Text

Rev 12 to Technical Requirements Manual
	ML20056C789
Person / Time
Site:	Comanche Peak
Issue date:	07/15/1993
From:	; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	;
Shared Package
ML20056C784	List: ML20056C789; TXX-9323, Forwards Rev 12 to Technical Requirements Manual. Manual Revs Evaluated for Relative Significance & Reviewed Under 10CFR50.59 Process & Found Not to Include Any Unreviewed Safety Questions;
References
	PROC-930715, NUDOCS 9307230209
	Download: ML20056C789 (66)
	v • d • e

Attachment 2 to TXX-93233 July 15, 1993 Page 1 of 4 CPSES - TECHNICAL REQUIREMENTS MANUAL (TRM)

AMENDMENT / REVISION 12 DETAILED DESCRIPTION Prefix Page (as .arended) Group Description 0-1 4 Changes position title fr am Vice President, Nuclear Operations to Vice President of Nuclear Operations.

Update :

Position title change is consistent with the organizational changes made to the FSAR via LDCR#

SA-92-839 (TUS-93080).

Change Request Number : TR-93-7.1 Commitment Register Number :

Related SER : 13,1 SSER :26 13.1 SER/SSER Impact : No 0-1 4 Corrects typographical errors, including those to rev bars, and makes each page's fo* mat consistent within the TRM. Other pages impatted: 0-14, 0-15, 0-20, 0-21, 0-25, 1-3, 1-4, 1-7 ttru l-15, 1-18.thru-1-22, 2-2, 2-3, 2-14, 2-16, 2-27, 2-28, 3-4 thru 3-6, 3-8. 4-3, 4-4, 4-8, 4-9, 4-21, 4-22 & 4-31.

Editorial :

Editorial improvement of the TRM.

Change Request Number : TR-93-7.3-Commitment Register Number :

Related SER : SSER :

SER'SSER Impact : No 0-18 4 Revises requirements related to inservice inspection ano testing of ASME Code Class 1, 2 & 3 pumps and valves.

Update :

Makes the wording of the requirements consistent with that contained within the Combined Unit Technical Specification 4.0,5.

Change Request Number : TR-93-7.2 Commitment Register Number :

Related SER : 3.9.6 SSER :23 3.9.6 SER/SSER Impact : No 1-2 4 See Sheet No(s) :1-6, -15, -17, -22, 2-2, 3-2 & 4-2 Deletes asterisk & note stating that Unit 2 requirements are effective upon issuance of the Unit 2 operating license.

Update :

The Unit 2 operating licence has been issued: there is no further reason for this note to appear'in the.

TRM.

Change Request Number : TR-93-7.4 Commitment Register Number :

Related SER : SSER :

9307230209 930715 Th SER/SSER Impact : No PDR ADOCK 05000445 E;j P PDR g

E o Attachmont 2 to TXX-93233 July 15, 1993 Page 2 of 4 Prefix Page

'(al Angndad) Group Description 2-25 4 Adds Unit 1 indicator toLvalve tag' number VD-907' ,

and provides Unit 2 tag number equivalent to IVDr 907.

Correction :

Required for consistency with the Inservice Testing ~

Plan (IST) Table 16, and FSAR Tables 3.98-10.Sh. 25 and 6.2.4-2 Sh. 7. (Ref: ONE Form 93-864)

Change Request Number : TR-93-9.

Commitment Register Number :

Related SER : 6.2 SSER :

SER/SSER Impact : No 3-3 2 Revision to allow the first inservice visual inspection of Unit 2 snubbers to be performed after completing two (2) months of power operation. ;Also, adds note stating that the " Unit 2 visual inspections shall not begin until the Unit 2 Startup Testing Program has been completed".

Revision :

The basis for requiring the initial visual inspection of snubbers after four (4) months of power operation is to provide the' snubbers a sufficient opportunity to experience various modes of operation. Since the CPSES Unit 2 Startup Testing Program will have been completed after 2 months of power. operation, performing visual.

inspections at 2 months of power operation will not compromise the original basis for the initial inspection requirement. In addition, the note added clarifies the timing of the visual inspections.

Change Request Number : TR-93-10.

Commitment Register Number :

Related SER : 3.9 SSER :

SER/SSER Impact : No 4-8 4 See Sheet No(s) :4-9 thru 4-11 & 4-13 Replaces " Containment" with " Compartment" with regard to the " Device Location" for certain protective devices: adds "VAC" to indicate voltage:

and, makes other miscellaneous editorial changes /

corrections.

Editorial :

Changes are trivial, editori 1 enhancements or corrections.

Change Request Number TR-93-8.6 Commitment Register Nunmer :

Related SER : 8.4.1 SSER :22 8.4.1 SER/SSER Impact : No 4-12 4 See Sheet No(s) :4-25 Corrects Motor Operated Valve tag numbers by removing the "HV" prefix.

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-Attachment 2 to TXX-93233 July 15,1993 Page 3 of 4 Prefix Page (as amended) GrouD DescriDtion Correction :

Correction is warranted to make valve tag numbers" consistent with Licensing Basis and Design Basis Documents.

Change Request Number : TR-93-8.5 Commitment Register Number : . .

Related SER : 8.4.1 SSER :22 8.4.1 SER/SSER Impact : No l 4-16 3 See Sheet No(s) :4-29 Corrects backup breaker type located in the Miscellaneous Signal Control Cabinet on Tables 4.1.la and 4.1.Ib.

Correction :

Makes TRM consistent with field-installed breaker type. (Ref: Drawing D-599-220) ;

Change Request Number : TR-93-8.3 !

Commitment Register Number : u Related SER : 8.4.1 SSER :22 8.4.1 )

SER/SSER Impact : No. !

4-16 4 See Sheet No(s) :4-29 Panel board circuit designations are added for panel.

boards A and B in the Miscellaneous Signal Control Cabinet. ,

Addition : !

This information is added to Tables 4.1.la and j 4.1.lb to enhance the description of the backup -!

breakers located in the Miscellaneous Signal Control Cabinet. l Change Request Number : TR-93-8.4 l Commitment Register Number : H Related SER : 8.4.1 SSER :22 8.4.1 I SER/SSER Impact : No 4-18 3 See Sheet No(s) :4-19 Overcurrent protective relays are added to TRM-Table 4.1.lb for 6.9 kV AC switchgears 2A1, 2A2 '2A3 and 2A4.

Addition :

Similar relays are already listed.for Unit 1 in Table 4.1.la (pages 4-5 & 4-6). Though not previously included in the Unit 2 TRM table. they have been tested per Work Orders 5-92-503440-AA, 5-92-503442-AA, 5 503443-AA & 5-92-503444-AA.

(Ref: ONE Form 93-440)

Change Request Number : TR-93-8.1 Commitment Register Number :

Related SER : 8.4.1 SSER :22 8.4.1 SER/SSER Impact : No 4-21 4 See Sheet No(s) :4-23, 4-24 & 4-26 Replaces " Containment" with " Compartment" with v

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Attachment 2 to TXX-93233 '

. July 15, 1993 ,

Page 4 of.4 1

Prefix Page ]

(As amended) Group Description - 1

-regard to the " Device Location" for certain-protective devices: and, makes another. miscellaneous editorial change / correction.

Editorial :

Changes are trivial, editorial enhancements. or corrections.

Change Request Number. : TR-93-8.7 Commitment Register Number :

Related SER : 8.4.1 SSER :22, 8.4.1 .

SER/SSER Impact : No '

4-29 3 Adds asterisks and a note identifying common circuit ,

breakers on Table 4.1.lb. (These circuits provide backup protection to both Units'1 and 2.)

Clarification :

Clarifies function of breakers. These circuit breakers are also listed on Table 4.1.la, and their '

testing is controlled by the Unit 1 surveillance program.

Change Request Number- :-TR-93-8.2 Commitment Register Number :

Related SER : 8.4.1 'SSER :22 8.4.1 SER/SSER Impact : No.

1 A

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I COMANCHE PEAK STEAM ELECTRIC STATION i TECHNICAL REQUIREMENTS MANUAL INSTRUCTION SHEET The following instructional information and checklist is being furnished to help ,

insert Revision 12 into the Comanche Peak Steam Electric Station TRM. A l description of this revision is provided in TXX-93233, dated July 15, 1993. l 1

Discard the old sheets and insert the new sheets, as listed below. Keep all i instruction sheets in the front of the Effective Page Listing to. serve as a- 1 record of changes. j

~

Remove Insert Section 0 0-1 0-l' 0-14 & 0-15 0-14 & 0-15 0-18 0-18 0-20 & 0-21 0-20 & 0-21 0-25 0-25 Section 1 1-2 thru l-4 1-2 thru l-4 1-6 thru 1-15 1-6 thru l-15 i 1-17 thru 1-22 1-17 thru l-22 Section 2 2-2 & 2-3 2-2 & 2-3 2-14 2-14 2-16 2-16 2-25 2-25 2-27 & 2-28 2-27 & 2-28 Section 3 3-2 thru 3-6 3-2 thru 3-6 3-8 3-8 Section 4 4-2 thru 4-4 4-2 thru 4-4 4-8 thru 4-13 4-8 thru 4-13 4-16 4-16 4-18 & 4-19 4-18 & 4-19 4-21 thru 4-26 4-21 thru 4-26 4-29 4-29 4-31 4-31 List of Effective Paaes EPL-1 thru EPL-4 EPL-1 thru EPL-4

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TECHNICAL REQUIREMENTS MANUAL ~ ;

(TRM)

Description of the Administrative Control Process INTRODUCTION CPSES has relocated certain information from the Technical 2 l Specifications to a separate controlled document based on the NUMARC. j Technical Specification Improvement Program, the Westinghouse Owners 1 Group MERITS Program, and the Commission's Interim Policy Statement J for improvement of Technical Specifications'for nuclear power ~ plants.

(52 FR 3788 of February 6, 1987). This information'is now contained in a separate document to be called the CPSES Technical Requirements 3 Manual (TRM). The following is a description of the administrative ]

l program for control, distribution, updating, and amending the .l information contained in the TRM.

DOCUMENT CONTROL The TRM is considered a licensing basis document and as such, overall 2 i control of the document is addressed by the site-wide procedures for licensing document control. 4 DOCUMENT DISTRIBUTION The TRM is considered a controlled document and distribution is controlled by the Nuclear Licensing Department. Licensing specifies 2 (by copy number) the proper distribution for the TRM. Distribution includes those personnel / locations which receive the CPSES Technical Specifications as well as any other groups which need access to the :

information contained in the TRM.

CHANGES / DELETIONS TO THE TRM Changes to the TRM are controlled by the procedure on licensing 2 ;

document change control. This procedure addresses the administrative :

requirements necessary to change / amend CPSES licensing documents l (e.g., Fire Protection Report, Offsite Dose Calculation Manual).

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For changes to the TRM, the procedure requires initiation of a Licensing Document Change Request (LDCR). The LDCR is the mechanism whereby changes are tracked to ensure that appropriate reviews, approvals, and signatures are obtained. TRM changes are evaluated ,

per 10CFR50.59. TRM changes require a review by SORC and the approval 12 l of the Vice President of Nuclear Operations.

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l COMANCHE PEAK - UNITS 1 AND 2 0-1 Revision 12 l July 15, 1993

TECHNICAL' REQUIREMENT 0.2 APPLICABILITV. a This Technical Requirement contains Section 3.0/4.0, APPLICABILITY, of the Technical-Specifications, which are also applied to the Technical Requirements Manual.except where otherwise specified. For.the purpose -

of this Technical Requirement, the Technical Requirements Manual terms specified below shall be considered. synonymous with the listed i Technical Specification terms:

Technical Recuirements Manual Technical Specifications' OPERABILITY CRITERIA LIMITING' CONDITION FOR-OPERATION COMPENSATORY MEASURE ACTION' TESTS / INSPECTIONS SURVEILLANCE REQUIREMENTS ,

TECHNICAL REQUIREMENT SPECIFICATION L

NOTE: Although the CPSES Technical Specification is repeated here, 5 in part, care must be taken not to overlook Technical Specification requirements.

