Nuclear Officer for plant operations at CPSES.

17.2-1 AMENDMENT4-W to TXX-06063 CPSES/FSAR Page 4 of 4 Specific duties and responsibilities of the Site Vice President include the following:

I. Technical and administrative direction of the Director. Plant Support.

2. Technical and administrative direction of the Nuclear Training Manager.

3. Operational and technical support of CPSES.

4. Technical and administrative direction of Plant Manager and assumes duties if the position is not occupied.

17.2.1.1.3 Plant Manager (see Sectioin 13.1.1.2. 1)

The Plant Manager reports is responsible to the Site Vice President for plant operations at CPSES.

Specific duties and responsibilities of the Plant Manager include the following:

I. Technical and administrative direction of the Director, Operations.

2. Technical and administrative direction of the Director, Maintenance.

3. Technical and administrative direction of the Radiation and Industrial Safety Manager.

4. Operational and technical maintenance support of CPSES.

- Tcehnical and adminisrative direction for the implemenation of quality assuranee requirements and controls at C-PSES.

56. Management of all operations activities at CPSES.

67. Chairmanship of the Station Operations Review Committee (SORC).

7&. Membership on the Operations Review Committee upon appointment by the Senior Vice President & Chief Nuclear Officer.

17.2.1.1.3.1 Station Operations Review Committee (SORC)

The SORC shall function to advise the Plant Manager (see Section 13.1. .2.1) on all matters related to nuclear safety.

The SORC shall as a minimum be composed of the Chairman and six individuals n:iwagers or individuals reporting direetly to managers froem who collectively have experience and expertise in the areas listed below and meet the requirements of ANSI-N 183.1-1971 Section 4.2 or 4.4 for required experience.

Operations 17.2-2 AMENDMENT 4-00

Enclosure I to TXX-06063 Page 1 of 326 ENCLOSURE I to TXX-06063 Reformatted CPSES Unit 1 and Unit 2 Technical Specifications (325 pages)

TECHNICAL SPECIFICATIONS FOR COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 AND 2

TABLE OF CONTENTS 1.0 USE AND APPLICATION ..................... ................................... 1.1-1 1.1 Definitions ........................................................ 1.1-1 1.2 Logical Connectors ........................................................ 1.2-1 1.3 Completion Times ........................................................ 1.3-1 1.4 Frequency ...... 1.4-1 2.0 SAFETY LIMITS (SLs) ........................................................ 2.0-1 2.1 SLs ........................................................ 2.0-1 2.2 SL Violations ........................................................ 2.0-1 3.0 JMITING CONDITION FOR OPERATION (LCO) APPLICABILITY ............ 3.0-1 3.0 SURVEILLANCE REQUIREMENT (SR) APPLICABILITY ........................... 3.0-4 3.1 REACTIVITY CONTROL SYSTEMS ..................................................... 3.1-1 3.1.1 Shutdown Margin (SDM) ............................................ ............ 3.1-1 3.1.2 Core Reactivity ........................................................ 3.1-2 3.1.3 Moderator Temperature Coefficient (MTC) ................... ................... 3.1-4 3.1.4 Rod Group Alignment Limits ........................................................ 3.1-7 3.1.5 Shutdown Bank Insertion Limits ....................................................... 3.1-10 3.1.6 Control Bank Insertion Limits ........................................................ 3.1-12 3.1.7 Rod Position Indication ........................................................ 3.1-14 3.1.8 PHYSICS TESTS Exceptions - MODE 2 ...................... ................... 3.1-17 3.2 POWER DISTRIBUTION LIMITS ........................................................ 3.2-1 3.2.1 Heat Flux Hot Channel Factor (FO(Z) (FQ Methodology) ................. 3.2-1 3.2.2 Nuclear Enthalpy Rise Hot Channel Factor .................. ................... 3.2-5 3.2.3 AXIAL FLUX DIFFERENCE (AFD) (Constant Axial Offset Control (CAOC) Methodology) .3.2-8 3.2.4 QUADRANT POWER TILT RATIO (QPTR) .3.2-11 3.3 INSTRUMENTATION .3.3-1 3.3.1 Reactor Trip System (RTS) Instrumentation .3.3-1 3.3.2 Engineered Safety Feature Actuation System (ESFAS)

Instrumentation........................................................................... 3.3-20 3.3.3 Post Accident Monitoring (PAM) Instrumentation ............................. 3.3-33 3.3.4 Remote Shutdown System .................................................. 3.3-37 3.3.5 Loss of Power (LOP) Diesel Generator.(DG) Start Instrumentation. 3.3-40 3.3.6 Containment Ventilation Isolation Instrumentation ........................... 3.3-45 3.3.7 Control Room Emergency Filtration System (CREFS) Actuation Instrumentation......................................................................... 3.3-49 3.4 REACTOR COOLANT SYSTEM (RCS) ................................................ 3.4-1 3.4.1 RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits .................................................. 3.4-1 3.4.2 RCS Minimum Temperature for Criticality ........................................ 3.4-3 3.4.3 RCS Pressure and Temperature (P/T) Limits ................... ............... 3.4-4 3.4.4 RCS Loops - MODES 1 and 2 .................................................. 3.4-6 3.4.5 RCS Loops - MODE 3.................................................. 3.4-7 3.4.6 RCS Loops -MODE 4.................................................. 3.4-10 3.4.7 RCS Loops - MODE 5, Loops Filled ................................................. 3.4-12 3.4.8 RCS Loops - MODE 5, Loops Not Filled .......................................... 3.4-14 3.4.9 Pressurizer .................................................. 3.4-16 COMANCHE PEAK - UNITS 1 AND 2 i Amendment Nao.

TABLE: OF CONTENTS 3.4 REACTOR COOLANT SYSTEM (RCS) (continued) 3.4.10 Pressurizer Safety Valves ..................................................... 3.4-18 3.4.11 Pressurizer Power Operated Relief Valves (PORVs) ...................... 3.4-20 3.4.12 Low Temperature Overpressure Protection (LTOP) System ........... 3.4-24 3.4.13 RCS Operational LEAKAGE ..................................................... 3.4-29 3.4.14 RCS Pressure Isolation Valve (PIV) Leakage .................................. 3.4-31 3.4.15 RCS Leakage Detection Instrumentation .......................... ............... 3.4-35 3.4.16 RCS Specific Activity ..................................................... 3.4-39 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) ............. .............. 3.5-1 3.5.1 Accumulators ..................................................... 3.5-1 3.5.2 ECCS - Operating ..................................................... 3.5-3 3.5.3 ECCS - Shutdown ..................................................... 3.5-6 3.5.4 Refueling Water Storage Tank (RWST) ........................................... 3.5-8 3.5.5 Seal Injection Flow ..................................................... 3.5-10 3.6 CONTAINMENT SYSTEMS ..................................................... 3.6-1 3.6.1 Containment ..................................................... 3.6-1 3.6.2 Containment Air Locks ........................ ............................. 3.6-2 3.6.3 Containment Isolation Valves ..................................................... 3.6-7 3.6.4 Containment Pressure ..................................................... 3.6-14 3.6.5 Containment Air Temperature ..................................................... 3.6-15 3.6.6 Containment Spray System ..................................................... 3.6-16 3.6.7 Spray Additive System ........................ ............................. 3.6-18 3.7 PLANT SYSTEMS ..................................................... 3.7-1 3.7.1 Main Steam Safety Valves (MSSVs) ................................................ 3.7-1 3.7.2 Main Steam Isolation Valves (MSIVs) .............................................. 3.7-6 3.7.3 Feedwater Isolation Valves (FlVs) and Feedwater Control Valves (FCVs) 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) .................................................. 3.7-15 3.7.7 Component Cooling Water (CCW) System ....................... ............... 3.7-16 3.7.8 Station Service Water System (SSWS) ............................................ 3.7-18 3.7.9 Ultimate Heat Sink (UHS) .................................................. 3.7-21 3.7.10 Control Room Emergency Filtration/Pressurization System (CREFS) 3.7-22 3.7.11 Control Room Air Conditioning System (CRACS) ............................ 3.7-25 3.7.12 Primary Plant Ventilation System (PPVS) - ESF Filtration Trains.... 3.7-28 3.7.13 Fuel Building Air Cleanup System (FBACS) ..................... ............... 3.7-30 3.7.14 Penetration Room Exhaust Air Cleanup System (PREACS) ........... 3.7-31 3.7.15 Fuel Storage Area Water Level .................................................. 3.7-32 3.7.16 Fuel Storage Pool Boron Concentration ........................................... 3.7-33 3.7.17 Spent Fuel Assembly Storage .................................................. 3.7-34 3.7.18 Secondary Specific Activity .................................................. 3.7-40 3.7.19 Safety Chilled Water .................................................. 3.7-41 3.7.20 UPS HVAC System .................................................. 3.7-43 3.8 ELECTRICAL POWER SYSTEMS .................................................. 3.8-1 3.8.1 AC Sources - Operating .................................................. 3.8-1 3.8.2 AC Sources - Shutdown .................................................. 3.8-18 COMANCHE PEAK - UNITS 1 AND 2 ii Amendment N~o.

TABLE OF CONTENTS 3.8 ELECTRICAL POWER SYSTEMS (continued) 3.8.3 Diesel Fuel Oil, Lube Oil, and Starting Air ........................................ 3.8-21 3.8.4 DC Sources - Operating ........................................................ 3.8-24 3.8.5 DC Sources - Shutdown ........................................................ 3.8-27 3.8.6 Battery Parameters ........................................................ 3.8-29 3.8.7 Inverters - Operating ......................... ............................... 3.8-33 3.8.8 Inverters - Shutdown ........................................................ 3.8-35 3.8.9 Distribution Systems - Operating ...................................................... 3.8-37 3.8.10 Distribution Systems - Shutdown ..................................................... 3.8-39 3.9 REFUELING OPERATIONS ........................................................ 3.9-1 3.9.1 Boron Concentration ........................................................ 3.9-1 3.9.2 Unborated Water Source Isolation Valves .................... ................... 3.9-2 3.9.3 Nuclear Instrumentation ........................................................ 3.9-4 3.9.4 Containment Penetrations ........................................................ 3.9-6 3.9.5 Residual Heat Removal (RHR) and Coolant Circulation - High Water Level .3.9-8 3.9.6 Residual Heat Removal (RHR) and Coolant Circulation - Low Water Level .................................................. 3.9-10 3.9.7 Refueling Cavity Water Level .................................................. 3.9-12 4.0 Design Features ........... 4.0-1 4.1 Site Location ........................................................ 4.0-1 4.2 Reactor Core ........................................................ 4.0-1 4.3 Fuel Storage ........................................................ 4.0-2 5.0 ADMINISTRATIVE CONTROLS ........................................................ 5.1-1 5.1 Responsibility ........................................................ 5.1-1 5.2 Organization ........................................................ 5.2-1 5.3 Unit Staff Qualifications ........................................................ 5.3-1 5.4 Procedures ........................................................ 5.4-1 5.5 Programs and Manuals ........................................................ 5.5-1 5.6 Reporting Requirements ........................................................ 5.6-1 5.7 High Radiation Area ........................................................ 5.7-1 COMANCHE PEAK - UNITS 1 AND 2 Amendment NJo.

iii

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COMANCHE PEAK - UNITS 1 AND 2 iv Amendment No. 124

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COMANCHE PEAK - UNITS 1 AND 2 v Amendment No. 'i24

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COMANCHE PEAK - UNITS 1 AND 2 vi Amendment No. 124

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COMANCHE PEAK - UNITS 1 AND 2 vii Amendment No. 124

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 wi :hin 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 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 1-13',

(microcuries/gram) that alone would produce the same thyroid dose as the quantity and isotopic mixture of 1-131, 1-132, 1-133, 1-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table Ill of TID-14844, AEC, 1962, "Calculation of Distance Factors for Power and Test Reactor Sites," or those listed in Table E-7 of Regulatory Guide 1.109, Rev. 1, NRC, 1977 E - AVERAGE E shall be the average (weighted in proportion to the DISINTEGRATION ENERGY concentration of each radionuclide in the reactor coolant at the time of sampling) of the sum of the average beta and gamma energies per disintegration (in MeV) for isotopes, other than iodines, with half lives >10 minutes, making up at least 95% of ihe total noniodine activity in the coolant.