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COMANCHE PEAK - UNITS 1 AND 2 0-14 July-15,.1993 i

3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS 3/4.0 APPLICABILITY.

LIMITING CONDITION FOR OPERATION 3.0.1 Compliance with the Limiting Conditions for 0peration contained in the succeeding specifications is required during the OPERATIONAL ;

MODES or'other conditions specified therein; except that upon failure-

~

to meet the Limiting Conditions for Operation, the associated ACTION requirements shall be' met.

3.0.2 Noncompliance with a specification shall exist'when the requirements of the Limiting Condition for Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting Condition for Operation is restored prior to .

~.

expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 .When a Limiting Condition for Operation is not met, except as.

provided in the associated ACTION requirements, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months action.

shall be initiated to place the unit in a MODE in which the specification does not apply by. placing it, as applicable, in: ;;

a. At least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ,

b. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months , and

c. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Where corrective measures are completed _that permit operation.under.

the ACTION requirements, the action may be taken in accordance.with-the specified time limits as measured from the. time'of failure to meet the Limiting Condition for Operation. ~ Exceptions to these requirements are stated in the individual specifications. -

This specification is not applicable.in MODE 5 or 6.

l 3.0.4 Entry into an OPERATIONAL MODE or.Other specified condition .l shall not be made when the conditions for the Limiting Conditions.for i Operation are not met and the associated ACTION requires a shutdown if they are not met-within a specified time interval. Entry into an OPERA'IONAL MODE or specified condition may be made in accordance with i ACTION requirements when conformance to them permits continued ,

operation of the facility for an unlimited period of time. This !

provision shall not prevent passage through or to OPERATIONAL MODES as required to comply with ACTION requirements. Exceptions to these requirements are stated in the individual specifications.

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COMANCHE PEAK --UNITS 1 AND 2 0-15 July 15, 1993 L.

1 APPLICABILITY i SURVEILLANCE RE0VIREMENTS (continued)

a. Inservice inspection of ASME Code Class 1, 2, and 3 12 components shall be performed in accordance with Section XI of the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10CFR50.55a;

b. Inservice testing of ASME Code Class 1, 2, and 3 pumps and- 12 valves shall be performed in accordance with Section XI of ;

the ASME Boiler and Pressure Vessel Code and applicable Addenda as required by 10CFR50.55a;

c. Surveillance intervals specified in Section XI of the ASME 12 Boiler and Pressure Vessel Code and applicable Addenda for l the inservice inspection and testing activities required by the ASME Boiler and Pressure Vessel Code and applicable Addenda shall be applicable as follows in these Technical Specifications:

ASME Boiler and Pressure Vessel Required frequencies for Code and applicable Addenda performing inservice terminology for inservice inspection and testing insoection and testina activities activities Week ly 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

d. The provisions of Specification 4.0.2 are applicable to the 12 above required frequencies for performing inservice inspection and testing activities;

e. Performance of the above inservice inspection and testing 12 activities shall be in addition to other specified Surveillance Requirements; and

f. Nothing in the ASME Boiler and Pressure Vessel Code shall be 12 construed to supersede the requirements of any Technical specification.

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l COMANCHE PEAK - UNITS 1 AND 2 0-18 Revision 12 July 15, 1993

APPLICABILITY 8 i BASES 8 8

ACTION requirements are applicable when this limit expires if the- . '8 surveillance has not been completed. _When a shutdown is required to comply with ACTION requirements, the plant may have entered a MODE in which a new specification becomes applicable. In this case, the time.

limits of the ACTION requirements would apply from the point in time that the new specification becomes applicable if the requirements of the Limiting Condition for Operation are not met.

Specification 3.0.2 establishes that noncompliance with a -8 specification exists when the requirements of tha Limiting Condition for Operation are not met and the associated ACTION requirements have not been implemented within the specified time interval. 'The purpose i of this specification is to clarify that (1) implementation of.the ACTION requirements within the specified time interval constitutes compliance with a specification and (2) completion of the remedial measures of the ACTION requirements is not required when compliance with a Limiting Condition of Operation is restored within the time interval specified in the associated ACTION requirements.

Specification 3.0.3 establishes the shutdown ACTION requirements that 8 must be implemented when a Limiting Condition for Operation is not met and the condition is not specifically addressed by the associated ACTION requirements. The purpose of this specification is to delineate the time _ limits for placing'the unit in a safe shutdown MODE when plant operation cannot be maintained within the limits for safe operation defined by the Limiting Conditions for Operation and its ,

ACTION requirements. It is not intended to be_used.as an operational convenience which permits (routine) voluntary removal of redundant systems or components from service in lieu of other alternatives that would not result in redundant systems or components being inoperable.

One hour is allowed to prepare for an orderly shutdown before initiating a change in plant operation. This time permits the operator to coordinate the reduction in electrical generation with the load dispatcher to ensure tne stability and availability of the electrical grid. The time limits specified to reach lower MODES of operation permit the shutdown to proceed in a controlled and orderly ,

manner that is well within the specified maximum cooldown rate and >

within the cooldown capabilities of the facility assuming only the minimum required equipment is OPERABLE. This reduces thermal <

stresses on components of the primary coolant system and the potential for a plant upset that could challenge safety systems under conditions for which this specification applies.

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I COMANCHE PEAK - UNITS 1 AND 2 0-20 July 15, 1993 i

APPLICABILITY 8 BASES- 8 8

If remedial measures permitting limited continued operation of the 8 facility under the provisions of the ACTION' requirements are completed, the shutdown may be terminated. The time limits of'the ACTION requirements are applicable from the point in time there was a i failure to meet a Limiting Condition for Operation. Therefore, the shutdown may be terminated if the~ ACTION requirements have been met or the time limits of the ACTION requirements have not expired, thus providing an allowance for the completion of the required actions. j The time limits of Specification 3.0.3 allow 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months for the plant to 8 be in the COLD SHUTDOWN MODE when a shutdown is required during the i POWER MODE of operation. If the plant is in a-lower MODE of operation when a shutdown.is required, the time limit for reaching the ,

next lower MODE of operation applies. However, if a lower MODE of operation is reached in less time than allowed, the total allowable time to reach COLD SHUTDOWN, or other applicable MODE, is not reduced.

For example, if HOT STANDBY is reached in 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months , the time allowed to reach HOT SHUTDOWN is the next 11 hours1.273148e-4 days 0.00306 hours 1.818783e-5 weeks 4.1855e-6 months because the total time to reach HOT SHUTDOWN is not reduced from the allowable limit of 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months .

Therefore, if remedial measures are completed that would permit a 8 return to POWER operation, a penalty is not incurred by having to reach a lower MODE of operation in less than the total time allowed.

The same principle applies with regard to the allowable outage time 8 limits of the ACTION requirements, if compliance with the ACTION requirements for one specification results in entry into a MODE or condition of operation for another specification in which the requirements of the Limiting Condition for Operation are not met. If the new specification becomes. applicable in less time than'specified, the difference may be added to the allowable outage time limits of the second specification. However, the allowable outage time limits of l ACTION requirements for a higher MODE of operation may not be used to extend the allowable outage time that is applicable when a Limiting Condition for Operation is not met in a lower MODE of operation.

The shutdown requirements of Specification 3.0.3 do not apply in MODES 8 5 and 6, because the ACTION requirements of individual specifications derine the remedial measures to be taken.

Specification 3.0.4 establishes limitations on MODE changes when a 8 j Limiting Condition for Operation is not met. It precludes placing ;

the facility in a higher MODE of operation when the requirements for a l

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COMANCHE PEAK - UNITS 1 AND 2 0-21 July 15, 1993

APPLICABILITY- 8 i

BASES 8 a surveillance is not completed within the 24-hour allowance, the time 8 limits of the ACTION requirements are applicable at that time. When a surveillance is performed within the 24-hour allowance, and the Surveillance Requirements are not met, the time limits of the ACTION requirements are applicable at the time that the surveillance is terminated.

t Surveillance Requirements do not have to be performed on inoperable 8 equipment because the ACTION requirements define the remedial measures 1 that apply. However, the Surveillance Requirements have to be met to !

demonstrate that inoperable equipment has been restored to OPERABLE :

status.

Specification 4.0.4 establishes the requirement that all applicable 8 surveillances must be met before entry into an OPERATIONAL-MODE or other condition of operation specified in the' Applicability statement. The purpose of this specification is to ensure that ;

system and component OPERABILITY requirements or parameter limits are i met before entry into a MODE or condition for which these systems and components ensure safe operation of the facility. This provision applies to changes in OPERATIONAL MODES or other specified conditions ;

associated with plant shutdown as well as startup.

Under the' provisions of this specification, the applicable 8 ,

Surveillance Requirements must be performed within the specified !

surveillance interval to ensure that the Limiting Conditions for Operation are met during initial plant startup or following a plant outage.

When a shutdown is required to comply with ACTION requirements, the 8 provisions of Specification 4.0.4 do not apply because this would delay placing the facility in a lower MODE of operation.

Specification 4.0.5 establishes the requirement that inservice 8 -

inspection of ASME Code Class 1, 2, and 3 components and inservice testing of ASME Code Class 1, 2, and 3 pumps and valves shall be ;

performed in accordance with a periodically updated version of Section '

XI of the ASME Boiler and Pressure Vessel Code and Addenda as required by 10CFR50.55a. These requirements apply except when relief has been ,

provided in writing by the Commission.

This specification includes a clarification of the frequencies for 8 performing the inservice inspection and testing activities required by sSection XI of the ASME Boiler and Pressure Vessel Code and applicable -'

Addenda. This clarification'is provided to ensure consistency in surveillance intervals throughout the Technical Specifications ~and to .

remove any ambiguities relative to the frequencies for performing the required inservice inspection and testing activities. )

COMANCHE PEAK - UNITS 1 AND 2 0-25 July 15, 1993

. . . ~ .. . -

3/4.3 INSTRUMENTATION j 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION' !

1 3.3.1 As a minimum, the Reactor Trip System instrumentation channels and~ interlocks of Table 3.3-1 shall be OPERABLE. ,

APPLICABILITY: As shown in Table 3.3-1, 12 ACTION:

i As shown in Table 3.3-1.

SURVEILLANCE REQUIREMENTS 4.3.1.1 Each Reactor Trip System Instrumentation channel and ;

interlock and the automatic trip logic shall be demonstrated OPERABLE ;

by the performance of the Reactor Trip System-Instrumentation-Surveillance Requirements specified in Table 4.3-1 t

4.3.1.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip function shall be demonstrated to be within its limit at least'once per 18 months. Each test shall include at least one' train such that '

both trains are tested at least once per 36 months and one channel per function'such that all channels are tested at'least once every-N times 18 months where N is the total number of redundant channels in-a specific Reactor trip function as shown in the " Total No. of-Channels" column of Table 3.3-1. i 12 .

t COMANCHE PEAK - UNITS 1 AND 2 1-2 Revision 12 July 15, 1993

q 1 TECHNICAL RE0VIREMENT 1.1 Table 1.1.1 REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE-TIME'

{

1. Manual Reactor Trip -

3 .N.A.

2. Power Range, Neutron. Flux 5 0.5 second*

3. Power. Range, Neutron' Flux -

High Positive Rate N . A.