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

Definitions 1.1 1.1 Definitions 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 tirme 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.

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 (SG) to the Secondary System;

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

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

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

Definitions 1.1 1.1 Definitions 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.

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, subsystern, train, component, or device to perform its specified safety function(s) are also capable of performing their related suppor:

function(s).

PHYSICS TESTS PHYSICS TESTS shall be those tests performed to measure tie 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. Plant operation within these limits is addressed in LCO 3.4.3, "RCS Pressure and Temperature (P/T) Limits," and LCO 3.4.12, "Low Temperature Overpressure Protection (LTOP) System."

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

Definitions 1.1 1.1 Definitions 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.

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 componen:s 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 cr total steps.

COMANCHE PEAK - UNITS 1 AND 2 1.1-5 Amendment No.

Definitions 1.1 1.1 Definitions 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.

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 1.1-6 Amendment No.

Defini :ions 1.1 Table 1.1-1 (page 1 of 1)

MODES REACTIVITY % RATED AVERAGE REACTOR MODE TITLE CONDITION THERMAL COOLANT (keff) POWER(a) TEMPERATURE (OF) 1 Power Operation > 0.99 > 5 NA 2 Startup > 0.99 *5 NA 3 Hot Standby < 0.99 NA 2 350 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 1.1-7 Amendment Ngo.

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 Ere 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 log cal 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 Nlo.

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 cn 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 inoperatility:

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 inlo 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 Condit on) 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 Tine 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 . . ."

Example 1.3-3 illustrates one use of this type of Completion Time. The 10 day Completion Time specified for Conditions A and B in Example 1.3-3 may not be extended.

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 (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 lime 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. 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-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 the first 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 stcp 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 (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. AND 10 days from discovery of failure to meet the LCO 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. AND 10 days from discovery of failure to meet the LCO 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.

Completion Times 1.3 1.3 Ccmpletion Times EXAMPLES (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).

The Completion Times of Conditions A and B are modified by a logical connector with a separate 10 day Completion Time measured from the time it was discovered the LCO was not met. In this example, without the separate Completion Time, it would be 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. The separate Completion Time modified by the phrase "from discovery of failure to meet the LCO" is designed to prevent indefinite continued operation while not meeting the LCO. This Completion Time allows for an exception to the normal "time zero" for beginning the Completion Time "clock". In this instance, the Completion Time "time zero" is specified as commencing at the time the LCO was initially not met, instead of at the time the associated Condition was entered.

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 Noo.

Completion T mes 1.3 1.3 Ccmpletion Times EXAMPLES (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 MODE4. 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 (continued) declared inoperable, Condition A is entered and its Completion Time start3. 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 OPERA13LE 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 I AND 2 1.3-7 Amendment No.

Completion Times 1.3 1.3 Completion Times EXAMPLES (continued)

If after entry into Condition B, Required Action A.1 or A.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 -:he 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 URSE 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.

EXAMP LES 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 FREQUENCY Perform CHANNEL CHECK. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 (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 whici 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 2 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 log cal connector "AND" indicates that both Frequency requirements must be met.

Each time reactor power is increased from a power level < 25% RTP to 2 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.C'.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 Ngo.

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 2 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 riot met, provided operation does not exceed 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months with power Ž 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 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 < 47000 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 X.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 specilied 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 'he 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 Ngo.

LCO Applicability 3.0 3.0 LCO APPLICABILITY SR 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 3.43.6 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 systemn LCO ACTIONS are required to be entered. This is an exception to LCO 3.').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 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 tc be met, entry into a MODE or other specified condition in the Applicability shal be made in accordance with the other applicable Specifications.

COMANCHE PEAK- UNITS 1 AND 2 3.0-3 Amendment Nho.

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 variables outside specified limits.

SR 3.0.2 The specified Frequency for each SR is met if the Surveillance is perform ad 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 specifiec 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 delayec 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 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

- NOTE -

While this LCO is not met, entry into MODE 5 from MODE 6 is not permitted.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. SDMI 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 Nao.

Core Reaclivity z-;.1 .2 3.1 REACTIVITY CONTROL SYSTEMS 3.1.2 C:ore 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 restrictions and SRs. 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.

COMANCHE PEAK - UNITS 1 AND 2 3.1-2 Amendment Nlo.

Core Reactivity 3.1.2 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 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 l 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 2 1.0 for the upper MTC limit, MODES 1, 2, and 3 for the lower MTC limit ACTIONS CONDITION REQUIRED ACTION COMPLETION TIIME A. MTG. not within upper limit. A.1 Establish administrative withdrawal 24 hour2.777778e-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 Nho.

M1TC

3.1.3 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.1.3.1 Verify MTC is within upper limit. Once prior to entering MODE I 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 0.9

_ I _

U-

-S 0.6 a

S.l UNACCEPTABLE 0.7 _ - OPERATION

.-I c D.6

.1 j __ _ X_____

4-4-

I - I I I I 0.5 0

CJ I I W

C, 4-) 0.4 L.

9)

W 0.3 I - ACCEPTABLE i CD W

IL- OPERATION l I II 0.2

'a 0

I I I.

0.1 0

0 10 20 30 40 50 60 70 80 90 100 Percent Rated Thermal Power Figure 3.1.3-1 (page 1 ot 1)

Moderator Temperature Coefficient vs. Power Level COMANCIHE PEAK - UNITS 1 AND 2 3.1-6 Amendment 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

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

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 2 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 < 2.4 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 Ž 5000 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 Ngo.

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 Ž 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 NJo.

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 movable incore detectors.

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 movable incore detectors.

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 movable incore 24 steps in one direction detectors.

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 5 50% RTP.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.1-15 Amendment No.

Rod Position Indication 3.1.7 ACTICNS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. Ona 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 ind cator 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, "Shutdown Bank 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 2 541OF; 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. SDW 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 Nho.

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 mel.

SURVE:ILLANCE 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 2 541 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 Noo.

FQ(Z) (F0 Methodology) 3.2.1 3.2 POWER DISTRIBUTION LIMITS 3.2.1 Heat Flux Hot Channel Factor (Fo(Z) (F0 Methodology)

LCO 3.2.1 F0 (Z), as approximated by F c(Z) and F w(Z), shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. FQ(Z) not within limit. A.1 Reduce THERMAL POWER 2 1% 15 minutes after each RTP for each 1% Fc(Z) exceeds F C(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 2 1% for each 1% Fgc(Z) determination FQC(Z) exceeds limit.

AND 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% FQ(Z) FQ(Z) determination exceeds limit.

AND A.4 Perform SR 3.2.1.1. Prior to increasing THERMAL POWER above the limit of Required Action A.1 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.2-1 Amendment Nlo.

F0 (Z) (F0 Methodo ogy)

3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. F0 (Z) not within limits. B.1 Reduce AFD limits 2 1%for each 1% 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months F0 (Z) exceeds limit.

C. Recluired 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 3.2-2 Amendment No.

FQ(Z) (F0 Methodclogy) 3.2.1 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 map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.1.1 Verify Fc(Z) is within limit. Once after each refueling prior to THERMAL POWVER 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

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

COMANCHE PEAK- UNITS 1 AND 2 3.2-3 Amendment N~o.

F0 (Z) (F0 Methodology) 3.2.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.2.1.2

- NOTE -

If Fc(Z) measurements indicate maximum over z [K(Z

[K(Z)]

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

a. Increase F w(Z) by the appropriate factor and reverify Fa (Z) is within limits; or

b. Repeat SR 3.2.1.2 once per 7 EFPD until two successive flux maps indicate maximum over z [()] has not increased.

Verify FQ (Z) is within limit. Once after each refueling prior to THERMAL POWER exceeding 75% FRTP 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

Ž 20% RTP, the THERMAL POWER at which Fc(Z) %as last verified AND 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.2-4 Amendment iJo.

N FAH 3.2.2 3.2 POWER DISTRIBUTION LIMITS N

3.2.2 Nuclear Enthalpy Rise Hot Channel Factor (FAH)

LCO .2.2 FAH shall be within the limits specified in the COLR.

APPLICABILITY: MODE 1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME N

A. A.1.1 Restore FAH to within limit. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

- NOTE -

Required Actions A.2 and OR A.3 must be completed whenever Condition A is A.1.2.1 Reduce THERMAL POWER to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months entered. <50% RTP.

AND N

FAH not within limit.

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 3.2-5 Amendment No.

N FAH

.2.2 ACTIONS (continued)

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 2 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 3.2-6 Amendment Nso.

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 map is obtained.

SURVEILLANCE FREQUENCY SR 3.2.2.1 Verify FAH is within limits specified in the COLR. Once after each refueling prior to THERMAL POWER exceeding 75% RTP AND 31 EFPD thereafter COMANCHE PEAK - UNITS 1 AND 2 3.2-7 Amendment \lo.

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

LCO 3.2.3 The AFD:

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

b. May deviate outside the target band with THERMAL POWER < 90%

RTP but 2 50% RTP, provided AFD is within the acceptable operation limits and cumulative 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 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . The acceptable operation limits are specified in the COLR.

c. May deviate outside the target band with THERMAL POWER < 50%

RTP.

- NOTES -

1. The AFD shall be considered outside the target band when two or more OPERABLE excore channels indicate AFD to be outside the target bald.

2. With THERMAL POWER > 50% RTP, penalty deviation time shall be accumulated on the basis of a 1 minute penalty deviation for each 1 minute of power operation with AFD outside the target band.

3. With THERMAL POWER < 50% RTP, penalty deviation time shall be accumulated on the basis of a 0.5 minute penalty deviation for each 1 minute of power operation with AFD outside the target band.

4. A 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.

APPLICABILITY: MODE 1with THERMAL POWER > 15% RTP COMANCHE PEAK - UNITS 1AND 2 3.2-8 Amendment No.

AFD (CAOC Methodology) 3.2.3 ACTIO\ IS CONDITION REQUIRED ACTION COMPLETION TIME A. THERMAL POWER 2 90% A.1 Restore AFD to within target band. 15 minutes RTP.

AN[)

AFD) not within the target band.

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

Time of Condition A not met.

C. --- - C.1 Reduce THERMAL POWER to 30 minutes

- NOTE - < 50% RTP.

Required Action C.1 must 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)

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

AFD (CAOC Methodology) 3.2.3 ACTIONS (continued)

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

Time for Condition C not met.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.2.3.1 Verify AFD is within limits for each OPERABLE excore 7 days channel.

SR 3.2.3.2 Not Used.

SR 3.2.3.3 --

-NOTE-The initial target flux difference after each refueling may be determined from design predictions.

Determine, by measurement, the target flux difference of Whenever FaD(Z Is each OPERABLE excore channel. verified per 3.2.1.2.

COMANCHE PEAK - UNITS 1 AND 2 3.2-1 0 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. QPlR not within limit. A.1 Reduce THERMAL POWER 2 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 3.2-1 1 Amendment Nlo.

QPTR C.2.4 ACTIONS (continued)

CONDITION I 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 Prior to increasing restore 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 nol 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 (continued)

COMANCHE PEAK - UNITS I AND 2 3.2-1 2 Amendment No.

QPTR 3.2.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 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.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY 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 movable incore 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months detectors.

COMANCHE PEAK - UNITS 1 AND 2 3.2-1 3 Amendment lNo.

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

- NOTE-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 3.3.1-1 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 ACTIONIS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

- 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.

C. 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 lgo.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One Power Range Neutron Flu: - High channel - NOTE -

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 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 ACTICNS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. Ona 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 F.1 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---

Neutron Flux channels - NOTE -

inoperable. Limited boron concentration changes 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 Noo.

RTS Instrumentation 3.3.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Not used.

I. One Source Range 1.1 --------------------------------------------

Neutron Flux channel - NOTE -

inoperable. Limited boron concentration changes associated with RCS inventory control or limited plant temperature changes are allowed.

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)

COMANC HE PEAK - UNITS I 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 _-_-_ _ _- _ _ _-_ ___

Turbine Trip channel - NOTE -

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.

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 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months 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 ACTICNS (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 1AND 2 3.3-8 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.3.1.2

- NOTES -

1. Adjust NIS and N-16 Power Monitor channel if absolute difference is > 2%.

2. 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 Ž15% 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 Nuclear Instrumentation System (NIS) and N-16 Power Monitor channel output.

SR 3.3.1.3

- NOTES -

1. Adjust NIS channel if absolute difference is Ž 3%.

2. 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 incore detector measurements to 31 effective full NIS AFD. power days (EFPD)

+

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 (continu ad)

COMANCHE PEAK- UNITS 1 AND 2 3.3-9 Amendment No.

RTS Instrumentation 3.3.1 SURVI iLLANCE 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 2 75%

RTP.

Calibrate excore channels to agree with incore detector 92 EFPD 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-10 are in their required state for existing unit conditions.

Perform COT. 184 days (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 0 Amendment Nlo.

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-10 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 (continu ad)

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 1 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 (continued)

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

RTS Instrumentation W.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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 2 90%

RTP.

------ ----

--- ---------- --- ---- --- --- ---- --- --- ---- --- -- .

Perform CHANNEL CALIBRATION. 18 months 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 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 3 Amendment No.

RTS Instrumentation 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 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 3.3-1 4 Amendment Noo.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 1 of 5)

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 Flu):

a. High 1,2 4 D SR 3.3.1.1 < 110.8% RTP 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 *27.7%RTP 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 Flu) Rate High SR 3.3.1.11 with time constant Pos'tive Rate 2 2 sec

4. Intemediate 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

5. Source Range 2(e) 2 lIJ 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 (continuec)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

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

(c) Below the P-10 (Power Range Neutron Flux) interlock.

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

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

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

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 2 of 5)

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

6. Overtemperature 1,2 4 E SR 3.3.1.1 Refer to Note 1 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 N-16 1,2 4 E SR 3.3.1.1

112.9% RTP SR 3.3.1.2 SR 3.3.1.7 SR 3.3.1.10 SR 3.3.1.16

8. Pre!;surizer Pressure

a. Low 1 (g) 4 M SR 3.3.1.1 I 1863.6 psig SR 3.3.1.7 (Unit 1)

SR 3.3.1.10 2 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)

9. PressurizerWaterLevel- 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 - 1 (g) 3 per loop M SR 3.3.1.1 Ž 88.6% of indicated Low SR 3.3.1.7 loop flow (Unit 1)

SR 3.3.1.10 Ž 88.8% of indicated SR 3.3.1.16 loop flow (Unit 2)

11. Not Used

12. Undervoltage 1() 1 per bus M SR 3.3.1.9 2 4753 V RCFs SR 3.3.1.10 SR 3.3.1.16

13. Underfrequency 1 per bus M SR 3.3.1.9 2 57.06 Hz RCPs SR 3.3.1.10 SR 3.3.1.16 (continued)

(a) The Al owable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

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

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 6 Amendment No.

RTS Instrumentation 3,.3.1 Table 3.3.1-1 (page 3 of 5)

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

14. Stcam Generator (SG) 1,2 4 per SG E SR 3.3.1.1 Ž 23.1% of narroN 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) 2 33.4% of narrow range instrument span (Unit 2)

15. No: Used.

16. Turbine Trip

a. Low Fluid Oil 1 ) 3 0 SR 3.3.1.10 Ž 46.6 psig Pressure SR 3.3.1.15

b. Turbine Stop Valve 1,) 4 P SR 3.3.1.10 2 1% open Closure SR 3.3.1.15

17. Safaty Injection (SI) Input 2 trains Q SR 3.3.1.14 NA frori Engineered Safety FeE ture Actuation System (ESFAS)

18. Reactor Trip System Interlocks

a. Intermediate Range 2 S SR 3.3.1.11 2 6E-11 amp 2 (e)

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 4 T SR 3.3.1.11 < 50.7% RTP Neutron Flux, P-8 SR 3.3.1.13

d. Power Range 1 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 Ž 7.3% RTP and Neutron Flux, P-10 SR 3.3.1.13 < 12.7% RTP

f. Turbine First Stage 1 2 T SR 3.3.1.10

12.7% turbine Pressure, P-13 SR 3.3.1.13 power (continued)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

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

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

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

COMANCHE PEAK - UNITS 1 AND 2 3.3-1 7 Amendment No.

RTS Instrumentation 3.3.1 Table 3.3.1-1 (page 4 of 5)

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

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

20. ReactorTrip Breaker 1,2 1 each per RTB U SR 3.3.1.4 NA Uncervoltage 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 3tb), 4 (b), 5(b) 2 trains C SR 3.3.1.5 NA (continued)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

(b) With Fod 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 I AND 2 3.3-1 8 Amendment No.

RTS Instrumentation Table 3.3.1-1 (page 5 of 5)

Reactor Trip System Instrumentation Note 1: Overtemperature N-16 The Overtemperature N-1 6 Function Allowable Value shall not exceed the following setpoint by more than 1.72% of spe n for Unit 1, or 2.82% of span for Unit 2.

Qsetpoint = KI - K2 [(1 +T 2S)TC- T] + K3(P - P) - f (Aq)

Where:

Qsetpoint = Overtemperature N-16 trip setpoint, K1 -

K2 = /0 F K3 = /psig Tc = Cold leg temperature T0 = Reference Tc at RATED THERMAL POWER,

0F P = Measured pressurizer pressure, psig p1 2

psig (Nominal RCS operating pressure) s = the Laplace transform operator, sec-1.

T1,T2 = Time constants utilized in lead-lag controller for Tc, T1 2 sec. and T2

sec f1(Aq) = ((qt - qb) + %} when (qt - qb) < *% RTP 0% when *% RTP < (qt - qb) < 1% RTP

{(qt- qb) - %} when (qt - qb) *% RTP Note 2: Not Used.

as specified in the COLR COMANCHE PEAK- UNITS 1 AND 2 3.3-1 9 Amendment Ngo.

ESFAS Instrumentation 3.3.2 3.3 INSTRUMENTATION 3.3.2 lEngineered 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 ACTIONIS

- NOTE -

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 Ngo.

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 Ngo.

ESFAS Instrumentation

';.3.2 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One Containment Pressure-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 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)

COMANCHE PEAK - UNITS 1 AND 2 3.3-22 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 I 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 hour6.944444e-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 -

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 Nlo.

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 STAGGEREDTEST BASIS SR 3.3.2.11 --------

-NOTE-Verification of setpoint not required.

Perform TADOT. 18 months SR 3.3.2.12 Perform CHANNEL CALIBRATION. 9 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 5)

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

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 Ž1803.6 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 2 594.0 psig(c)

Low SR 3.3.2.5 (Unit 1)

SR 3.3.2.9 Žt 578.4 psig(c)

SR 3.3.2.1 0 (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 s 18.8 psig Oressure SR 3.3.2.5

-igh - 3 SR 3.3.2.9 SR 3.3.2.10 (Continued)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the 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 250 seconds and T2 5 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 5)

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 I (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 SR 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 setting. See the Bases for the Trip Setpoints.

COMANCHE PEAK - UNITS 1 AND 2 3.3-29 Amendment Ngo.

ESFAS Instrumentation 3.3.2 Table 3.3.2-1 (page 3 of 5)

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(i) 2 F SR 3.3.2.8 NA

b. Automatic Actuation 1, 2(), 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(i 3(i) 3 D SR 3.3.2.1 s 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 1i 2i), 3(b)(i) 3 per steam line D SR 3.3.2.1 Ž 594.0 psig(c)

SR 3.3.2.5 (Unit 1)

SR 3.3.2.9 Ž 578.4 psigtc)

SR 3.3.2.1 0 (Unit 2)

(2) Negative Rate - 3 19)(i) 3 por steam line D SR 3.3.2.1 < 178.7 psith)

High SR 3.3.2.5 SR 3.3.2.9 SR 3.3.2.1(0 (Continued)

(a) The Allowable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

(b) Above the P-11 (Pressurizer Pressure) Interlock and below P-i1, unless the Function is blocked.

(c) Time constants used in the lead/lag controller are T, 2 50 seconds and T2

5 seconds.

(g) Below the P-1I (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 2 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 ilgo.

- -----

ESFAS Instrumentbtion

3.3.2 Table 3.3.2-1 (page 4 of 5)

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 Feadwater Isolation

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

b. SG Water Level - 1, 20) 3 per SG(P) I SR 3.3.2.1 < 84.3% of narrow High High (P-14) SR 3.3.2.5 range span (Unit 1)

SR 3.3.2.9 <83.5% of narrow SR 3.3.2.10 range span (Unit 2)

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

6. Aumiliary 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 >23.1% of narrovi Low-Low SR 3.3.2.5 range span (Unit I)

SR 3.3.2.9 Ž33.4% of narrow SR 3.3.2.10 range span (Unit,')

d. Safety Injection Refer to Function I (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

-eedwater Pumps pump

h. Not Used.

(continued)

(a) The Al'owable Value defines the limiting safety system setting. See the Bases for the Trip Setpoints.

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

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

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

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

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 Ccntainment 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. RefuelingWater 1.2,3,4 4 K SR3.3.2.1 243.9% instrument Storage Tank SR 3.3.2.5 span (Unit 1)

(RWST) Level - Low SR 3.3.2.10 Ž44.1% instrument Low SR 3.3.2.12 span (Unit 2)

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

Safety Injection

8. ES-AS 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 setting. See the Bases for the Trip Setpoints.

COMANCHE PEAK - UNITS 1 AND 2 3.3-32 Amendment NJo.

PAM Instrumentation Z;.3.3 3.3 INSTRUMENTATION 3.3.3 F'ost 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 -

Separale Condition entry is allowed for each Function.

- - - .--- - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - .--

I - -

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 3.3-33 Amendment No.

PAM Instrumentation 2.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIVE 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.

OF Ore required Tcold channel and one required Steam Line Pressure channel for the associated loop inoperable.

D. Req uired 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 3.3-34 Amendment Ngo.

PAM Instrumentation W.3.3 SURVEILLANCE REQUIREMENTS

- NOTE -

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 3.3-35 Amendment No.

- ---

PAM Instrumentation 3.3.3 Table 3.3.3-1 (page 1 of 1)

Post Accident Monitoring Instrumentation CODTINREEENE =FO CONDITION REFERENCED FROM FUNCTION REQUIRED CHANNELS 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. RG S Cold Leg Temperature (Wide Range) 1 per loop E (Tcold)

5. RCS Pressure (Wide Range) 2 E

6. Reactor Vessel Water Level 2(a) F

7. Ccntainment 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. Au> iliary 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 3.3-36 Amendment Nso.

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 3.3-37 Amendment NGo.

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 3.13.4.2 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 for each required 18 months instrumentation channel.

COMANCHE PEAK - UNITS 1 AND 2 3.3-38 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. RIS Hot Leg Temperature 1 per loop

4. RCS Cold Leg Temperature 1 per loop

5. Condensate Storage Tank Level 1

6. SG Pressure I per SG

7. SG Level 1 per SG

8. AFW Flow 1 per SG

9. Pressurizer Level I 10.Charging Pump to CVCS Charging and RCP 1 Seals Flow Indication COMANCHE PEAK - UNITS 1 AND 2 3.3-39 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

- NOTE -

Not applicable for 6.9 kV Preferred Offsite Source Undervoltage function when associated source breaker is open.