4. Power Range, Neutron Flux High Negative Rate 5 0.5 second*'

5. Intermediate Range, Neutron Flux N.A. ,

6. Source Range, Neutron Flux 5 0.5-second*

7. Overtemperature N-16 5 7 seconds *#

8. Overpower N-16 5 7 seconds *#

9. Pressurizer Pressure-Low 5 2. seconds

10. Pressurizer Pressure-High 5 2 seconds

11. Pressurizer Water Level-High N.A. .;

~

Neutron / gamma detectors are exempt from response time _ testing.

Response time of the neutron / gamma flux signal portion of the channel shall be measured from detector output or input of first electronic component in a channel.

Response time includes the thermal well response time.

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l COMANCHE PEAK - UNITS l'AND 2 1-3 July 15, 1993 1

-~c EW

.. . ., . . __ - - .. - .~ _-

TECHNICAL REOUIREMENT 1.1 (continued) ,

Table 1.1.1 (continued)

BEACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE TIME

12. Reactor Coolant Flow-Low

a. Single Loop (Above P-8) 5 1 second

b. Two Loops (Above P-7 and below P-8) 1 1 second

13. Steam Generator Water Level--Low-Low 5 2 seconds

14. Undervoltage - Reactor Coolant Pumps 5 1.5 seconds

15. Underfrequency - Reactor Coolant Pumps 5 0.6 second 7

16. Turbine Trip

a. Low Fluid Oil Pressure N.A.

b. Turbine Stop Valve Closure N.A. ,

17. Safety injection Input from ESFAS N.A.

18. Reactor Trip System Interlocks N.A.

19. Reactor Trip Breakers N.A.

20. Automatic Trip and Interlock Logic N.A. [

BASES ,

1.1 REACTOR TRIP SYSTEM RESPONSE TIMES :.

The bases for the Reactor Trip System are contained in the CPSES ,

Technical Specifications. The measurement of response time at the ;

specified frequencies provides assurance that the Reactor trip actuation associated with each channel is completed within the time :

limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response times indicated as not-applicable. Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurements provided that such tests demonstrate the total channel response time as >

defined. Sensor response time verification may be denonstrated by either: (1) in place, onsite, or offsite test measurements, or (2)-

utilizing replacement sensors with certified response time.

_ COMANCHE. PEAK - UNITS 1 AND 2 1-4 July 15, 1993

-INSTRUMENTATIQH 3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 The Engineered Safety Features Actuation System (ESFAS) instrumentation channels and interlocks shown in Table 3.3-2 shall be OPERABLE with their Trip Setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-3.

APPLICABILITY: As shown in Table 3.3-2. 12 ACTION:

a. With an ESFAS Instrumentation or Interlock Trip Setpoint tripL less conservative than the value shown in the Trip Setpoint' column but more conservative than the value shown in the Allowable Value column of Table 3.3-3, adjust the Setpoint-consistent with the Trip Setpoint value.

b. With an ESFAS Instrumentation or Interlock Trip Setpoint less conservative than the value shown in the Allowable Value column of Table 3.3-3, either:

1. Adjust the Setpoint consistent-with the Trip Setpoint value of Table 3.3-3 and determine within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that Equation 2.2-1 was satisfied for the affected channel, or

2. Declare the channel inoperable and apply the applicable-ACTION statement requirements of Table 3.3-2 until the-channel-is_ restored to OPERABLE status with its'Setpoint adjusted consistent with the Trip Setpoint.value.

Equation 2.2-1 Z + R + S 5 TA Where:

Z = The value from Column Z of Table 3.3-3 for the affected channel, R = The "as measured" value (in percent-span) of rack error for the affected channel, 12 i

.4 COMANCHE PEAK - UNITS 1 AND 2 1-6 Revision 12 July 15, 1993

INSTRUMENTATION I

LIMITING CONDITION FOR OPERATION (continued) _

ACTION (continuedl S= Either the "as measured" value (in percent span) of.the sensor error, or the value from Column S (Sensor Error) of Table 3.3-3 for the affected channel, and TA = The value from Column TA (Total Allowance) of1 Table'3.3-3 for the affected channel.

c. With ESFAS instrumentation channel or' interlock inoperable, take the ACTION shown in Table 3.3-2.

SURVEILLANCE RE0VIREMENTS 4.3.2.1 Each ESFAS instrumentation channel and interlock and the automatic actuation logic and relays shall be demonstrated OPERABLE by performance of the ESFAS Instrumentation Surveillance Requirements specified in Table 4.3-2.

4.3.2.2 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS >

function.shall be demonstrated to be within the limit at least once per 18 months. Each test shall include at least one train-such that both trains are tested at least once per:36 months and one channel per function such that'all channels are tested ~at least once per;N times 18 months where N is the total number of redundant channels in a +

specific ESFAS function as shown in the " Total No. of Channels" column of Table 3.3-2. '

c 6

COMANCHE PEAK - UNITS 1 AND.2 1-7 July 15, 1993 i l

i

, TECHNICAL REOUIREMENT 1.2 TABLE-1.2.1' ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL'AND FUNCTION RESPONSE TIME IN SECONDS

1. -Manual Initiation

a. Safety Injection (ECCS) N.A.

b. Containment Spray (Phase "B" Isolation and Containment Vent Isolation) N.A.

c. Phase "A" Isolation (Containment Vent Isolation) .N.A.

d. Steam Line Isolation N.A.

e. Feedwater Isolation (SI) 'N.A.

f. Auxiliary Feedwater (SI) N.A.

g. Station Service Water (SI) N.A.

h. Component Cooling Water (SI) N.A.

i. Control Room Emergency Recirculation (SI) . N . A. -

j. Reactor Trip N.A.

k. Emergency Diesel Generator Operation 'N.A.

1. Essential Ventilation Systems (SI) N.A. 1

m. Turbine Trip N.A.

I I

i COMANCHE PEAK - UNITS 1 AND 2 1-8 July 15, 1993

l<

TECHNICAL REOUIREMENT 1.2 (continued)-

1

-TABLE 1.2.1 (continued) i ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE ~ TIME IN SECONDS !

2. Containment Pressure--High-1

a. ' Safety Injection (ECCS) 527(1,5a)/27(4,5b) 9'

b. Reactor Trip 52

c. Feedwater Isolation 16.5

d. Phase "A" Isolation 117(2)/27(1)

e. Containment Ventilation Isolation N.A.

f. Auxiliary Feedwater '50 6 9

g. Station Service Water N.A.

h. Component' Cooling Water N.A.

i. Essential Ventilation Systems N.A.

j. Emergency Diesel Generator 5 12 Operation 1

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump $32(1,7) 11 COMANCHE PEAK - UNITS 1 AND 2 1-9 July 15, 1993'

TECHNICAL REOUIREMENT 1.2 (continued)-

TABLE 1.2.1 (continue'di' ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION -RESPONSE TIME IN SECONDS

3. Pressurizer Fressure--Low

a. Safety Injection (ECCS)_ 527(1,5a)/ 27(4,5b) l9

b. Reactor Trip 52 ,

c. Feedwater Isolation 57

d. Phase "A" Isolation 517(2)/27(1).

e. Containment Ventilation Isolation s 5(6) 9

f. Auxiliary Feedwater 5 60 9 9 Station Service Water N.A.

h. Component Cooling Water N.A.

i. Essential _ Ventilation Systems N.A. 3

j. Emergency Diesel Generator Operation 1 12

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump N.A. 9 i

J

'i COMANCHE PEAK - UNITS 1_AND 2 1-10 July 15, 1993

1 i

_ TECHNICAL RE0VIREMENT 1.2 (cont'inued)

TABLE 1.2.1 (continued) -

ENGINEERED SAFETY FEATURES RESPONSE TIMES.

INITIATION SIGNAL AND FUNCTION RESPONSE TIME ~IN SECONOS

4. Steam Line Pressure--Low :

a. Safety Injection-(ECCS) -537(3,5b)/27(4,5b)

b. Reactor Trip 52

c. Feedwater Isolation 5 6.5 91

d. Phase "A" Isolation 517(2)/27(1) ,

e. Containment Ventilation Isolation 'N.A.

f. Auxiliary Feedwater 5 60 9_

g. Station Service Water N.A. >

h. Component Cooling Water N.A.

i.- Essential Ventilation Systems N.A. '

j. Emergency Diesel Generator Operation 5 12 ,

k. Turbine Trip _ N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump N.A. 9

n. Steam Line Isolation 5 6.5 9

~l COMANCHE _ PEAK . UNITS 1 AND 2 1-11 July 15,'1993

y q ,

TECHNICAL RE0VIREMENT 1.2 (continued) -;

.1

' TABLE-1.2.1 (continued)

.- l ENGINEERED SAFETY FEATURES RESPONSE TIMES

[ INITIATION SIGNAL-AND FUNCTION RESPONSE TIME IN SECONDS

5. Containment Pressure--High-3 -

a. Containment Spray Pump N.A. -

b. Phase "B" Isolation N.A.

c. Containment Spray Pump Discharge Valve 5 119 9-

6. Containment Pressure--High-2 Steam Line Isolation -5 6.5

7. Steam Line Pressure - Negative Rate-High Steam Line Isolation 57 9

8. Steam Generator Water Level - High-High.

a. Turbine Trip N.A.

b. Feedwater Isolation 5 11

9. Steam Generator Water Level - Low-Low' ;

a. Motor-Driven Auxiliary Feedwater Pumps 5 60

b. Turbine-Driven Auxiliary Feedwater Pump 5 85 4

10. Loss-of-Offsite Power Auxiliary Feedwater N.A. 9

11. Trip of All Main Feedwater Pumps All Auxiliary Feedwater Pumps N.A.

COMANCHE PEAK - UNITS 1-AND 2 1-12 July 15,-1993- -

'l

.I

~

f

TECHNICAL REOUIREMENT 1.2 (continuedP e

ETABLE 1.2.1 (continued)

ENGINEERED SAFETY FEATURES RESPONSE TIMES-

' INITIATION' SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS .

12. RWST Level - Low-Low Coincident with Safety Injection Automatic. Initiation of ECCS. 5-30 Switchover to Containment Sump

13. Loss of Power (6.9 KV and 480V Safeguards System Undervoltage) ,

a. 6.9 KV Preferred Offsite Source N.A. '9 undervoltage

.2

b. 6.9 KV Alternate Offsite Source N.A. 9 undervoltage

c. 6.9 KV Bus Undervoltage 52(8) -9

d. 6.9 KV and 480V Degraded Voltage with Safety Injection 5 10(8,9). 9, without Safety Injection s 63(8,9) .g .

e. 480 V Low Grid Undervoltage s 63(8,9) 9 9

f

')

I COMANCHE PEAK - UNITS 1 AND 2 1-13 -July 15, 1993'

L{

i i

l-TECHNICAL RE0VIREMENT 1.2'(continued)'

TABLE 1.2.1 (continued)

TABLE NOTATIONS .j r

(1) Diesel generator starting and sequence loading delays -

included.

(2) Diesel generator starting delay nqt included. 0ffsite power available.

(3) Diesel generator starting delay included. 0nly centrifugal charging pumps are included. :

(4) Diesel generator starting delay nqt included. Only 11 1*

centrifugal charging pumps are. included. ,

(Sa) Sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close) is not included.

(5b) Sequential transfer of charging pump suction from the VC to the RWST (RWST valves open, then VCT valves close) is-included.

(6) Includes containment pressure relief line isolation only.

(7) This is a bounding response time for all scenarios. 11.-

(8) Response time measured to output of undervoltage channel only.

(9) Two additional seconds allowable for alternate offsite source

breaker trip functions.