ACTIONS

- NOTES -

Separate Condition entry is allowed for each Function.

CONDITION REQUIRED ACTION COMPLETION TIME

- NOTE -

Not applicable to Automatic Actuation Logic and Actuation Relays Function A. 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 3.3-40 Amendment Ngo.

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.

voltsge 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 3.3-41 Amendment No.

LOP DG Start Instrumenlation 3.3.5 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. TwD 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.

vol-:age 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 3.3-42 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 ir MODE 5 for 2 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 2 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 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 3.3-43 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 Ž 5040 V

3. Alternate offsite source bus 2 per bus 3.3.5.2 f 5580 V and undervoltage 3.3.5.3 2 5040 V

4. 6.9 kv Class 1E bus 2 per bus 3.3.5.2

2115 V undervoltage 3.3.5.3 3.3.5.4

5. 6.9 kv Class 1E bus degraded 2 per bus 3.3.5.2 Ž 6024 V voltage 3.3.5.3 3.3.5.4

6. 481) V Class 1E bus low grid 2 per bus 3.3.5.2 2439 V undervoltage 3.3.5.3 3.3.5.4

7. 480 V Class 1E bus degraded 2 per bus 3.3.5.2 2 439 V voltage 3.3.5.3 3.3.5.4 COMANCHE PEAK - UNITS 1 AND 2 3.3-44 Amendment No.

Containment Ventilation Isolation Instrumentbtion

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

- NOTE -

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.

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 One or more Automatic gaseous effluent monitoring Actuation Logic and instrumentation requirements in Part I of Actuation Relays trains the ODCM.

inoperable.

OR B.1 Enter applicable Conditions and Immediately Required Actions of LCO 3.6.3, Required Action and "Containment Isolation Valves," for associated Completion containment ventilation isolation Time of Condition A not valves made inoperable by isolation met. instrumentation.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.3-45 Amendment No.

Containment Ventilation Isolation Instrumentation 3.3.6 ACTICNS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

- NOTE - - NOTE -

On y applicable during The containment pressure relief valves CORE ALTERATIONS or may be opened in compliance with the moiement 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 mel. OR C.2 Enter applicable Conditions and Immediately Required Actions of LCO 3.9.4, "Containment Penetrations," for containment ventilation isolation valves made inoperable by isolation instrumentation.

SURVEILLANCE REQUIREMENTS

- NOTE -

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 3.3-46 Amendment ego.

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 I AND 2 3.3-47 Amendment Nho.

Containment Ventilation Isolation Instrumentation 3.3.6 Table 3.3.6-1 (page 1 of 1)

Containment Ventilation Isolation Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE TRIP FUNCTION CONDITIONS CHANNELS REQUIREMENTS SETPOINT

1. Vanual Initiation 1, 2,3,4 Referto 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) Mus: 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 3.3-48 Amendment N~o.

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-',

shall be OPERABLE.

APPLICABILITY: According to Table 3.3.7-1 ACTIONIS

- NOTE -

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

- NOTE -

Applicable only to Functions 3a and 3b.

A.2 Secure the Control Room makeup air 7 days supply fan from the affected air intake.

(continued)

COMANCHE PEAK - UNITS I AND 2 3.3-49 Amendment Nho.

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 rnet in MODE 5 or 6, or during movement of D.2 Suspend movement of irradiated fuel Immediately irradiated fuel assemblies. assemblies.

COMANCHE PEAK - UNITS 1 AND 2 3.3-50 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 o sd S R 3.3.7.6 -------------------------------------------------------------------------------

- NOTE -

Verification of setpoint is not required.

Perform TADOT. 18 months SR 3.3.7.7 Perform CHANNEL CALIBRATION. 18 months COMANCHE PEAK - UNITS 1 AND 2 3.3-51 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 SETPOIIJT

1. Manual Initiation 1, 2, 3,4, 5, and 6, (a) 2 trains SR 3.3.7.6 NA

2. Au:omatic 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 10i4 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 10i4 South Intake SR 3.3.7.2 iCi/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 3.3-52 Amendment N~o.

RCS Pressure, Temperature, and Flow DNB Limits 3:.4.1 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.1 FRCS 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 2 the limit specified in the COLR;

b. RCS average temperature < the limit specified in the COLR; and

c. RCS total flow rate 2 389,700 gpm and 2 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.

(continu ad)

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. ----------- B.1 Maintain THERMAL POWER less Immediately

- NOTE - than 85% RTP.

Only applicable prior to exceeding 85% RTP after a refueling outage.

Measured RCS Flow not within 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.

SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.1.1 Verify pressurizer pressure is 2 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 5 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 2 389,700 and 2 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 2 389,700 and 2 the limit specified in the COLR.

COMANCHE PEAK - UNITS 1 AND 2 3.4-2 Amendment Igo.

RCS Minimum Temperature for Criti-ality 3.4.2 3.4 RE-ACTOR COOLANT SYSTEM (RCS) 3.4.2 RCS Minimum Temperature for Criticality LCO 3.4.2 Each operating RCS loop average temperature (Tavg) shall be 2 551'F.

APPLICABILITY: MODE 1, MODE 2 with keff > 1.0 ACTION4S CONDITION REQUIRED ACTION COMPLETION TIME A. Tavc 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 2 551OF. 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 P/T 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 ACTIONJS CONDITION REQUIRED ACTION COMPLETION TIME A- ---- A.1 Restore parameter(s) to within limits. 30 minutes

- NOTE -

Recuired Action A.2 shall AND be completed whenever this Condition is entered. 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.

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

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 I AND 2 3.4-4 Amendment No.

RCS P/T Limits 3.4.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.-- C.1 Initiate action to restore parameter(s) Immediately

- NOTE - to within limits.

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

-C.2 Determine RCS is acceptable for Prior to entering continued operation. MODE 4 Requirements of LCO not met any time in other than MODE 1, 2, 3, or4.

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 1AND 2 3.4-6 Amendment No.

RCS Loops - MOD)E 3 J.4.5 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.5 FICS 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 100 F below saturation temperature.

APPLICABILITY: MODE 3 ACTIOINS 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 Act~ion 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 ACTIO1JS (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 2 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 10% 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 3A.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.

- NOTES -

1. All reactor coolant pumps (RCPs) and RHR 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 100F below saturation temperature.

2. No RCP shall be started with any RCS cold leg temperature S3500F unless the secondary side water temperature of each steam generator (SG) is

50'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 inop erable. loop to OPERABLE status.

AND A.2 ---------

- NOTE-Onlreuired if one RHR loop is e iRABLE Be in MODE 5. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (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 > 10% for 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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

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 2 10%.

- 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 100F 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 < 3500F 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 3.4-1 2 Amendment No.

RCS Loops - MODE 5, Loops Filled 3.4.7 ACTIO \IS 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 limils. 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.

SURVELLANCE 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 Ž 10% in required 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months 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 3.4-1 3 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 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months provided:

a. The core outlet temperature is maintained at least 100F below saturation temperature.

b. No operations are permitted that would cause introduction of coolaIt 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 1AND 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 3.4-1 5 Amendment Nso.

Pressu izer 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 > 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 with n 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 Noo.

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 2 150 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 > 2460 psig and *2510 psig.

APPLICABILITY: MODES 1, 2, and 3, MODE 4 with all RCS cold leg temperatures > 3200 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 0F.

Two or more pressurizer safety valves inoperable.

COMANCHE PEAK - UNITS 1 AND 2 3.4-18 Amendment No.

Pressurizer Safety Va ves 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 \lo.

Pressurizer PORVs 3 4.11 3.4 REEACTOR 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

- NOTE -.

Separate Condition entry is allowed for each PORV.

CONDITION REQUIRED ACTION COMPLETION TIIVE 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 Ngo.

- ---

Pressurizer PC)RVs 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. Recuired 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 enet.

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-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.

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 Ngo.

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 2 436.5 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 Ž 436.5 psig and < 46:3.5 psig, or

d. The RCS depressurized and an RCS vent of Ž 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 allowec by the P/T limit curves provided in the PTLR.

- -- - -- - -- - - - -- -.--

-- - - - - - - - - - -- - - - - - -- - - - - - --.-- - -.--

APPLICABILITY: MODE 4, MODE 5, MODE 6 when the reactor vessel head is on

- NOTE -

The LCO is not applicable when all RCS cold leg temperatures are > 32001:

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.

(continu ad)

COMANCHE PEAK - UNITS I AND 2 3.4-25 Amendment \o.

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 > 3200 F.

Timo 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 600 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 0F.

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.

- m 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 2.98 square inches.

OR Required Action and associated Completion Time of Condition A, B, D, E, cr F not met.

OR LTCP 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.-A.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 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 < 350 0F.

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.- .13 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.13 RCS Operational 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;

d. 1 gpm total primary to secondary LEAKAGE through all steam generators for Unit 2 (SGs); and

e. 150 gallons per day for Unit 1 and 500 gallons per day for Unit 2 primary to secondary LEAKAGE through any one SG.

APPLICA~BILITY: MODES 1, 2, 3, and 4 ACTION_'S CONDITION REQUIRED ACTION COMPLETION TIME A. RCS LEAKAGE not within A.1 Reduce LEAKAGE to within limits. 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months limits for reasons other than pressure boundary 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.

COMANCHE PEAK - UNITS 1 AND 2 3.4-29 Amendment Igo.

RCS Operational LEAKAAGE 3.4.13 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.13.1 ----- ------------------------------- - ----------------------.

- 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.

Perform RCS water inventory balance. 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months SR 3.4.13.2 Verify steam generator tube integrity is in accordance with In accordance w th the Steam Generator Tube Surveillance Program. the Steam Generator Tube Surveillance Program 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

- NOTES -

1. Separate Condition entry is allovied 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 1.4.14 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more flow paths -

with leakage from one or - NOTE -

more RCS PIVs not within Each valve used to satisfy Required limnt. Action A.1 and Required Action A.2 must 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 SURVEIILLANCE 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 SURVE LLANCE 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 Ngo.

RCS Leakage Detection Instrumentation C.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 --------------------------------------------

Sump Level and Flow - NOTE -

Monitoring System Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after inoperable. 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 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 Analyze grab 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 -

Required containment air Not required until 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months after cooler condensate flow rate establishment of steady state monitor 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 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 SURVEEILLANCE 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 \lo.

RCS Specific Activity 3A4.16 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.16 RCS Specific Activity LCO 3.4.16 The specific activity of the reactor coolant shall be within limits.

APPLICABILITY: MODES 1 and 2, MODE 3 with RCS average temperature (Tavg) 2 500'F.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. DOSE EQUIVALENT 1-131-

> 0.45 pCi/gm. - NOTE -

LCO 3.0.4.c is applicable.

A.1 Verify DOSE EQUIVALENT 1-131 Once per4 hours within the acceptable region of Figure 3.4.16-1.

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. Gross specific activity of the B.1 Be in MODE 3 with Tavg < 500 0 F. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months reactor coolant 2 100/E pci/gm.

(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 with Ta.g < 500 0F. 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months associated Completion Time of Condition A not met.

OR DOSE EQUIVALENT 1-131 in the unacceptable region of Figure 3.4.16-1.

SURVE:ILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.16.1 Verify reactor coolant gross specific activity < IOO/E 7 days

[Ci/gm.

SR 3.4.16.2 ---------------------------------------------------------------------------

- NOTE -

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 2 15%

RTP within a 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months period (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.4-40 Amendment No.

RCS Specific Activity 3.4.16 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.4.16.3 -------------------------------------------------------------------------------

- NOTE -

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

Determine E from a sample taken in MODE 1 after a 184 days minimum of 2 effective full power days and 20 days of MODE 1 operation have elapsed since the reactor was last subcritical for > 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months .

COMANCHE PEAK - UNITS 1 AND 2 3.4-41 Amendment No.

RCS Specific Activity 3.4. 16 300 0_

250

-

UNAC EPTAB E OPER TION 0

0 LL 200 AL 0~

at C,)

I-z

-J 150 0

0 0

a-cl) 100 AC EPTABLE w OP RATIO I-z I_ 50 w

at a_j

,

U) 0 a

0 20 30 40 50 60 70 80 90 100 PERCENT OF RATED THERMAL POWER Figure 3.4.16-1 (page 1 of 1)

Reactor Coolant DOSE EQUIVALENT 1-131 Specific Activity Limit Versus Percent of RATED THERMAL POWER COMANCHE PEAK - UNITS 1 AND 2 3.4-42 Amendment No.

Accumulators 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) 3.5.1 Accumulators LCO '.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 Nlo.

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 Ž 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 2 623 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 2 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 2 101 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.

- NOTE-

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 cf all RCS cold legs exceeds 375 0F, 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 cent ifugal 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)

COMANC(HE PEAK - UNITS 1 AND 2 3.5-4 Amendment Nio.

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 trash racks and screens 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.

- NOTE -

An RHR train may be considered OPERABLE during alignment and operation for decay heat removal, if capable of being manually realigned to the ECC'S 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 witi 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 limils.

B. RW.ST 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 1AND 2 3.5-8 Amendment No.

RWST

,.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 2 40'F and 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months

< 120 0F.

SR 3.5.4.2 Verify RWST borated water volume is Ž 473,731 gallons. 7 days SR 3.5.4.3 Verify RWST boron concentration is 2 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 s 40 gpm with RCS pressure

> 2215 psig and

2255 psig and the charging flow control valve full open APPLIC ABILITY: 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 Ž 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 I AND 2 3.5-10 Amendment No.

Contair ment 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. Recuired 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 Tima 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 3.13.2 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 air locks with one - NOTES -

cortainment air lock door 1. Required Actions A.1, A.2, and A.3 inoperable. are not applicable if both doors in the 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 air locks with containment - NOTES -

air lock interlock 1. Required Actions B.1, 8.2, and B.3 me.hanism inoperable. are not applicable if both doors in the same 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 ACTIONJS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One or more containment C.1 Initiate action to evaluate overall Immediately air 1Dcks 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 0.6.2 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 wiih 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 3.3.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. A.1 Isolate the affected penetration flow 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

- NOTE- path by use of at least one closed Only applicable to and de-activated automatic valve, penetration flow paths with closed manual valve, blind flange, or two containment isolation check valve with flow through the valves. valve secured.

AND One or more penetration flow Daths with one containment isolation valve A.2 inoperable except for - 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.- B.1 Isolate the affected penetration flow 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months

- NOTE - path by use of at least one closed Only applicable to and de-activated automatic valve, penetration flow paths with closed manual valve, or blind flange.

two containment isolation valves.

One or more penetration flow paths with two containment isolation valves inoperable except 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 Ngo.

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C.- C.1 Isolate the affected penetration flow 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months

- NOTE - path by use of at least one closed Only applicable to and de-activated automatic valve, penetration flow paths with closed manual valve, or blind flange.

onl,/ one containment isolation valve and a closed AND system.

.. 2 One or more penetration - 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 fow paths with one or path by use of at least one closed more containment and de-activated automatic valve, purge, hydrogen purge closed manual valve, or blind flange.

cr containment pressure relief valves not within AND leakage limits.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-1 0 Amendment No.

Containment Isolation Valves 3.6.3 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. (con:inued) D.2 --------------------------------------------------

- NOTES-

1. Isolation devices in high radiation areas may be verified by use of administrative means.

2. Isolation devices that are locked, sea 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 3.6-1 1 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 ------------------------------------------------------------------------------

- NOTE -

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 --

- NOTE -

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 the containment isolation valves that are open under previous 92 days administrative controls.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-1 2 Amendment Ngo.

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.

COMANCHE PEAK - UNITS 1 AND 2 3.6-1 3 Amendment No.

Containment Pressure 3.6.4 3.6 CONTAINMENT SYSTEMS 3.6.4 Containment Pressure LCO '-.6.4 Containment pressure shall be 2 - 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 < 1200 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 '-,.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. Recuired 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 TimD 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.

SURVE'LLANCE 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 3.6-1 6 Amendment No.

Containment Spray System 3.6.6 SURVEILLANCE REQUIREMENTS (continued)

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 S R 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 each spray additive manual, power operated, and 31 days automatic valve in the flow path that is not locked, sealed, or otherwise secured in position is in the correct position.

SR 3.6.7.2 Verify spray additive tank solution level is 2 91% and 184 days

< 94%.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.6-18 Amendment No.

Spray Additive System 3.6.7 SURVIEILLANCE REQUIREMENTS (continued)

SR 3. '.7.3 Verify spray additive tank NaOH solution concentration is 2 184 days 28% and < 30% by weight.

SR 3.6.7.4 Verify each spray additive automatic valve in the flow path 18 months that is not locked, sealed, or otherwise secured in position, actuates to the correct position on an actual or simulated actuation signal.

SR 3.6.7.5 Verify spray additive flow from each solution's flow path. 5 years COMANCHE PEAK - UNITS 1 AND 2 3.6-1 9 Amendment No.

MSS'Vs 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 ACTION S

- NOTE -

Separate Condition entry is allowed for each MSSV.

------ ---

--- ---

---

--- ------ --- --- ---- --- --- --- --- ---- --- --- --- --- ---- --- --- --- ----..

CONDITION REQUIRED ACTION COMPLETION TIM_

A. One or more steam A. Reduce THERMAL POWER to <87% 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 Ngo.

MS SVs 3.7.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. One or more steam B.1 Reduce Thermal Power to 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 inoperable and the MTC - NOTE -

posilive at any power level. Only required in MODE 1.

B.2 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 2 4 MSSVs inoperable.

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

MSSVs

3.7.1 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENC" SR 3.7.1.1 ------------------------------------------------------------------------------

- NOTE -

Only required to be performed in MODES 1 and 2.

I----n accordance with Verify each required MSSV lift setpoint per Table 3.7.1-2 in the Inservice accordance with the Inservice Testing Program. Following Testing Program testing, lift setting shall be within +/- 1%.

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 <87 3 <65 2 <43 COMANCHE PEAK - UNITS 1 AND 2 3.7-4 Amendment Igo.

M ;SVs

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%)

2 #3 #4 MS-021 MS-058 MS-093 MS-1 29 1185 MS-022 MS-059 MS-094 MS-130 1195 MS-023 MS-060 MS-095 MS-131 1205 MS-024 MS-061 MS-096 MS-132 1215 PAS-025 MS-062 MS-097 MS-133 1235 COMANCHE PEAK - UNITS 1 AND 2 3.7-5 Amendment No.

MS IVs 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. - -- C.1 Close MSIV. 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months

- NOTE -

Separate Condition entry is AND allowed for each MSIV.

- - - C.2 Verify MSIV is closed. Once per 7 days One or more MSIV inoperable in MODE 2 or 3.

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 (FlVs) 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 TIMVE 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 (continu ad)

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 flovipath 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 Tirrie 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 S R 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 I AND 2 3.7-1 0 Amendment No.

ARVs

3.7.4 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.4.1 Verify one complete cycle of eaph ARV. In accordance w th the Inservice testing Program SR 3.;.4.2 Verify one complete cycle of each ARV block valve. In accordance with the Inservice testing Program COMANCHE PEAK - UNITS 1 AND 2 3.7-1 1 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 ACTION S

- 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. AND 10 days from discovey of failure to meet the LCO 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. AND 10 days from discovery of failure to meet the LCO (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-1 2 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. --------------------------------------------

inoperable. - NOTE -

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 I AND 2 3.7-1 3 Amendment Ngo.

AFW System 3.7.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.5.1

- NOTE -

Not required to be performed for each flow control valve in the flow paths until the AFW system is in standby for automatic actuation or until the unit is above 10% RATED THERMAL POWER, whichever comes first.

Verify each AFW manual, power operated, and automatic 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 2 532 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 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.

SR 3.7.5.4 -------------------------------------------------------------------------------

- 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 2 532 psig in the steam generator.

Verify each AFW pump starts automatically on an actual or 18 months simulated actuation signal.

COMANCHE PEAK - UNITS 1 AND 2 3.7-1 4 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 2 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 2 53%. 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-15 Amendment No.

CCW System 3.7.7 3.7 PI-ANT SYSTEMS 3.7.7 Component Cooling Water (CCW) System LCO ',.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. A.1 --------------------------------------------

- 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.

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 3.7-1 6 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 3.7-1 7 Amendment N\o.

S SWS 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 ACTIO \IS 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 to OPERABLE status. 7 days (continued)

COMANCHE PEAK- UNITS 1 AND 2 3.7-1 8 Amendment No.

S'z3WS 3.7.8 ACTIONS (continued)__

CONDITION REQUIRED ACTION COMPLETION TIME B. One SSWS train B.1 ----------------------------------------------

inoperable. - NOTES -

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 rnet.

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 I AND 2 3.7-1 9 Amendment No.

SS'NS 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 3.7-20 Amendment Ngo.

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 ACTIO \IS 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 2 770 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 5 102 0F. 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months COMANCHE PEAK - UNITS 1 AND 2 3.7-21 Amendment No.

CFREFS 3.7.10 3.7 PLANT SYSTEMS 3.7.10 Control Room Emergency Filtration/Pressurization System (CREFS)

LCO 37.10 Two CREFS trains shall be OPERABLE

- NOTE -

The Control Room 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. Two CREFS Trains B.1 Restore control room boundary to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months inoperable due to OPERABLE status.

inoperable Control Room OR boundary in MODES 1, 2, 3, and 4. 14 days for a one time implementation for each unit of the Turbine Generator Protection System Digital Modification to be completed during 1RF11 and 2RF09 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.7-22 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 except for up to 14 days for E.2 Suspend movement of irradiated fuel Immediately a one time implementation assemblies.

for each unit of the Turbine Generator Protection System Digital Modification to be completed during 1RFl1 and 2RF09.

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

COMANCHE PEAK - UNITS 1 AND 2 3.7-23 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 2 10 continuous hours with the heaters operating and Emergency Filtration Unit 2 15 minutes.

SR 3.7.10.2 Perform required CREFS testing in accordance with the In accordance with Ventilation Filter Testing Program (VFTP). VFTP SR 3. '.10.3 Verify each CREFS train actuates on an actual or simulated 18 months actuation signal.

SR 3.7.10.4 Verify one CREFS train can maintain a positive pressure of 18 months on a

Ž 0.125 inches water gauge, relative to the adjacent areas STAGGEREDTEST during the emergency recirculation mode of operation at a BASIS makeup flow rate of < 800 cfm.

COMANCHE PEAK - UNITS 1 AND 2 3.7-24 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, or4.

B.2 Be in MODE 5. 36 hours4.166667e-4 days 0.01 hours 5.952381e-5 weeks 1.3698e-5 months C. Reqjired 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 3.7-25 Amendment No.

CRACS 3.;'.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 3.7-26 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 3.7-27 Amendment Igo.

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 APPLIGABILITY: 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 2 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 2 0.01 inch water gauge in the Auxiliary, pressure.

Safeguards, and Fuel Buildings 2 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 3.7-28 Amendment No.

PPVS - ESF Filtration Trains 3.7.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.7.12.1 Operate each ESF Filtration train for 2 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 TEST BASIS pressure during the post accident mode of operation.

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 3.7-29 Amendment Noo.