BASES l

1.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM RESPONSE TIMES The bases for the Engineered Safety Features Actuation System are contained in the CPSES Technical Specifications. The measurement of response time at the specified frequencies provides assurance that-the '

Engineered Safety Features actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response-times indicated as not applicable. Response time may be demonstrated by any series of sequential, overlapping, or total channel test measurements provided that such tests demonstrate the total channel response time as defined. Sensor response time verification may be demonstrated by either: (1) in place, onsite, or offsite test j measurements, or (2) utilizing replacement sensors with certified !

response' time. I i

l COMANCHE PEAK - UNITS 1 AND 2 1-14 July 15, 1993

-TECHNICAL' REQUIREMENT 1.1 MOVABLE INCORE DETECTORS-OPERABILITY CRITERIA

.i 1.3 The Movable Incore Detection System shall be OPERABLEfwith:

a. At least 75% of the detector thimbles,_ f

b. A minimum of two detector thimbles per core quadrant, and ,

c. Sufficient movable detectors, drive, and readout equipment.to -

map these thimbles.

' APPLICABILITY: When the Movable Incore Detection System is used for: -12 -

a. Recalibration of the Excore Neutron Flux Detection System, or i

b. Monitoring the QUADRANT POWER TILT RATIO, or ,

c. MeasurementofFjH.F(Z)andFxy-Q COMPENSATORY MEASURES:

With the Movable Incore Detection System Inoperable, do not use the system for the above applicable monitoring or. calibration functions.

The provisions of Technical Requirement 0.2 Operability Criteria 3.0.3 3 i and 3.0.4 are not applicable. ,

TESTS / INSPECTIONS TRI.3 The Movable Incore Detection system shall be demonstrated OPERABLE within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to use by irradiating _each'

required detector and determining the acceptability of its voltege curve when the system is required for: ;

a. Recalibration of the Excore Neutron Flux Detection System, or

b. Monitoring the QUADRANT POWER TILT RATIO, er !

c. MeasurementofFjg,Fg(Z)andFxy. l BASES f

1.3 MOVABLE INCORE DETECTORS ;

i The OPERABILITY of the movable incore detectors with the specified '

+ minimum complement of equipment ensures.that the measurements obtained from use of this system accurately represent the spatial l neutron flux distribution of the core. The OPERABILITY of this system j is demonstrated by irradiating each detertor used and determining the 9 acceptability of its voltage curve.

12 I

l COMANCHE PEAK - UNITS 1 AND 2 1-15 Revision 12 j July 15, 1993 1 i

TECHNICAL REOUIREMENT 1.4 l

SEISMIC INSTRUMENTATION OPERABILITY CRITERIA

^

1.4 The seismic.' monitoring instrumentation shown in Table 1.4.1 shall be OPERABLE. ;

APPLICABILITY: 'At all times. 12 QMPENSATORY MEASURES (UNITS 1 AM.2)1 8

a. With one or more of the above required seismic monitoring instruments inoperable for more than 30 days, prepare and-submit a Special Report to the Commission pursuant to CPSES Technical Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the instrument (s) to OPERABLE status.

b. The provisions of Technical Requirement 0.2 Operability 3 Criteria 3.0.3 and 3.0.4 are not applicable.

TESTS / INSPECTIONS TR1.4.1 Each of the above required seismic monitoring instruments shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CALIBRATION, and ANALOG CHANNEL "

OPERATIONAL TEST at the frequencies shown in Table 1.4.2.

TRI.4.2 Each of the above required seismic monitoring instruments which is accessible during power operations and which is actuated during a seismic event greater than or equal to 0.01g shall be restored to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 15 days following the seismic event. Data shall be retrieved from actuated instruments and analyzed to determine the magnitude of the vibratory ground motion. A Special Report shall be prepared and submitted to the Commission.

pursuant to CPSES Technical Specification 6.9.2 within 14 days describi.g the magnitude, frequency spectrum, and resultant effect upon facility features important to safety.

TR1.4.3 Each of the above seismic monitoring instruments which-is actuated during a seismic evert greater than or equal to 0.01g but is not accessible during power operation shall be restored to OPERABLE status and a CHANNEL CALIBRATION performed the next time the plant enters. MODE S'or_below.

A supplemental report shall then be prepared and submitted.

to the Commission within 14 days pursuant _to CPSES Technical Specification 6.9.2 describing the additional-data from these instruments.

12 COMANCHE PEAK - UNITS 1 AND 2 1-17 Revision 12 i July 15, 1993 l

r- -

l TECHNICAL RE0VIREMENT 1.4 (continued) t TABLE 1.4.1 SEISMIC MONITORING INSTRUMENTATION

8' MINIMUM INSTRUMENTS ,

INSTRUMENTS AND SENSOR LOCATIONS OPERABLE

1. Triaxial Time-History Accelerographs i

a. Accelerometer-Fuel Building 1

b. Accelerometer-Unit 1 Containment 1 8

c. Accelerometer-ElectricalManhole(Yard) 1 8

d. Seismic Trigger-Fuel Building 1** 8

e. Recorder Unit, SMA-3 (Unit 1 Control Room) 1 8

f. Playback Unit, SMP-1 (Unit 1 Control Room) 1 8-

2. Triaxial Peak Accelerographs

a. Pressurizer Lifting Trunion (Unit 1 Containment) 1 8

b. Reactor Coolant Piping (Unit 1 Containment) 1 .8 i

c. CCW Heat Exchanger (Auxiliary Building) 1 8

3. Triaxial Seismic Switch Fuel Building 1**--

8

4. Triaxial Response-Spectrum Recorders

a. Fuel Building 1

b. Unit 1 Reactor Bldg. Internal Structure 1 8-

c. Unit 1 Safeguards Building 1- 8 -

5. Response Spectrum Annunciator Unit 1 Control Room 1** 8

Unit 1 and-Unit 2 control room alarms are connected to shared seismic 8 instruments which are located in Unit 1 and common structures.

- With control room indication. ,

E COMANCHE PEAK - UNITS,1-AND 2 1-18 July 15, 1993

l TECHNICAL REOUIREMENT 1.4 (continued)

TABLE 1.4.2 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS *- 8 ANALOG ** 8 CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST 1

1. Triaxial Time-History

)

Accelerographs

a. Accelerometer-Fuel M R SA Building =l t

b. Accelerometer-Unit 1 M R SA 8 Containment

c. Accelerometer-Elec- M R SA trical Manhole (Yard) 8

d. Seismic Trigger-Fuel M R SA Building *** 8

e. Recorder Unit, SMA-3 M R SA (Unit 1 Control Room) 8

f. Playback Unit, SMP-1 M R SA (Unit 1 Control Room) 8'

2. Triaxial Peak Accelerographs

a. Pressurizer Lifting N.A. R N.A. 8- i Trunion - Unit 1 Containment 8

b. Reactor Coolant Piping - N.A. R N.A.

Unit 1 Containment 8

c. CCW Heat Exchanger - N.A. R N.A.

Auxiliary Building 8

3. Triaxial Seismic Switch Fuel Building *** M R SA 8

Unit 1 and Unit 2 control room alarms are connected to shared seismic 8 instruments which are located in Unit 1 and common structures.

- Setpoint verification is not applicable. 8

- - With control room indication. 8 COMANCHE PEAK - UNITS 1 AND 2 1-19 July 15, 1993 u-__=--_____---___ - - _ _ _ _ - - - _ _ - - _ _ _ _ _ - - . _ _ _ _ - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ _ _ _ _ _ _

TECHNICAL RE0VIREMENT 1.4 (continued) ,

TABLE 1.4.2 (continued)

SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS* 8 ,

ANALOG ** 8 CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK CALIBRATION TEST t

4. Triaxial Response-Spectrum Recorders

a. Fuel Building N.A. R N.A.

b. Unit 1 Reactor Bldg. N.A. R N.A. 8 Internal Structure

c. Unit 1 Safeguards Building N.A. R N.A. 8

5. Response Spectrum M R SA Annunciator *** 8 (Unit 1 Control Room) 8

+

D i

?

Unit 1 and Unit 2 control room alarms are connected to shared 8 .

seismic instruments which are located in Unit 1 and common- !

structures. *

- Setpoint verification is not applicable.

- - With control room indication. ;

1 COMANCHE PEAK - UNITS 1 AND 2 1-20 July 15, 1993- l i

TECHNICAL REQUIREMENT 1.4 (continugdl r

SEISMIC INSTRUMENTATION BASES 1.4 SEISMIC INSTRUMENTATION The OPERABILITY of the seismic instrumentation ensures that sufficient -

capability is available to promptly determine the magnitude of a seismic event and evaluate the response of those features important to safety. This capability is required to permit comparison of the measured' response to that used in the design basis for the facility to ;

determine if plant shutdown is required pursuant to Appendix A of 10CFR100. The instrumentation is consistent with the recommendations of Regulatory Guide 1.12. " Instrumentation for Earthquakes," April 1974.

h t

l COMANCHE PEAK - UNITS 1 AND 2 1-21 July 15, 1993

\

'IECHNICAL RE0VIREMENT 1.5 LOOSE-PART DETECTION SYSTEM QPERABILITY CRITERIA i

1.5 The Loose-Part Detection System shall be OPERABLE. !

APPLICABILITY: MODES 1 and 2. 12 COMPENSATORY MEASURES:

a. With one or more Loose-Part Detection System channels inoperable for more than 30 days, prepare and submit a Special Report to the Commission pursuant to CPSES Technical Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status.

b. The provisions of Technical Requirement 0.2 Operability 3 .

Criteria 3.0.3 and 3.0.4 are not applicable. !

TESTS / INSPECTIONS TRI.5 Each channel of the Loose-Part Detection Systems shall be demonstrated OPERABLE by performance of:

a. A CHANNEL CHECK at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ,

b. An ANALOG CHANNEL OPERATIONAL TEST

at least once_per 31 days, and l

c. -A CHANNEL CALIBRATION at least once per 18 months. ,

Setpoint verification is not_ applicable. -

BASES 1.5 LOOSE PARTS DETECTION SYST G l The OPERABILITY of the Loose-Part Detection System ensures that sufficient capability is available to detect loose metallic parts in the Reactor System and avoid or mitigate damage to Reactor System components. The allowable out-of-service times and surveillance requirements are concistent with the recommendations of Regulatory ,

Guide 1.133, " Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors," May 1981. '

12 ,

COMANCHE PEAK - UNITS 1 AND 2 1-22 Revision 12. 1 July 15,_1993 i i

CONTAINMENT SYSTEMS 3 /4. 6. 3 CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3 The containment isolation valves shall be OPERABLE.# ,

APPLICABILITY: MODES 1, 2, 3, and 4. 12 ACIl0!!:

With one or more of the containment isolation valve (s) inoperable, maintain at least one isolation valve OPERABLE in each affected~ <

penetration that is open and:

a. Restore the inoperable valve (s) to OPERABLE status within 4. ,

hours, or

b. Isolate each affected penetration within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least one deactivated automatic valve secured in the isolation position, or

c. Isolate each affected penetration within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at '

least one closed manual valve or blind flange, or ,

d. Be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD' SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

]

\

1 SURVEILLANCE RE0VIREMENTS 4.6.3.1 The containment isolation valves shall be demonstrated i

OPERABLE prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its' associated-actuator, control or power circuit by performance of a cycling test, ,

and verification of isolation time. '

The requirements cf Specification 3.6.3 do not apply for those .

valves covered by Specifications 3.7.1.1, 3.7.1.5, 3.7.1.6 and 3 3.7.1.7.

.12

CAUTION: The inoperable isolation valve (s) may be part of a system (s). Isolating the affected penetration (s) may affect the use of the system (s). Consider the Technical Specification Requirements on the affected systerr(s) and act accordingly.