FEACS 3.7.13 3.7 PLANT SYSTEMS 3.7.13 Fuel Building Air Cleanup System (FBACS)

NOT USED COMANCHE PEAK - UNITS 1 AND 2 3.7-30 Amendment No.

la 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 3.7-31 Amendment No.

Fuel Storage Area Water Level 3.7.15 3.7 PL.ANT SYSTEMS 3.7.15 Fuel Storage Area Water Level LCO 3.7.15 The fuel storage area water level shall be 2 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 --------------------------------------------

level not within limit. - NOTE -

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 2 23 ft above the 7 days top of the storage racks.

COMANCHE PEAK - UNITS 1 AND 2 3.7-32 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 Ž 2000 ppm.

APPLICABILITY: When fuel assemblies are stored in the fuel storage pool.

ACTION\JS CONDITION REQUIRED ACTION COMPLETION TIME A. Fuel storage pool boron concentration not within - NOTE -

limit. LCO 3.0.3 is not applicable.

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 3.7-33 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 1out 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 ------------------------------------------

not met. - NOTE -

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 3.7-34 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 3.7-35 Amendment No.

Spent Fuel Assembly Storage 3.7.17 Decay 65000 Time:

0 Years 60000

............--. ......... ....

55000

.-.-.--------------------

50000

-* 45000 F -- ---- ---------. ... .. .. . . . .....

C 40000 C.

= 35000 m

> 30000 E

(In Ahl 25000 LI. 20000

.

15000 10000 -IUNACCEPTABLE 5000 0

1.0 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 II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-36 Amendment No.

Spent Fuel Assembly Storage 3.7.17 45000 Decay Time:

0 Years

--. . -......-.-..... ..... ....

40000

........... ~

35000 1- 30000

a. 25000 I

0

.0 20000 E

U,

------ -- - ---- ~

In

= 15000 --------

LI.

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 3.7-37 Amendment No.

Spent Fuel Assembly Storage 3.7.17 20000

-

,I II :! ;

I ; - I-L-i i :

I i i i j ; I i

. L-I -- II i _.1:

i I I I i

, 1!i

!

IIi i I I !

I i ,

I!

. I

.. .... ----------

15000 E

-

- rIiiI_-__7 Z ACCEPTABLE ] . ..... . ..

G a.

CL

==....e*_F~~~~~.

.. ..... . ,.__=_.'_.=

= 10000 m

E UZ 03 .. . i__ II I;

,!.

...... .. . ;. .. .. ........

91) a)

IL 5000 I. - .__ :.ACCE PTABLE]

.,-I .

,~~~~~~~~~~~~~-

- - - -- -..........

.__..

......

__

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 3.7-38 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 A A AA A A A A A A A AL A A A A A A B B B A A AA A A B BB B B B C *C C D __ _

_ C C C C C I C_

I C C C

_ I C I 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 Ill1 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, 214, 1/4) in Region II Racks COMANCHE PEAK - UNITS 1 AND 2 3.7-39 Amendment No.

Secondary Specific Activity 3.7.18 3.7 PI-ANT SYSTEMS 3.7.18 Secondary Specific Activity LCO 3 .7.18 The specific activity of the secondary coolant shall be < 0. 10 pCi/gm DOISE 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 SR 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 3.7-40 Amendment No.

Safety Chilled Water 3.7.19 3.7 PLANT SYSTEMS 3.7.19 Safety Chilled Water LCO 13.7.19 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 COMANCHE PEAK - UNITS 1 AND 2 3.7-41 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 3.7-42 Amendment Ngo.

UPS HVAC System 3.7.20 3.7 PLANT SYSTEMS F

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 I AND 2 3.7-43 Amendment No.

UPS HVAC System 3.7.20 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME 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.

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 3.7-44 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 2 1 continuous hour.

SR 3.7.20.2 Verify each required UPS A/C train operates for 2 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 3.7-45 Amendment No.

AC Sources - Operating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC Sources - Operating LCO 3.3.1 *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 1E power distribution subsystem(s); and

c. Automatic load sequencers for Train A and Train B.

APPLICABILITY: MODES 1, 2, 3, and 4 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 REQUIRED 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

- NOTE -

In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

A.2 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 (continued)

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

AC Sources - Operating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) 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.

AND 6 days from discovery of failure to meet LCO OR 21 days for a one time preventive maintenance outage on Startup Transformer XST2 tc* be completed by February 28, 2002 (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-3 Amendment No.

AC Sources - Operaling 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION l_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

- NOTE-In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

---

--- ---- --- ---- --- ---- -- .

B.2 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

- NOTE -

The SR need not be performed if the DG is already operating and loaded.

B.3.2 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 3.8-4 Amendment No.

AC Sources - Operating 3.8.1 ACTICNS (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 AND 6 days from discover of failure to meet LCO C. Two required offsite circuits inoperable. - NOTE -

In MODES 1, 2 and 3, the TDAFW pump is considered a required redundant feature.

C.1 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.

(continL ed)

COMANCHE PEAK - UNITS 1 AND 2 3.8-5 Amendment No.

AC Sources - Operating

3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One required offsite circuit inoperable. - NOTE -

Enter applicable Conditions and AND Required Actions of LCO 3.8.9, "Distribution Systems - Operating,"

One DG inoperable. when Condition D is entered with no AC power source to any 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 inoperable. - NOTE -

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.

F.1 Restore Sl sequencer to OPERABLE 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-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 3.8-6 Amendment No.

AC Sources - Operating 3.B.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 Ž 6480 V and < 7150 V, and frequency Ž 58.8 Hz and < 61.2 Hz.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-7 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SR 3.B.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 2 60 minutes at a load Ž 6300 kW and < 7000 kW.

SR 3.8.1.4 Verify each day tank contains 2 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.E.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 3.8-8 Amendment No.

AC Sources - Operating 3.3.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY 1-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: 184 days

a. in

10 seconds, voltage Ž 6480 V and frequency >

58.8 Hz; and

b. steady state, voltage Ž 6480 V and

7150V, and frequency 2 58.8 Hz and

61.2 Hz.

SR 3.81.8 ------------------------------------------------------------------------------

- NOTE-Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 3.8-9 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENC Y SR 3.8.1.9

- NOTE -

Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 -------------------------------------------------------------------------------

- NOTE -

Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

Verify each DG does not trip and voltage is maintained

18 months 8280 V during and following a load rejection of 2 6300 kW and < 7000 kW.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-10 Amendment No.

AC Sources - Operat ng 3.13.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.11 --

-NOTES-

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

2. Verify requirement during MODES 3,4, 5, 6 or with core off-loaded.

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 2 6480 V and

< 7150 V,

4. maintains steady state frequency Ž 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 3.8-1 1 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.12 ------------------------------------------------------------------------------

- NOTES -

1. All DG starts may be preceded by prelube period.

2. Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 2 6480 V and frequency 2 58.8 Hz;

b. Achieves steady state voltage 2 6480 V and < 7150 V and frequency 2 58.8 Hz and < 61.2 Hz;

c. Operates for 2 5 minutes; SR 3.8.1.13 ----------------------------------------------------------------------------

- NOTE -

1. Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

2. For Unit 2, testing need only be performed for LOOP concurrent with SI until startup following 2RF05.

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 3.8-1 2 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.14 ------------------------------------------------------------------------------

- NOTES -

1. Momentary transients outside the load and power factor ranges do not invalidate this test.

2. Verify requirement during MODES 3,4, 5, 6 or with core off-loaded.

Verify each DG operates for 2 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months s: 18 months

a. For Ž 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 6900 kW and < 7700 kW; and

b. For the remaining hours of the test loaded 2 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 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months loaded 2 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 Ž 6480 V and frequency >

58.8 Hz; and

b. steady state, voltage Ž 6480 V and < 7150 V and frequency 2 58.8 Hz and < 61.2 Hz.

(continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-13 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued)

SURVEILLANCE FREQUENCY SR 3.8.1.16---

-NOTE-Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 -

Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 3.8-1 4 Amendment No.

AC Sources - Operating 3.8.1 SURVEILLANCE REQUIREMENTS (continued) _

SURVEILLANCE FREQUENCY SR 3.8.1.18 ------------------------------------------------------------------------------

-NOTE-Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 3.8-1 5 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. Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

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 2 6480 V and

< 7150 V,

4. achieves steady state frequency 2 58.8 Hz and *61.2 Hz, and

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

> 5 minutes.

(continued)

COMANC HE PEAK - UNITS 1 AND 2 3.8-16 Amendment No.

AC Sources - Operating 3.3.1 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 2 6480 V and frequency >

58.8 Hz, and

b. steady state, voltage 2 6480 V, and < 7150 V and frequency 2 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 3.8-1 7 Amendment N,,o.

AC Sources - Shutdown 3.8.2 3.8 EL.ECTRICAL 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 1E 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 1E AC electrical power distribution subsystems required by lCO 3.8.10.

APPLICABILITY: MODES 5 and 6 COMANCHE PEAK - UNITS 1 AND 2 3.8-18 Amendment No.

AC Sources - Shutdown 3.8.2 ACTICNS CONDITION REQUIRED ACTION COMPLETION TIME A. One required offsite circuit --------------------------------------------------------

inoperable. - NOTE -

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 3.8-1 9 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 SR 3.8.2.1

- NOTE -

The following SRs are not required to be performed: SR 3.8.1.3, SR 3.8.1.9 through SR 3.8.1.1 1, SR 3.8.1.14, SR 3.8.1.15, and SR 3.8.1.16.

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 3.8-20 Amendment No.

Diesel Fuel Oil, Lube Oil, and Starting Air C.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 with n limits for each required diesel generator (DG).

APPLICABILITY: When associated DG is required to be OPERABLE.

ACTIONS

- NOTE -

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 3.8-21 Amendment N>o.

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 1AND 2 3.8-22 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 2 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 2 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 2 180 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 3.8-23 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 3.8-24 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 Ž 300 amps at greater 18 months than or equal to the minimum established charger test voltage for 2 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months .

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 I AND 2 3.8-25 Amendment No.

DC Sources - Opera :ing 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.

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

COMANCHE PEAK - UNITS 1 AND 2 3.8-26 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.

COMAN\'CHE PEAK - UNITS 1 AND 2 3 .8-27 Amendment No.

DC Sources - Shutdown 3.8.5 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY

+

SR 3.8.5.1

- NOTE -

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 3.8-28 Amendment No.

Battery Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Parameters LCO 3.3.6 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 or two 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 2.07 V.

B. One or two batteries on 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 I AND 2 3.8-29 Amendment No.

Battery Parameters 3.8.6 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME

- NOTE - - NOTE -

Required Action C.2 shall be Required Actions C.1 and C.2 are only completed if electrolyte level applicable if electrolyte level was below was below the top of plates. the top of plates.

C. 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 or two 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 3.8-30 Amendment No.

Battery Paramelers 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 Ž 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 3.8-31 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 3.3.6.5 Verify each battery connected cell voltage is 2 2.07 V. 92 days SR 3.13.6.6 -------------------------------------------------------------------------------

- NOTE -

Verify requirement during MODES 3, 4, 5, 6 or with core off-loaded.

Verify battery capacity is 2 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 reacted 85% of the expected life with capacity

Ž 100% of manufacturer's rating COMANCHE PEAK - UNITS 1 AND 2 3.8-32 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 TIVE A. One required inverter A.1 --------------------------------------------------

inoperable. - NOTE -

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 3.8-33 Amendment No.

Inverters - Operaling 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 3.8-34 Amendment No.

Inverters - Shutdown 3.8.8 3.8 ELECTRICAL POWER SYSTEMS 3.8.8 Inverters - Shutdown LCO 2.8.8 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 ACTIONJS 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 3.8-35 Amendment No.

Inverters - Shutdown

3.8.8 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.3.8.1 Verify correct inverter voltage and alignments to required 7 days AC vital buses.

COMANCHE PEAK- UNITS 1 AND 2 3.8-36 Amendment No.