COMANCHE PEAK - UNIIS 1 AND 2 2-2 Revision 12 July 15, 1993

CONTAINMENT SYSTEMS (continued) l CONTAINMENT ISOLATION VALVES ,

SURVEILLANCE RE0UIREMENTS (continued) 4.6.3.2 Each containment isolation valve shall be demonstrated OPERABLE during the REFUELING MODE or COLD SHUTDOWN'at least once per 18 months by:

a. Verifying that on a Phase "A" Isolation test signal. each Phase "A" isolation valve actuates to its isolation position;-

b. Verifying that on a Phase "B" Isolation test signal, each Phase "B" isolation valve actuates to'its isolation position; ,

and

c. Verifying that on a Containment Ventilation Isolation test signal, each pressure relief discharge valve actuates'to its '

isolation position.

4.6.3.3 The isolation time of each power-operated or automatic valve shall be determined to be within its limit when tested pursuant to Specification 4.0.5.

t I

s COMANCHE. PEAK - UNITS 1 AND 2 2-3 July 15, 1993

i TECHNICAL REOUIREMENT 2.1 (Continued). l TABLE 2.1.1 (continued) l CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND >

FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REOUIREMENTS

4. Manual Valves (Continued) .

2BS-0030#- 134 Airlock N.A. Notes 8 Hydraulically 5,6,7 8 Operated Equalization 8 ,

28S-0025# 134 Airlock N.A. Notes 8 Hydraulically 5,6,7 8 Operated Equalization 8 285-0056# 134a Airlock Manual N.A. Notes 8 Equalization 5, 6 8 ,

2BS-0044# 134a Airlock Manual N.A. Notes 8 Equalization 5, 6 8 2BS-0029# 134a Airlock Manual N.A. Notes 8' Equalization 5, 6 3 2BS-0015# 134a Airlock Manual N.A. Notes 8-Equalization 5, 6 8

5. Power-Operated Isolation Valves

HV-2452-1 4 Main Steam to Aux. N.A. N.A. 9 l FPT From Steam Line #1 i

PV-2325 5 Atmospheric Relief N.A. Note 3 8 Steam Generator 3 :

PV-2326 9 Atmospheric Relief N.A. Note 3 8 Steam Generator 3 PV-2327 13 Atmospheric Relief N.A. Note 3 8- j Steam Generator- 3 1 HV-2452-2 17 Main Steam to Aux. N.A. N.A. 8 FPT From Steam Line PV-2328 18 Atmospheric Relief N.A. Note'3 8 Steam Generator '3 HV-2491A 20a Auxiliary Feedwater N.A. N . A .- 8 to Steam Generator

1 COMANCHE PEAX - UNITS 1 AND 2 2-14 July 15, 1993

TECHNICAL REQUIREMENT 2.1- (continuedF TABLE 2.1.1 (continued) l CONTAINMENT ISOLATION VALVES >

MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) -REOUIREMENTS j

5. Power-Operated Isolation Valves (Continued) 8801B 42 Safety Injection N.A. N.A. 8 to Cold Leg Loops

1, #2, #3, and #4 1

8802A 43 SI Injection to H.A. N.A. 8' RCS Hot Leg Loops

2 and #3 8802B 44 SI Injection to N.A. N.A. 8 RCS Hot Leg Loops '

1 and #4 8835 45 SI Injection to N.A. N.A. 8 RCS Cold Leg Loops

1, #2, #3, and #4 8351A 47 ~!

Seal Injection to N.A. N.A. 8-RCPump(Loop #1) 8351B 48 Seal Injection to N.A. N.A. 8 RCPump(Loop #2) 8351C 49 Seal Injection to N.A. N.A. 8 RCPump(Loop #3) ,

83510 50 Seal Injection to N.A. N.A. 8 3 RCPump(Loop #4)- ;

HV-4777 54 Containment Spray N.A. Note 4. 8 to Spray Header 2 (Train B)

HV-4776 55 Containment Spray N.A. Note 4 8-to Spray Header 2 (Train A) i 8840 63 RHR.to Hot Leg N.A. Note 4 8 Loops #2 and #3 '2 -

8811A 125 Containment N.A. N.A. Et Recirc. Sump to RHR Pumps (TrainA)

-COMANCHE PEAK - UNITS 1 AND 2 2-16 July 15, 1993 l

TECHNICAL REQUIREMENT 2.1 (continued)

TABLE 2.1.1 (continuedl CONTAINMENT ISOLATION VALVES MAXIMUM ,

ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) RE0UIREMENTS

10. Relief. Valves (Continued)

RC-036 41a Penetration Ther- N.A. C 8 ;

mal Relief-WP-7176 52a Penetration Ther- N.A. .C 8 mal Relief DD-430 60a Penetration Ther- N.A. C .8 mal Relief IVD-907- 61a Penetration Ther- N.A. C 12 I 2VD-896 mal Relief 12 PS-503 74a Penetration Ther- N.A. C 8 mal Relief PS-501 77a Penetration Ther- N.A. C 8 mal Relief PS-502 78a Penetration Ther- N.A. C 8 mal Relief PS-500 80a Penetration Ther- N.A. C 8 -

mal Relief WP-7177 81a Penetration Ther- N.A. C 8 mal Relief ,

1S1-8972 83a Penetration Ther- .N.A. C 9 251-8983 mal Relief ,

1CC-1067 114a Penetration Ther- N.A. C- -9 20C-1090 mal Relief .

1CH-0271 120a Penetration Ther- N.A. C 9 2CH-0281 mal Relief ;

1CH-0272 121a Penetration Ther- N.A. C 9 -

2CH-0282 mal Relief SI-0182 125 Pressure Relief N.A. N.A. 9 for Bonnet of 9 l MOV 8811A 9 i

COMANCHE PEAK - UNITS 1 AND 2 2-25 Revision 12 July'15, 1993

1 TECHNICAL REQUIREMENT 2.1 (continuadl TABLE 2.1.1 (continued)

TABLE NOTATIONS

Identification code for containment penetration and associated isolation valves in FSAR Tables 6.2.4-1, 6.2.4-2, and 6.2.4-3.

May be opened on an intermittent basis under administrative control.

The table does not list local vent, drain and test connections as they are a special class of containment isolation valves and are locked closed and capped to meet containment isolation criteria when located within the penetration boundary.

Note 1: All four MSIV bypass valves are locked closed in Mode 1.

During Mode 2, 3, and 4 one MSIV bypass valve may be. opened provided the other three MSIV bypass valves are locked closed and their associated MSIVs are closed.

Note 2: These valves require steam to be tested and are thus not required to be tested until the plant is in MODE 3.

Note 3: These valves are included for table completeness; the requirements of Specification 3.6.3 do not apply. Instead, the requirements of Specification 3.7.1.1, 3.7.1.5, 3.7.1.6 3 and 3.7.1.7 apply for main steam safety valves, main steam 3 isolation valves, feedwater isolation valves and steam 3 generator atmospheric relief valves, respectively. 3 Note 4: These valves are leak tested in accordance with Technical Specification Surveillance Requirement 4.6.1.2. 2 Note 5: 10 CFR 50 Appendix J. Type C testing of these valves is 6-satisfied by the testing of the airlock under Technical 6 Specification Surveillance Requirement 4.6.1.3b. 6 Note 6: These valves are consie red an integral part of the airlock 6 associated with their i nective airlock door. Therefore, 6 they are subject to the untrols of Specification 3.6.1.3. 6 Note 7: These valves are secured in position by hydraulic system 6 locks and/or interlocks and do not require separate locks. 6

'l 4

COMANCHE PEAK - UNITS 1 AND 2 2-27 July 15, 1993 ]

. TECHNICAL REOUIREMENT 2.1 (continued) i BASES l

- 2.1 CONTAINMENT ISOLATION VALVES The OPERABILITY of the containment isolation valves ensures that-the [

containment atmosphere will be isolated from the outside environment. t in the event of a release of radioactive material to the' containment atmosphere or pressurization of the containment and is. consistent with l the requirements of General Design Criteria 64 through 57 of-10CFR50, Appendix A. Containment isolation within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a.LOCA. .

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' COMANCHE PEAK - UNITS 1 AND 2 2-28 July 15, 1993

3 PLANT SYSTEMS 3/4.7.9 SNUBBERS LIMITING CONDITION FOR OPERATION 3.7.9 All snubbers shall be OPERABLE. The only snubbert excluded from the requirements are those installed on nonsafety-ralated systems, and then only if their failure or failure of the system on chicn they are installed would have no adverse'effect on any safety-related system.

APPLICABILITY: MODES 1, 2, 3, and 4. MODES 5 and 6 for snubbers 12 located on systems required OPERABLE in those MODES.

ACTION:

With one or more snubbers inoperable on any system, within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months replace or restore the inoperable snubbers (s) to OPERABLE status and perform an engineering evaluation in accordance with the approved augmented inservice inspection program on tne attached component or declare the attached system inoperable and follow the tppropriate ACTION statement for thit system. +

SURVEILLANCE RE0VIREMENTS ___

4.7.9 Each snubber shall be demonstrated OPERABLE by performance of the requirements of the approved augmented inservice inspection program.

12 COMANCHE PEAK - UNITS 1 AND 2' 3-2 Revision 12 July 15, 1993 nu s ,we-

l TECHNICAL RE0VIREMENT 3.1 SNUBBERS TESTS / INSPECTIONS i

)

TR3.1 Each snubber shall be demonstrated.CPERABLE.by performance of the following augmented inservice-inspection program in lieu of the requirements of Technical Specification 4.0.5.

a. Inspection Typel As used in this specification, type of snubber shall mean snubbers-of the same design and manufacturer, irrespective of capacity.

b. Visual Inspection 1 Snubbers are categorized as inaccessible or accessible during-reactor operation. Each of these groups (inaccessible and 10 accessible) may be inspected independently. The first inservice 12 visual inspection of each type of snubber shall be' performed after 2 months *** but within 10 months of commencing POWER OPERATION and shall include all snubbers. If all snubbers of each type.on any system are found OPERABLE during the first inservice visual 10 inspection, the second inservice visual inspection on that type shall be performed at the first refueling outage. Otherwise subsequent visual inspections of a given system shall be' performed in accordance with the followir.g schedule:

~

No. of Inoperab_le Snubbers 10 of Each Type on any System Subsequent Visual 10

. Der Inspection Period ** Inspection Period

10 1

0,1 12 months 1 25% 10 -

2 6 months 25% 10 3,4 124 days 1 25% 10 5,6,7 62 days 1 25% 10 8 or more 31 days 1 25% .10 Visual inspection intervals following the second refueling outage ~ 10 shall be determined based upon the criteria provided in the table below:

10

The inspection interval for each type of snubber shall not be 10 1 lengthened more than one step at a time unless a generic problem has '

been identified and corrected; in that event the inspection interval i may be lenthened one step the first time and two steps thereafter if ,

no inoperable snubbers of that type are.found on any system.

- If one or-more snubbers of each type on any system are found 10 inoperable during the first inservice visual inspection, the second inservice visual inspection on that type shall be performed no later than the first refueling outage or the subsequent visual inspection period, whichever comes first.

- - The Unit 2 visual inspections shall not begin until the Unit'2 12- .i Startup Testing Program has been completed. )

1 COMANCHE PEAK - UNITS 1 AND 2 3-3 Revision 12 July 15, 1993 l

TECHNICAL REOUIREMENT 3.1 (continued)

SNUBBERS TESTS / INSPECTIONS (continued)

NUMBER OF UNACCEPTABLE SNUBBERS 5 Population Column A Column B Column C 5.

or Category Extend Interval Repeat Interval Reduce Interval 5 (Notes 1 & 2) (Notes 3 & 6) (Notes 4 & 6) (Notes 5 & 6) 5-1 0 0 1 5 80 0 0 2 5 100 0 1 4 5 5

150 0 3 8 5 200 2 5 13 5 300 5 12 25 5 5

400 8 18 36 5 500 12 24 48 5 750 20 40 78 5 1000 or greater 29 56 109 5 5

Note 1: The next visual inspection interval for a snubber 5 population or category size shall be determined based upon the previous inspection interval and the number of unacceptable snubbers found during that interval.