Distribution Systems - Operaling 3.8.9 3.8 ELECTRICAL POWER SYSTEMS 3.8.9 Distribution Systems - Operating LCO 3.13.9 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 TIM_

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. AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCC)

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.

AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCC)

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. AND 16 hours1.851852e-4 days 0.00444 hours 2.645503e-5 weeks 6.088e-6 months from discovery of failure to meet LCO (continued)

COMANCHE PEAK - UNITS 1 AND 2 3.8-37 Amendment No.

Distribution Systems - Operating 3.8.9 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 E. Two trains with inoperable E.1 Enter LCO 3.0.3. Immediately distribution subsystems that result in a loss of safety function.

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 3.8-38 Amendment No.

Distribution Systems - Shutdown 3.E.10 3.8 ELECTRICAL POWER SYSTEMS 3.8.10 Distribution Systems - Shutdown LCO 3.3.10 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.

elec:rical 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 3.8-39 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.

SURVE:ILLANCE 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 3.8-40 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

- NOTE -

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 0.9.2 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 -,he closed position.

APPLICABILITY: MODE 6.

ACTIONS

- NOTE -

Separale Condition entry is allowed for each unborated water source isolation valve.

CONDITION REQUIRED ACTION COMPLETION TIIVE A. ------ -------- A.1 Suspend CORE ALTERATIONS. Immediately

- NOTE -

Required Action A.4 must AND be completed whenever Condition A is entered. A.2 Suspend positive reactivity addition. Immediately AND One or more valves not secured in closed position. 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 SURVE ILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.'3.2.1 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 Igo.

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 SR 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 L.evel

3.9.5 3.9 REEFUELING 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.

- NOTE -

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 2 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 L.evel

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 2 23 ft Immediately of water above the top of reactor vessel flange.

(continued, COMANCHE PEAK - UNITS 1 AND 2 3.9-1 0 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 Ž 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 3.9-1 1 Amendment No.

Refueling Cavity Water L.evel

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 2 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. Refieling 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 2 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 3.9-1 2 Amendment No.

Design Features 4.0 4.0 DE SIGN FEATURES 4.1 Si:e 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 (UO2 ) 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 approvec 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 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 IIfuel storage racks (as shown in Figure 3.7.17-4) or unrestricted storage in Region I fuel storage racks;

9. 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 4 out of 4 configuration in Region II fueli storage racks as shown in Figure 3.7.17-4;

h. New or partially spent fuel assemblies with a discharge burnup n 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

i. 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.

COMAN'CHE 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 storace 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 his absence.

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 1,,Io.

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 corpo-ate 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 End an additional non-licensed operator shall be assigned if either 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 I 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. -------------------------- 7------------------- 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 AD)MINISTRATIVE 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), 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, Mtay 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 to NUREG-0737, Supplement 1, as stated in Generi:

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.

5.5.1.1 Licensee initiated changes to the ODCM:

a. Shall be documented and records of reviews performed shall be retained. This documentation shall contain:

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

and

2. 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, dcse, or setpoint calculations;

b. Shall become effective after the approval of the Plant Manager; and

c. 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 Prcgrams and Manuals 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 releasec 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; COMAN'CHE 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 l;

9. 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 ard 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 l;

i. Limitations on the annual and quarterly doses to a member of the public, beyond the site boundary, from iodine-131, iodine-133, tritium, and all radionuclides in particulate form with half lives > 8 days in gaseous effluerts 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 I AND 2 5.5-3 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.7 Reactor Coolant Pump FlVwheel Inspection Program 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 specified in Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as follows:

ASME Boiler and Pressure Vessel Code Required Frequencies for and applicable Addenda terminology for performing inservice testing 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 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 Boiler and Pressure Vessel 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 5.5.9 Steam Generator (SG) Tube Surveillance Program Each steam generator shall be demonstrated OPERABLE by performance of the following augmented inservice inspection program.

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

a. Steam Generator Sample Selection and Inspection - Each steam generator shall be determined OPERABLE during shutdown by selecting and inspecting at least the minimum number of steam generators specified in Table 5.5-'l.

b. Steam Generator Tube Sample Selection and Inspection - The steam generator tube minimum sample size, inspection result classification, and the corresponding action required shall be as specified in Table 5.5-2 or 5.5-'-,.

Table 5.5-2 applies to all tubes except repaired tubes (Unit 1 only) which are covered by Table 5.5-3. The inservice inspection of steam generator tubes shall be performed at the frequencies specified in Specification 5.5.9d., arid the inspected tubes shall be verified acceptable per the acceptance criteria of Specification 5.5.9e. The tubes selected for each inservice inspection per Table 5.5-2 shall include at least 3% of all the expanded tubes and at least 3%

of the remaining number of tubes in all steam generators; the tubes selected for these inspections shall be selected on a random basis except:

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

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

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

ii. Tubes in those areas where experience has indicated potential problems, and iii. A tube inspection (pursuant to Specification 5.5.9e.1 .h)shall be performed on each selected tube. If any selected tube does not permit the passage of the eddy current probe for a tube inspection, this shall be recorded and an adjacent tube shall be selected and subjected to a tube inspection.

iv. Indications left in service as a result of the application of the tube support plate voltage repair criteria shall be inspected by bobbin probe during all future refueling outages.

COMANCHE PEAK - UNITS 1AND 2 5.5-5 Amendment No.

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

3. The tubes selected as the second and third samples (if required by Table 5.5.9-2 during each inservice inspection may be subjected to a partial tube inspection provided:

i. The tubes selected for these samples include the tubes from those areas of the tube sheet array where tubes with imperfections were previously found, and ii. The inspections include those portions of the tubes where imperfections were previously found.

4. Implementation of the steam generator tube/tube support plate repair criteria requires a 100% bobbin coil inspection for hot-leg and cold-leg tube support plate intersections down to the lowest cold-leg support with known outside diameter stress corrosion cracking (ODSCC) indications. The determination of the lowest cold leg tube support plate intersections having ODSCC indications shall be based on the performance of at least a 20% random sampling of the tubes inspected over their full length.

The results of each sample inspection shall be classified into one of the following three categories:

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

In all inspections, previously degraded tubes must exhibit significant (grea:er than 10%) further wall penetrations to be included in the above percentage calculations.

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

C-2 One or more tubes, but not more than 1% of the total tubes inspected are defective, or between 5% and 10% of the total tubes inspected are degraded tubes.

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

COMANCHE PEAK - UNITS 1 AND 2 5.5-6 Amendment No.

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

c. Steam Generator F*Tube Inspection (Unit 1 only) - In addition to the minimum sample size as determined by Specification 5.5.9.b., all F*tubes will be inspected within the tubesheet region. The results of the inspections of F*

tubes identified in previous inspections will not be a cause for additional inspections per Tables 5.5-1 and 5.5-2.

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

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

Subsequent inservice inspections shall be performed at intervals of not less than 12 nor more than 24 calendar months after the previous inspection. If two consecutive inspections, not including the preservice inspection, result in all inspection results falling into the C-1 category or if two consecutive inspections demonstrate that previously observed degradation has not continued and no additional degradation has occurred, the inspection interval may be 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 5.5.9d.1; the interval may then be extended to a maximum of once per 40 months; and

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

i. Primary-to secondary tube leaks (not including leaks originating from tube-to-tube sheet welds) in excess of the limits of Specification 3.4.5.2, or ii. A seismic occurrence greater than the Operating Basis Earthquake, or iii. A loss-of-coolant accident requiring actuation of the Engineered Safety Features, or iv. A main steam line or feedwater line break.

COMANCHE PEAK - UNITS 1 AND 2 5.5-7 Amendment No.

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

e. Acceptance Criteria

1. As used in this specification:

i. Imperfection means an exception to the dimensions, finish, or contour of a tube from that required by fabrication drawings or specifications. Eddy-current testing indications below 20% of the nominal tube wall thickness, if detectable, may be considered as imperfections; ii. Degradation means a service-induced cracking, wastage, wear, or general corrosion occurring on either inside or outside of a tube; iii. Degraded Tube means a tube containing imperfections greater than or equal to 20% of the nominal wall thickness caused by degradation; iv. % Degradation means the percentage of the tube wall thickness affected or removed by degradation;

v. 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; vi. Plugging or Repair Limit means the imperfection depth at or beyond which the tube shall be removed from service by plugging or (for Unit 1 only) repaired by sleeving and is equal to 40% of the wall thickness. The plugging limit for laser welded sleeves is equal to 43% of the nominal wall thickness. The plugging limit for Leak Tight sleeves is equal to 20% of the nominal wall thickness. This definition does not apply to that portion of the Unit 1 tubing that meets the definition of an Ft tube. This definition does not apply to tube support plate intersections for which the voltage-based plugging criteria are being applied. Refer to 5.5.9e.1 m) for the repair limit applicable to these intersections. All tubes repaired with Leak Limiting sleeves shall be plugged upon detection of degradation in the sleeve and/or pressure boundary portion of the original tube wall in the sleeve/tube assembly (i.e., the sleeve-to-tube joint) regardless of depth. The F* criteria is not applicable to the parent tube located behind the Leak Limiting sleeves installed in the tubesheet transition zone; COMANCHE PEAK - UNITS 1AND 2 5.5-8 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Tube Surveillance Program (continued) vii. Unserviceable describes the condition of a tube if it leaks or contains a defect large enough to affect its structural integrity in the event of an Operating Basis Earthquake, a loss-of-coolant accident, or a steam line or feedwater line break as specified in Specification 5.5.9d.3, above; viii. Tube Inspection means an inspection of the steam generator tube from the tube end (hot leg side) completely around the U-bend to the top support of the cold leg. For a tube repaired by sleeving (for Unit 1 only) the tube inspection shall include the sleeved portion of the tube; ix. Preservice Inspection means an inspection of the full length of each tube in each steam generator performed by eddy current techniques prior to service to establish a baseline condition of the tubing. This inspection shall be performed prior to initial POWER OPERATION using the equipment and techniques expected to be used during subsequent inservice inspections;

x. F* Distance (Unit 1 only) is the distance of the hardroll expanded portion of a tube which provides a sufficient lengti of non-degraded tube expansion to resist pullout of the tube from the tubesheet. The F* distance is equal to 1.13 inches, plus. an allowance for eddy current measurement uncertainty, and i; measured down from the top of the tubesheet, or the bottom of the roll transition, whichever is lower in elevation. The F*

criteria is not applicable to the parent tube located behind the Leak Limiting sleeves installed in the tubesheet transition zone; xi. F* Tube (Unit 1 only) is that portion of the tubing in the area of the tubesheet region below the F* distance with a) degradation below the F* distance equal to or greater than 40%, b) which has no indication of degradation within the F* distance, and c) that remains inservice; xii. Hard Roll Expansion (Unit 1 only) isthat portion of a tube which has been increased in diameter by a rolling process such that no crevice exists between the outside diameter of the tube and the hole in the tubesheet; and COMANCHE PEAK - UNITS 1 AND 2 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Tube Surveillance Program (continued) xiii. For Unit 1 only, the Tube Support Plate Plugging Limit is used for the disposition of alloy 600 steam generator tubes for continued service that are experiencing predominantly axially oriented outside diameter stress corrosion cracking confined within the thickness of the tube support plates and flow distribution baffle (FDB). At tube support plate intersections (and FDB), the plugging limit is based on maintaining steam generator tube serviceability as described below:

1. Steam generator tubes, whose degradation is attribL ted to outside diameter stress corrosion cracking within the bounds of the tube support plate with bobbin voltages less than or equal to the lower voltage repair limit (1.0 volt), will be allowed to remain in service.

2. Steam generator tubes, whose degradation isattributed to outside diameter stress corrosion cracking within the bounds of the tube support plate with the bobbin voltage greater than the lower voltage repair limit (1.0 volt), will be repaired, except as noted in 5.5.9e.1.xiii.3.

below.