Snubbers may be categorized, based upon their accessibility during power operation, as accessible or inaccessible. These categories may be examined separately or jointly. However, the licensee must make and document that decision before any inspection and shall use that decision as.the basis upon which to determine the next inspection interval for that category.

Note 2: Interpolation between population or category sizes and the 5 number of unacceptable snubbers is permissible. Use next lower integer for the value of the limit for Columns A, B, or C if that integer includes a fractional value of unacceptable snubbers as' determined by interpolation.

Note 3: If the number of unacceptable snubbers is equal to or less 5 than the number in Column A, the next inspection interval-may be twice the previous interval but not greater than 48 months.

Note 4: If the number of unacceptable snubbers is equal to or less 5 than the number in Column B, but greater than the number in Column A, the next inspection interval shall be the same as the previous interval.

COMANCHE PEAK - UNITS 1 AND 2 3-4 July 15, 1993

TECHNICAL REOUIREMENT 3.1 (continued)

SNUBBERS l

TESTS / INSPECTIONS (continued) j Note 5: If the number of unacceptable snubbers is equal to or 5 greater than the number in Column C, the next inspection interval shall be two-thirds of the previous interval.

However, if the number of unacceptable snubbers is less ,

than the number in Column C but greater than-the number in Column B, the next interval shall be reduced proportionally by interpolation, that is, the previous interval shall be reduced by a factor that is one-third of. '

the ratio of the difference between the number.of unacceptable snubbers found during the previous. interval and the number in Column B to the difference in the numbers in Columns B and C.

Note 6: The provisions of Specification 4.0.2 are applicable for 5 all inspection intervals up to and including 48 months.

c. Visual Inspection Acceptance Criteria Visual inspections shall verify that: (1) there are no visible indications of damage or impaired OPERABILITY, (2) attachments to the foundation or supporting structure are secure, and (3) fasteners for attachment of the snubber to the component and to the snubber anchorage are secure. Snubbers which appear ,

inoperable as a result of visual inspections may be determined OPERABLE for the purpose of establishing the next visual .

inspection interval, provided that: (1) the cause of the !

rejection is clearly established and remedied for that particular snubber and for other snubbers irrespective of type.that may be generically susceptible; or (2) the affected snubber is functionally tested in the as-found condition and determined :

OPERABLE per Test / Inspection TR_3.lf. All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as inoperable snubbers.

d. Transient Event Inspection An inspection shall be performed of all snubbers attached.to sections of systems that have experienced unexpected, potentially -

damaging transients as determined from a rev.iew of operational data. A visual inspection of those systems shall be performed- l within 6 months following such an event. In addition to satisfying the visual inspection acceptance criteria, freedom-of-- ;

motion of mechanical snubbers shall be verified using at least one of the following: (1) manually induced snubber movement; or (2) evaluation of in-place snubber piston setting; or (3) stroking the mechanical snubber through its full range of travel. '

COMANCHE PEAK - UNITS 1 AND 2 3-5 July 15, 1993 l

TECHNI(M REQUIREMENT 3.1 (continued)

SNUBBERS TESTS /INSP_LCJTlQN_S(continued)

e. Functional Tests During the first refueling shutdown and at least once per 18 months thereafter during shutdown, a representative sample of snubbers of each type shall be tested using one of the following sample plans. The sample plan for each type shall be selected prior to the test period and cannot be changed during the test period. The NRC Regional Administrator shall be notified in writing of the sample plan selected for each snubber type prior to the test period or the sample plan used in the prior test period shall be implemented:

1) At least 10% of the total of each type of snubber shall be functionally tested either in-place or in a bench test. For each snubber of a type that does not meet the functional test acceptance criteria of Test / Inspection TR3.lf, an additional 10% of that type of snubber shall be functionally tested until no more failures are found or until all snubbers rf that type have been functionally tested; or

2) A representative sample of each type of snubber shall be functionally tested in accordance with Figure 3.1-1. "C" is the total number of snubbers of a type found not meeting the acceptance requirements of Test / Inspection TR3.lf. The cumulative number of snubbers of a type tested is denoted by "N". At the end of each day's testing, the new values of "N" and "C" (previous day's total plus current day's increments) shali be plotted on Figure 3.1-1. If at any time the point plotted falls in the " Accept" region, testing of snubbers of that type may be terminated. When the point plotted lies in 5 the " Continue Testing" region, additional snubbers of that type shall be tested until the point falls in the " Accept" region, or all the snubbers of that type have been tested.

1 COMANCHE PEAK - UNITS 1 AND 2 3-6 July 15, 1993

>;f

__ _ . . . . . _ _ . _ _ _ _ - . . _ . - . . ____ _ __ ~_-. . _ _ ,

IE(BNICAL RE0UIREMENT 3.1 (continued)

SNUBBERS TESTS / INSPECTIONS (continued)

g. Functional Test Failure Analysis (continued)

-l For the snubbers found inoperable, an engineering evaluation.shall q be performed on the components to which the inoperable snubbers are attached. The purpose of this engineering evaluation shall be to determine if the components.to which the inoperable snubbers are attached were adversely affected by the inoperability of the snubbers in order to ensure that the component remains capable of meeting the designed servicc.

If any snubber selected for functional testing either fails to lock up or fails to move, i.e., frozen in-place, the cause will be evaluated and, if caused by manufacturer or design deficiency, all snubbers of the same type subject to the same defect shall be functionally tested. This testing requirement shall be independent of the requirements stated in Test / Inspection TR3.le for snubbers not meeting the functional test acceptance criteria.

h. Functional Testina of ReDaired and Replaced Snubbers Snubbers which fail the visual inspection or the functional test acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the-functional test results shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the freedom-of-motion test must ,

have been performed within 12 months before being installed in the unit,

i. Snubber Service Life Proaram The service life of hydraulic and mechanical snubbers shall be ;

monitored to ensure that the service life is not exceeded between surveillance inspections. The maximum expected service life for various seals, springs, and other critical parts shall be ,

determined and established based on engineering information and shall be extended or shortened based on monitored test results and failure history. Critical parts.shall be replaced so that the maximum service life will not be exceeded during a period when,the '

snubber is required to be OPERABLE. Part replacement shall be documented and the documentation shall be retained in accordance with Technica; Specification 6.10.2.

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COMANCHE PEAK - UNITS 1 AND 2 3-8 July 15, 1993 !

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3/4.8.4 ELECTRICAL E0UIPMENT PROTECTIVE DEVICES CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES- ,

1 LIMITING CONDITION FOR'0PERATION 3.8.4 All' containment penetration conductor overcurrent protective devices shall be OPERABLE.

APPLICABILI11: MODES 1, 2, 3, and 4. 12 ACTION:

With one or more of the containment penetration conductor overcurrentL protective device (s) inoperable:

a. Restore the protective device to OPERABLE status or: ,

1. Deenergize the circuit (s)'by racking out, locking open,.or.-

removing the inoperable protective device.and tripping / removing the associated protective' device within -

72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affected system or component inoperable, and verify the inoperable protective device-4 racked out, locked open, or removed at least once per:31 days thereafter; the-provisions of Specification 3.0.4 are ,

not applicable to overcurrent protective devices 11n circuits which have their associated protective device-tripped / removed and their inoperable protective device racked out, locked open, or removed; or

2. Deenergize_thecircuit(s)bytripping/removingthe associated protective device nr racking out, locking open, or removing the inoperable protective device within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affected1 system or component inoperable, and verify the associated protectivi device to be tripped / removed or the inoperable protective device racked out, locked open, or removed at least once per.7 days thereafter; the provisions of SpecificationL3.0.4 are not applicable to overcurrent devices in circuits which-have their associated protective device tripped / removed or' ;

their inoperable protective device: racked out, locked.

open, or removed; or

b. Be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

12.

COMANCHE PEAK - UNITS 1 AND 2 4-2 Revision.12 July 15, 1993,

s. . . . . '- . . _ , . . _ _ _ _ _ _ _ _ .._m . _ _. , . ___ _________________________i___._____,._________._._.____..

l ELECTRICAL EQUIPMENT PROTECTIVE DEVICES (continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES SURVEILLANCE REQUIREMENTS 4.8.4 The containment penetration conductor overcurrent protective devices shall be demonstrated OPERABLE:

a. At least once per 18 months:

1) By verifying that the medium voltage 6.9 kV and low l voltage 480V switchgear circuit. breakers are OPERABLE by )

. selecting, on a rotating basis, at least 10% of the '

circuit breakers of each current rating and performing the !

following:

a) A CHANNEL CALIBRATION of the associated protective relays, t

b) An integrated system functional test which includes simulated automatic actuation of the system and verifying that each relay and associated circuit breakers and control circuits function as designed, i and c) For each circuit breaker found inoperable during these functional tests, one or an additional representative sample of at least 10% of all the circuit breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that type have been functionally tested;

2) By selecting and functionally testing a representative !

sample of at least 10% of each type 480V molded case !

circuit breakers and of lower voltage circuit breakers.

Circuit breakers selected for functional testing shall be selected on a rotating basis. Testing of these circuit breakers shall consist of injecting a current with a value j equal to 300% of the pickup of the long-time delay trip element and 150% of the pickup of the short-time delay trip element, and verifying that the circuit breaker operates within the time delay band width for that-current specified by the manufacturer. The instantaneous element shall be tested by injecting a current equal to 120% of ,

the pickup value of the element and verifying that the 1 circuit breaker trips instantaneously with no intentional l time delay. Molded case circuit breaker testing shall also follow this procedure except that generally no more than two trip elements, time delay and instantaneous, will be involved. The instantaneous element for molded case circuit breakers shall be tested by injecting a current for a frame size of 250 amps or less with tolerances of l

COMANCHE PEAK - UNITS 1 AND 2 4-3 July 15, 1993 i

I ELECTRICAL E0VIPMENT PROTECTIVE DEVICES (continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES SURVEILLANCE RE0VIREMENTS (continued) l

+40%, -25% and a frame size of 400 amps or greater with-tolerances of 125% and verifying that.the circuit breaker-trips instantaneously with no apparent time delay. I Circuit breakers found inoperable during functional ,

testing shall be restored to OPERABLE status prior to resuming operation. For each circuit breaker found inoperable during these functional tests, an additional representative sample of a least 10% of.all the circuit.

breakers of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of'that type have been functionally tested; and

b. At least once per 60 months by subjecting each circuit breaker-to an inspection and preventive maintenance in accordance with -

procedures prepared in conjunction with its manufacturer's- '

recommendations.

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CDMANCHE PEAK - UNITS 1 AND 2 '4-4 July 15,~1993

TECHNICAL REOUIREMENT 4.1 (continued)'

IAJ1E_4.1.la (continued) '8 UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED 2.2 Device Location - 480V Containment

-Switchgear 1EB4 Polar Crane

a. Primary Breaker - ISCCP1

b. Backup Breaker 1EB4-1 and BT-1EB24

1) long Time Delay Relay 1 51 1

~ISCCPI 1

2) Time Delay and Instantaneous Relays

1-62 (1EB4-1 and 62X (1SCCP1) 1 ISCCP1 BT-1EB24) ISCCP1 'l

3. 480VAC from Motor Control Centers 3.1 Device Location - MCC 1EB1-2 Compartment Numbers 12 listed below.

Primary and Backup - Both primary and backup breakers Breakers have. identical trip ratings and are in the same MCC Compt. These )

breakers are General Electric type THED or THFK with. thermal-magnetic trip elements. j Associatedcircuitbreaker(s)showninparentheses;e.g.,'1EB4-1 and BT-1EB24 are backup breakers for 1SCCPl.

1 COMANCHE PEAK - UNITS 1 AND 2 4-8 Revision 12 July 15,1993 q

__ _ __ _ ___ .__O

TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1.la (continued) 8 UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480VAC from Motor Control Centers (continued)

MCC IEB1-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED Motor Operated Valve 1-TV-4691 4M THED Motor Operated Valve 1-TV-4693 3F THED Containment Drain Tank Pump-03 9H THED Reactor Cavity Sump Pump-01 9M THED Reactor Cavity Sump Pump-02 7H THED Containment Sump #1 Pump-01 7M THED Containment Sump #1 Pump-02 6H THED RCP #11 Motor Space Heater-01 6M THED RCP #13 Motor Space Heater-03 8B THED Incore Detector Drive "A" 8D THED Incore Detector Drive "B" 7B THED Incore Detector Drive "F" l 3B THED Stud Tensioner Hoist Outlet-01 7D THED Hydraulic Deck Lift-01 4B THED Reactor Coolant Pump Motor Hoist Receptacle-42 8H THED RC Pipe Penetration Cooling Unit-01 8M THED RC Pipe Penetration Cooling Unit-02 5H THED RCP #11 011 Lift-Pump-01 SM THED RCP #13 Oil Lift Pump-03 10B THED Preaccess Filter Train Package-Receptacle-17 5B THED Containment Ltg. XFMR-14 (PNL C3) 10F THED 5.G. Wet Loyup Circ. Pump 01 (CP1-CFAPRP-01) 12M THED S.G. Wet Layup Circ.' Pump 03 (CP1-CFAPRP-03) 12H THED Containment Ltg. XFMR-28 2 (Phl C11 & C12) 1 COMANCHE PEAK - UNITS 1 AND 2 4-9 July 15, 1993

TECHNICAL REOUIREMENT 4.1 (continued)- l LABLE 4.1.la (continued) 8 UNIT 1 8.

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATIQN

3. 4BOVAC from Motor Control Centers (continued)

MCC 1EB1-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED-6D .THED Refueling Machine (Manipulator Crane-01) 2M THED RC Drain Tank Pump No. l' 1 2F THED Containment Ltg' XFMR-16 (PNL C7 & C9)

IM THED Containment Ltg. XFMR-12 (PNL C1 & C5) 3M THED Preaccess fan No. 11 .

SD THED Fuel Transfer System Reactor Side Cont. Pnl. for TBX-FHSTTS-02_ 12 3.2 Device Location - MCC 1EB2-2 Compartment Numbers 12 listed below. -

Primary and Backup - Both primary and backup breakers have ;

Breakers identical trip ratings and are located in the same MCC compt. These breakers are General Electric type THED or THFK with thermal-magnetic- 12 't trip elements. !

MCC 1EB2-2 G.E. i

, CQMPT. NO. BKR. TYPE SYSTEM POWEREQ 4G THED Motor Operated Valve 1-TV-4692 4M THED Motor Operated Valve 1-TV-4694' ;

3F THED Containment Drain Tank Pump-04 :

7H THED Containment Sump No. 2 Pump-03 7M THED Containment Sump No. 2 Pump-04 6H THED RCP #12 Motor Space Heater-02 >

6M THED RCP.#14 Motor Space Heater-04 ,

, 5B THED Incore Detector Drive "C" Incore Detector Drive "D" 2B THED 7B THED Incore Detector Drive "E" 5D THED Containment Fuel Storage Crane-01 3B THED Stud Tensioner Hoist Outlet-02 4B THED Containment Solid Rad Waste j Compactor-01 i COMANCHE PEAK - UNITS 1 AND 2 4-10 Revision 12 July 15, 1993

. -. .~

l TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1.la (continued) 8 UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480VAC from Motor Control Centers (continued)

MCC IEB2-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED i.

10B THED RCC Change Fixture Hoist Drive-01' 1 10F THED Refueling Cavity Skimmer Pump-01 128 THED Power Receptacles (Cont. El 841')

IM THED S.G. Wet Layup Circ. Pump 02 (CP1-CFAPRP-02) l 12M THED S.G. Wet Layup Circ. Pump 04 (CP1-CFAPRP-04) 8H THED RC Pipe Penetration Fan-03 8M THED RC Pipe Penetration Fan-04 5H THED RCP #12 Oil Lift Pump-02 SM THED RCP #14 011 Lift Pump-04 12H THED Preaccess Filter Train Package Receptacles - 18 6D THED Containment Auxiliary Upper Crane-01 2F THED Containment Ltg. XFMR-13 (PNL C2) 7D THED Containment Elevator-01 2D THED Containment Access Rotating Platform-01 2M THED Reactor Coolant Drain Tank Pump-02 9F THED Containment Ltg. XFMR-17 (PNL C8 & C10) 9M THED Containment Ltg. XFMR-15 (PNL C4 & C6) 3M THED Preaccess Fan-12 1G THFK Distribution Panel 1EB2-2-1 7 CP1-EPDPNB-24 7 3.3 Device location - MCC 1EB3-2 Compartment numbers 12 listed below.

Primary and Backup - Unless noted otherwise, both primary and backup breakers have identical trip ratings and are located in the same MCC compt.

These breakers are General Electric type THED or THFK with thermal-magnetic trip elements.

COMANCHE PEAK - UNITS 1 AND 2 4-11 Revision 12 July 15, 1993 l

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TECHNICAL REQUIREMENT-4.1 (continued) I TABLE 4.1.la (continued) 8 UNIT'1 8 CONTAINMENT PENETRATION CONDUCTOR-OVERCURRENT PROTECTIVE DEVICES ,

i DEVICE NUMBER i AND LOCATION l

3. 480VAC from Motor Control Centers (continued) l MCC 1EB3-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED BRF THED JB-15-10050, Altern. Feed to Motor. -

Operated Valve 1-8702A IG THED Motor Operated Valve 1-8112 9G THED Motor Operated Valve 1-8701A '

9M THED Motor Operated Valve 1-8701B SM THED Motor Operated Valve 1-8000A SG THED Motor Operated Valve 1-HV-6074 :'

4G THED Motor Operated Valve 1-HV-6076 4M THED* Motor Operated Valve 1-HV-6078-2G THED Motor Operated Valve 1-HV-4696 2M THED Motor-0perated Valve 1-HV-4701 3G THED* Motor Operated Valve 1-HV-5541 3M THED* Motor Operated Valve 1-HV-5543 1M THED Motor Operated Valve'1-HV-6083 6F THED Motor Operated Valve'l-8808A l12 j 6M THED Motor Operated Valve 1-8808C 12:

7M THED Containment Ltg. XFMR-18 i (PNL SC1'& SC3) 8M THED Neutron Detector Well Fan-09 7F THFK Electric H2 Recombiner Power Supply PNL .

8RM THED Motor. Operated Valve.1-HV-4075C.

Motor Operated Valve 1-HV-4782-9RF THED 9RM THED Motor Operated Valve 1-8811A t

Primary protection is provided by Gould Tronic TR5 fusible switch with 3.2A fuse. .

i i-COMANCHE PEAK - UNITS 1 AND 2 4-12 Revision 12 !

July 15, 1993 -;

i

t TECHNICAL REOUIREMENT 4.1 (continued) .

-TABLE 4.1.la (continued) 8 UNIT 1 -8 CONTAINMENT PENETRATION CONDUCTOR i OVERCURRENT PROTECTIVE DEVICES !

DEVICE NUMBER l AND LOCATION j

3. 480VAC From Motor Control Centers (continued) l 3.4 Device Location - MCC 1EB4-2. Compartment numbers 12 listed below.

Primary and Backup - Unless noted otherwise, both primary and backup breakers have identical trip ratings and are located in the same MCC compt.

These breakers are General Electric !

type THED or THFK with thermal- '

magnetic trip elements. !

MCC 1EB4-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED IM THED JB-1S-1230G, Altern. Feed ,

to Motor Operated Valve 1-8701B 8G THED Motor Operated Valve 1-8702A !

BM THED Motor Operated Valve 1-8702B 4 4M THED Motor Operated Valve 1-8000B i 4G THED Motor Operated Valve 1-HV-6075 ;

3G THED Motor Operated Valve 1-HV-6077 ;

3M THED* Motor Operated Valve.1-HV-6079 j 2G THED Motor Operated Valve 1-HV-5562 .i 2M THED* Motor Operated Valve 1-HV-5563 SF THED Motor Operated Valve 1-8808B .

SM THED Motor Operated Valve 1-8808D .

6M THED Containment Ltg. XFMR-19 l (PNL SC2 & SC4) !

7M THED . Neutron Detector Well Fan-10 6F THFK Elect. H2 Recombiner Power l Supply PNL-02 8RF THED Motor Operated Valve 1-HV-4783 BRM THED Motor Operated Valve 1-8811B

l l

l, Primary protection is provided by Gould Tronic TR5 fusible switch. :l with 3.2A fuse. !

i I

COMANCHE PEAK . UNITS 1 AND 2 4-13 Revision 12 July 15,-1993 1

. ~ . .- ..- -

TECHNICAL REOUIREMENT 4.1 (continued)

TABLE 4.1.la (continued)- 8 UNIT 1 8 CONTAINMENT EENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

6. 125V DC Control Power Various

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XED1-1 1,6 TED XED2-1 1,3,6 TED XD2-3 8 TED 1 1ED2-1 14,17 TED 1ED1-1 14 TED 2 1D2-3 7,10 TED 102-2 9 TED 1ED2-2 12 TED 1ED3-1 5 TED 1E01-2 7,8 TED TBX-WPXILP-01 Main (LBK3) FB(Westinghouse) 1

7. 120V AC Control Power from Isolation XFMR TXEC3 & TXEC4 1

a. Primary Devices - N/A (Fuse) 1

b. Backup Breakers - Square D Type Q08 located in 12 .-

Miscellaneous Signal Control Cabinet. 1 1 Panel Board A, Ckt. Bkr. connected at TB4-13 12.

2 Panel Board B, Ckt. Bkr. connected at TB6-7~ 12'

8. 120V AC Power-for Personnel and Emergency Airlocks

a. Primary Devices - N/A (Fuse)

b. Backup Breakers-GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XEC2 34 TED XECl-2 2 TED COMANCHE PEAK - UNITS 1 AND 2 4-16 Revision 12 July 15, 1993

TECHNICAL REQUIREMENT 4.1 (continued) 8 TABLE 4.1.lb 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICfl 8 DEVICE NUMBER SYSTEM 8 AND LOCATION P_0RE2fR 8

1. C.9 KVAC from Switchgears 8 l a. Switchgear Bus 2A1 RCP #21 8 l

1) Primary Breaker 2PCPX1 8 I a) Relay 50M1-51 8 b) Relay 86M 9 c) Relay 51M2 8

2) Backup Breakers 2Al-1 or 2Al-2 8 a) Relay 51M3 8 b) Relay 51 for 2A1-1 12 c) Relay 51 for 2A'-2

. 12 d) Relay 86/2A1 12

b. Switt:1 gear Bus 2A2 RCP #22 8

1) Primary Breaker 2PCPX2 8 a) Relay 50M1-51 8 b) Relay 86M 9 c) Relay 51M2 8

2) Backup Breakers 2A2-1 or 2A2-2 8 )

a) Relay 51M3 8 '

b) Relay 51 for 2A2-1 12 c) Relay 51 for 2A2-2 12 d) Relay 86/2A2 12 i

COMANCHE PEAK - UNITS 1 AND 2 4-18 Revision 12 July 15, 1993

TECHNICAL REQUIREMENT 4.1 jcontinued) 8 TABLE 4.1.lb (continued) 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 AND LOCATION POWERED 8