3. Steam 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.

4. Certain intersections as identified in WPT-1 5949 will be excluded from application of the voltage-based repair criteria as it is determined that these intersections may collapse or deform following a postulated LOCA + SSE event.

The upper voltage repair limit is calculated according to the methodology in GL 95-05 as supplemented

- VURL will differ at the TSPs and flow distribution baffle.

COMANCHE PEAK - UNITS 1 AND 2 5.5-1 0 Amendment No.

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

5. If an unscheduled mid-cycle inspection is performed, the following mid-cycle repair limits apply instead of the limits identified in 5.5.9e.1.xiii.1., 5.5.9e.1.xiii.2., and 5.5.9e.1.xiii.3. The midcycle repair limits are determined from the following equations:

VMURL- VSL 1.0 + NDE + Gr(CLCJAt)

VMLRL = VMURL (VURLVLRL)[ CLA]

where:

VURL = upper voltage repair limit VLRL = lower voltage repair limit VMURL = mid-cycle upper voltage limit based on time into cycle VMLRL = mid-cycle lower voltage repair limit based on VMLRL and time into cycle At = length of time since last scheduled inspection during which VURL and VLRL were implemented CL = cycle length (the time between two scheduled steam generator inspections)

VSL = structural limit voltage Gr = average growth per cycle NDE = 95-percent cumulative probability allowance for nondestructive examination uncertainty (i.e., a value of 20-percent has been approved by the NRC)

Implementation of these mid-cycle repair limits should follow the same approach as in TS 5.5.9e.1.xiii.1.,

5.5.9e.1.xiii.2., and 5.5.9e.1.xiii.3.

COMANCHE PEAK - UNITS 1AND 2 5.5-1 1 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 5.5.9 Steam Generator (SG) Tube Surveillance Program (continued) xiv. Tube Repair (for Unit 1 only) refers to the process that establishes tube serviceability. Acceptable tube repairs will be performed in accordance with the process described in Westinghouse WCAP-13698, Rev. 3 and Westinghouse Letter WPT-16094 dated March 20, 2000, WCAP-15090, Rev. 1, CEN-630-P, Rev. 2 dated June 1997, and WCAP-15918, Rev.

1, dated January, 2004.

2. The steam generator shall be determined OPERABLE after completing the corresponding actions (plug all tubes exceeding the plugging limit and all tubes containing through-wall cracks) required by Table 5.5-2 and Table 5.5-3.

COMANCHE PEAK - UNITS 1 AND 2 5.5-12 Amendment No.

Programs and Manuals 5.5 Table 5.5.9-1 (page 1 of 1)

Minimum Number Of Steam Generators To Be Inspected During Inservice Inspection Preservice Inspection Four No. of Steam Generators per Unit Four First Inservice Inspection Two Second & Subsequent Inservice Inspections One(a)

TABLE NOTATIONS (a) The two steam generators that were not inspected during the first inservice inspection shall be inspected during the second and third inspections, one in each inspection period. For the fourth and subsequent inspections, the inservice inspection may be limited to one steam generator on a rotating schedule encompassing 12% of the tubes if the results of the previous inspections of the four steam generators indicate that all steam generators are performing in a like manner. Note that under some circumstances, the operating conditions in one or more steam generators may be found to be more severe than those in other steam generators. Under such circumstances the sample sequence shall be modified to inspect the most severe conditions.

COMANCHE PEAK - UNITS 1 AND 2 5.5-1 3 Amendment No.

Programs and Manuals 5.5 Table 5.5.9-2 (page 1 of 1)

Steam Generator Tube Inspection 1ST SAMPLE 2ND SAMPLE 3 RD SAMPLE INSPECTION INSPECTION INSPECTION SAM 'LE RESULT ACTION RESULT ACTION RESULT ACTION SZ:E 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 and S.G. inspect additional C-2 Plug or repair* C-1 None per 2S tubes in this S.G. . defective tubes and inspect additional C-2 Plug or repair*

14S tubes in this S.G. defective tubes C-3 Perform action for C-3 result of first sample C-3 'Perform action for N.A. N.A.

C-3 result of first sample C-3 Inspect all tubes in All other l None I N.A. N.A.

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

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

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

_ _ _ __ _ _ _ _ _ _ _ _ _I _ _ _ _ _ _ _ _ _ _ _ =__

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

for Unit 1 only)

COMANCHE PEAK - UNITS 1 AND 2 5.5-1 4 Amendment No.

Programs and Manuals 5.5 Table 5.5.9-3 (page 1 of 1)

Steam Generator Repaired Tube Inspection for Unit 1 Only 1ST SAMPLE INSPECTION 2 ND SAMPLE INSPECTION SAMPLE SIZE R A RESULT ACTION REQUIRED RESULT ATON REQUIRED A minimum of C-1 None N.A. N.A.

20% of repaired tube, (1)

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

of the repaired tubes in this S.G.

C-2 Plug defective repaired tubes C-3 Perform action for C-3 result of first sample C-3 Inspect all repaired tubes All other None in this S.G., plug defective S.G.s are tubes and inspect 20% of C-1 the repaired tubes in each l _

other S.G. Same Perform action for C-2 S.G.s C-2 result of first sample but no additional S.G. are C-3 Additional Inspect all repaired tubes IiS.G is C-3 in each S.G. and plug defective tubes.

(1) Each repair method is considered a separate population for determination of initial inservica inspection and scope expansion.

COMANCHE PEAK - UNITS 1 AND 2 5.5-1 5 Amendment No.

Programs and Manuals 5.5 5.5 Programs and Manuals 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 5.5-1 6 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 A'STM 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 CFlMI Control Room Emergency pressurization unit 800 CFM Primary Plant Ventilation System - ESF 15,000 CFIVI filtration unit COMANCHE PEAK - UNITS 1 AND 2 5.5-17 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 speci ied 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 CFMA Control Room Emergency pressurization unit 9.5 in WG 800 CFMA 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 5.5-18 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 5.5-1 9 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 sedirrent content within limits.

b. Other properties for ASTM 2D fuel oil are within limits within 31 days following sampling and addition to storage tanks; and

c. Total particulate concentration of the fuel oil is < 10 mg/I when tested every 31 days in accordance with ASTM D-2276 1978, Method A.

d. 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 5.5-20 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 5.5-21 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 exception:

1. 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, Ihe 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:

i. Overall air lock leakage rate is

0.05 La when tested at 2 Pa.

ii. For each door, leakage rate is < 0.01 La when pressurized to

Ž 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.

COMANCHE PEAK - UNITS 1 AND 2 5.5-22 Amendment No.

-

Programs and Manuals 5.5 5.5 Programs and Manuals 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 CPSES. 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 11)

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.

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.

COMAI\'CHE PEAK - UNITS 1 AND 2 5.5-23 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 -

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 1')

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.

COMANCHE PEAK - UNITS 1 AND 2 5.6-1 Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.4 Deleted 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, RTP c

5. Heat Flux Hot Channel Factor, K(Z), W(Z), FQ , and the FQ (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-16 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 (LEFMV) as described in document number 20 listed below. When feedwater flow measurements from the LEFMqJ are not available, the originally approved initial power level of 102 percent of rated thermal power shall be used.

COMANCHE PEAK - UNITS 1AND 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 LEFMV 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. RXE-90-006-P-A, "Power Distribution Control Analysis and Overtemperature N-16 and Overpower N-16 Trip Setpoint Methodology," June 1994.

4. RXE-88-102-P-A, "TUE-1 Departure from Nucleate Boiling Correlation," July 1992.

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

December 1990.

6. RXE-89-002-A, "VIPRE-01 Core Thermal-Hydraulic Analysis Methods for Comanche Peak Steam Electric Station Licensing Applications,"

September 1993.

7. RXE-91-001-A, "Transient Analysis Methods for Comanche Peak Steam Electric Station Licensing Applications," October 1993.

8. RXE-91-002-A, "Reactivity Anomaly Events Methodology," October 1993.

9. ERX-2000-002-P, "Revised Large Break Loss of Coolant Accident Analysis Methodology," March 2000.

10. TXX-88306, "Steam Generator Tube Rupture Analysis", March 15, 1988.

11. RXE-91-005-A, "Methodology for Reactor Core Response to Steamline Break Events," February 1994.

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)

12. RXE-94-001-A, "Safety Analysis of Postulated Inadvertent Boron Dilution Event in Modes 3,4, and 5," February 1994.

13. RXE-95-001-P-A, "Small Break Loss of Coolant Accident Analysis Methodology," September 1996.

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

15. ERX-2001-005-P, "ZIRLOTM Cladding and Boron Coating Models for TXU Electric's Loss of Coolant Accident Analysis Methodologies,"

October 2001.

16. WCAP-10444-P-A, "Reference Core Report VANTAGE 5 Fuel Assembly," September 1985.

17. WCAP-1 5025-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.

18. WCAP-10360-P-A, "Westinghouse Fuel Assembly Reconstitution Evaluation Methodology," July, 1993.

c. The core operating limits shall be determined such that all applicable limits (e.g., fuel thermal mechanical limits, core thermal hydraulic limits, Emerge -cy 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.

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)

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:

Because plant specific analytic methods have not been approved for CPSES, the P/T Limits and the LTOP System Setpoints shall not be revised without prior NRC approval.

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 Not used 5.6.10 Steam Generator Tube Inspection Report

a. Within 15 days following the completion of each inservice inspection of steam generator tubes, the number of tubes plugged, repaired or designated as an F* tube in each steam generator shall be reported to the Commission; COMANCHE PEAK - UNITS 1 AND 2 5.6-5 Amendment No.

Reporting Requirements 5.6 5.6 Reporting Requirements 5.6.10 Steam Generator Tube Inspection Report (continued)

b. The complete results of the steam generator tube inservice inspection shall be submitted to the Commission in a report within 12 months following the completion of the inspection. This report shall include:

1. Number and extent of tubes and (for Unit 1 only) sleeves inspected,

2. Location and percent of wall-thickness penetration for each indication of an imperfection, and

3. Identification of tubes plugged or repaired.

c. Results of steam generator tube inspections which fall into Category C-3 shall be reported to the Commission in a report within 30 days and prior to resumption of plant operation. This report shall provide a description of investigations conducted to determine cause of the tube degradation and corrective measures taken to prevent recurrence.

d. For implementation of the voltage based repair criteria to tube support plate intersections, notify the staff prior to returning the steam generators to service should any of the following conditions arise:

1. If estimated leakage based on the projected end-of-cycle (or if not practical, using the actual measured end-of-cycle) voltage distribution exceeds the leakage limit (determined from the licensing basis dose calculation for the postulated main steam line break) for the next operating cycle.

2. Ifcircumferential crack-like indications are detected at the tube support plate intersections.

3. If indications are identified that extend beyond the confines of the tube support plate.

4. If indications are identified at the tube support plate elevations that are attributable to primary water stress corrosion cracking.

5. If the calculated conditional burst probability based on the projected end-of-cycle (or if not practical, using the actual measured end-of-cycle) voltage distribution exceeds 1 x 10 -2, notify the NRC and provide an assessment of the safety significance of the occurrence.

COMANCHE PEAK - UNITS 1 AND 2 5.6-6 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 bit 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 Exceedina 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, 3ut 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 ol 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 Centimelers 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.

CPSES-200600635, License Amendment Request (LAR) 06-004 Revision to Technical Specification 5.0, Administrative Controls.

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

7.0 REFERENCES

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

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CPSES-200600635, License Amendment Request (LAR) 06-004 Revision to Technical Specification 5.0, Administrative Controls.

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

7.0 REFERENCES

1.0 DESCRIPTION

2.0 PROPOSED CHANGE

3.0 BACKGROUND

4.0 TECHNICAL ANALYSIS

5.0 REGULATORY ANALYSIS

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