1. 6.9 KVAC from Switchgears (continued) 8 8

c. Switchgear Bus 2A3 RCP #23 8

1) Primary Breaker 2PCPX3 8 a) Relay 50M1-51 8 b) Relay 86M 9 c) Relay 51M2 8

2) Backup Breakers 2A3-1 or 2A3-2 8 a) Relay 51M3 8 b) Relay 51 for 2A3-1 12 c) Relay 51 for 2A3-2 12 d) Relay 86/2A3 12

d. Switchgear Bus 2A4 RCP #24 8

1) Primary Breaker 2PCPX4 8 a) Relay 50M1-51 8 b) Relay 86M 9 c) Relay 51M2 8

2) Backup Breaker 2A4-1 or 2A4-2 8 a) Relay 51M3 8 b) Relay 51 for 2A4-1 12 c) Relay 51 for 2A4-2 12 d) Relay 86/2A4 12

2. 480 VAC from Switchgears 8 2.1 Device Location - Containment 8 480V Switchgears 2EB1, 2EB2, Recirc. Fans 8 2EB3 and 2EB4 and CRDM 8 Vent Fans 8

a. Primary Breakers - 2FNAV1, f88 2FNAV2, 2FNAV3, 2FNAV4, 2FNCB1 and 2FNCB2 8 COMANCHE PEAK - UNITS 1 AND 2 4-19 Revision 12 I July 15, 1993

I l

TECHNICAL REQUIREMENT 4.1 (continued) 8 TABLE 4.1.lb (continued) 8 l UNIT 2 8 1

CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 AND LOCATION POWERED. 8 2.2 Device Location - 480V Containment 8 Switchgear 2EB4 Polar Crane 8

a. Primary Breaker - 2SCCP1 8

b. Backup Breaker 2EB4-1 and BT-2EB24 8

1) Long Time Delay Relay 8 51 8 2SCCP1 8

2) Time Delay and Instantaneous Relays

8 62 ,tEB4-1 and 62X (2SCCP1) 8 2SCCP1 BT-2EB24) 2SCCP1 8 8

3. 480VAC from Motor Control Centers 8 3.1 Device Location - MCC 2EB1-2 Compartraent Numbers 12 listed below. 8 Primary and Backup - Both prirr.ary and backup breakers 8 Breakers have identical trip ratings and 8 are in the same MCC Compt. These 8 breakers are General Electric 8 type THED or THFK with thermal- 8 magnetic trip elements. 8 I

8 f Associated circuit breaker (s) shown in parentheses; e.g., 2EB4-1 8

! and BT-2EB24 are backup breakers for 2SCCPl.

l COMANCHE PEAK - UNITS 1 AND 2 4-21 Revision 12 July 15, 1993 5

, - - _ ~ -

) .

m TECHNICAL RE0VIREMEFT 4.1 (continued) 8 TABLE 4.1.lb (continued) 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 QyERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 480VAC from Motor Control Centers (continued) 8 MCC 2EB1-2 G.E. 8 COMPT. NO. BKR. TYPE SYSTEM POWERED 8 4G THED Motor Operated Valve 2-TV-4691 8 4M THED Motor Operated Valve 2-TV-4693 8 3F THED Containment Drain Tank Pump-03 8 9H THED Reactor Cavity Sump Pump-01 8 9M THED Reactor Cavity Sump Pump-02 8 7H THED Containment Sump #1 Pump-01 8 ,

7M THED Containment Sump #1 Pump-02 8 !

6H THED RCP #21 Motor Space Heater-01 8 6M THED RCP #23 Motor Space Heater-03 8 8B THED Incore Detector Drive "A" 8 8D THED Incore Detector Drive "B" 8 7B THED Incore Detector Drive "F" 8 3B THED Stud Tensioner Hoist Outlet-01 8 70 THED Hydraulic Deck Lift-01 8 )

4B THED Reactor Coolant Pump Motor 8 i Hoist Receptacle-42 8 I i

8H THED RC Pipe Penetration Cooling 8 l Unit-01 8

BM THED RC Pipe Penetration Cooling 8 Unit-02 8 5H THED RCP #21 011 Lift Pump-01 8 SM THED RCP #23 Oil Lift Pump-03 8 10B THED Preaccess Filter Train Package 8 Receptacle-17 8 5B THED Containment Ltg. XFMR-14 8 (PNL 2LPC3) 8 10F THED S.G. Wet Layup Circ. Pump 01 8 (CF2-CFAPRP-01) 8 l

12M THED S.G. Wet Layup Circ. Pump 03 8 (CP2-CFAPRP-03) 8 12H THED Containment Ltg. XFMR-28 8 (PNL 2C11 & 2C12) 8 128 THED Personnel Air Lock Hydraulic 10 Unit #2 10 COMANCHE PEAK - UNITS 1 AND 2 4-22 July 15, 1993

TECHNICAL RE0UIREMENT 4.1 (continued) 8 TABLE 4.1.lb (continued) 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 480VAC from Motor Control Centers (continued) 8 MCC 2EB1-2 G.E. 8 COMPT. NO. BKR. TYPE SYSTEM PO' FRED 8 l 6D THED Refueling Machine (Manipulator 8 Crane-01) 8 2M THED RC Drain Tank Pump No. 1 8 2F THED Containment Ltg. XFMR-16 8

' (PNL 2C7 & 2C9) 8 1M THED Containment Ltg. XFMR-12 8 (PNL 2LPC1 & 2LPC5) 8 3M THED Preaccess Fan No. 11 8 50 THED Fuel Transfer System Reactor 8 Side Cont. Pnl. for TCX-FHSTTS-01 8 3.2 Device Location - MCC 2EB2-2 Compartment Numbers 12 listed below. 8 Primary and Backup - Both primary and backup breakers 8 Breakers have identical trip ratings and are 8 located in the same MCC compt. 8 These breakers are General Electric 8 type THED or THFK with thermal- 12 magnetic trip elements. 8 MCC 2EB2-2 G.E. 8 COMPT. NL BKR. TYPE SYSTEM POWERED 8 4G THED Motor Operated Valve 2-TV-4692 8 i 4M THED Motor Operated Valve 2-TV-4694 8 3F THED Containment Drain Tank Pump-04 8 7H THED Containment Sump No. 2 Pump-03 8 7M THED Conte.inment Sump No. 2 Pump-04 8 6H THED RCP #22 Motor Space Heater-02 8 6M THED RCP #24 Motor Space Heater-04 8 5B THED Incore Detector Drive "C" 8 2B THED Incore Detector Drive "D" 8 78 THED Incore Detector Drive "E" 8 SD THED Containment Fuel Storage Crane-01 8 3B THED Stud Tensioner Hoist Outlet-02 8 10 COMANCHE PEAK - UNITS 1 AND 2 4-23 Revision 12 July 15, 1993

TECHNICAL REQUIREMENT 4.1 (continuedl 8 TABLE 4.1.lb (continued) 8 UNIT 2 8 1

[0NTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 48CVAC from Motor Control Centers (continued) 8 MCC 2EB2-2 G.E. 8 COMPT. NO,. BKR. TYPE SYSTEM POWERED 8 10B THED RCC Change Fixture Hoist Drive-01 8 10F THED Refueling Cavity Skimmer Pump-01 8 12B THED Power Receptacles (Cont. E1. 8 841') 8 1M THED 5.G. Wet Layup Circ. Pump 02 8 (CP2-CFAPRP-02) 8 12M THED S.G. Wet Layup Circ. Pump 04 8 (CP2-CFAPRP-04) 8 8H THED RC Pipe Penetration Fan-03 8 8M THED PC Pipe Penetration Fan-04 8 5H THED RCP #22 011 Lift Pump-02 8 SM THED RCP #24 Oil Lift Pump-04 8 12H THED Preaccess Filter Train Package 8 Receptacles - 18 8 60 THED Containment Auxiliary Upper 8 Crane-01 8 2F THED Containment Ltg. XFMR-13 (PNL 8 2LPC2) 8 o 70 THED Containment Elevator-01 8 2D THED Containment Access Rotating 8 Platform-01 8 2M THED Reactor Coolant Drain Tank Pump-02 8 9F THED Containment Ltg. XFMR-17 8 (PNL 2C8 & 2C10) 8 9M THED Containment Ltg. XFMR-15 8 (PNL 2LPC4 & 2LPC6) 8 3M THED Preaccess Fan-12 8 10 10 1C THFK Containment Welding Receptacles 8 3.3 Device Location -MCC 2EB3-2 Compartment numbers 12 listed below. 8 Primary and Backup -Unless noted otherwise, both 8 primary and backup breakers have 8 identical trip ratings and are 8 located in the same MCC compt. 8 These breakers are General Electric 8 type THED or THFK with thermal- 8 magnet'c trip elements. 8 CDMANCHE PEAK - UNITS 1 AND 2 4-24 Revision 12 July 15, 1993

's j 1

i. 6

^^M I TECHNICAL REQUIREMENT 4.1 (continued) 8 TABLE 4.1.lb (continued) 8 e

UNIT 2 8

[0NTAINMENT PENETRATION CONDUCTOR 8 QVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATIDji 8 l

3. 480VAC from Motor Control Centers (continued) 8' MCC 2EB2-2 G.E. 8 1

COMPT NO. BKR. TYPE SYSTEM POWERED 8 1

10B THED RCC Change Fixture Hoist Drive-01 8 10F THED Refueling Cavity Skimmer Pump-01 8 12B THED Power Receptacles (Cont. El. G 841') 8 1M THED S.G. Wet Layup Circ. Pump 02 8 (CP2-CFAPRP-02) 8 12M THED S.G. Wet Layup Circ. Pump 04 8 (CP2-CFAPRP-04) 8 ,

8H THED RC Pipe Penetration Fan-03 8 l 8M THED RC Pipe Penetration Fan-04 8 5H THED RCP #22 Oil Lift Pump-02 8 i

SM THED RCP #24 011 Lift Pump-04 8 l 12H THED Preaccess Filter Train Package 8 Receptacles - 18 8 60 THED Containment Auxiliary Upper 8 Crane-01 8 2F THED Containment Ltg. XFMR-13 (PNL 8 ,

2LPC2) 8 7D THED Containment Elevator-01 8 2D THED ontainment Access Rotating 8 Platform-01 8 2M THED Reactor Coolant Drain Tank Pump-02 8 9F THED Containment Ltg. XFMR-17 8 (PNL 2C8 & 2C10) 8 9M THED Containment Ltg. XFMR-15 8 (PNL 2LPC4 & 2LPC6) 8 3M THED Preaccess Fan-12 8 10 10 1C THFK Containment Welding Receptacles 8 3.3 Device Location -MCC 2EB3-2 Compartment numbers 12 listed below. 8 Primary and Backup -Unless noted otherwise, both 8 primary and backup breakers have 8 identical trip ratings and are 8 located in the same MCC compt. 8 These breakers are General Electric 8 type THED or THFK with thermal- 8 magnetic trip elements. 8 COMANCHE PEAK - UNITS 1 AND 2 4-24 Revision 12 July 15, 1993 L - -- ---- -_------------- - - - _ _ _ _ __

TECHNICAL REOUIREMENT 4.1 (continuecil 8 TABLE 4.1.lb (continued) 8 i

UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER l AND LOCATION

3. 480VAC from Motor Control Centers (continued) 8 l MCC 2EB3-2 G.E. 8 COMPT. NO. EKR. TYPE S1 STEM POWERED 8 8RF THED Altern. Feed to Motor 8 Operated Valve 2-8702A 8 1G THED Motor Operated Valve 2-8112 C 9G THED Motor Operated Valve 2-8701A 8 9M THED Motor Operated Valve 2-8701B 8 SM THED Motor Operated Valve 2-8000A 8 SG THED Motor Operated Valve 2-HV-6074 8 4G THED Motor Operated Valve 2-HV-6076 8 4M THED* Motor Operated Valve 2-HV-6078 8 l 2G THED Motor Operated Valve 2-HV-4696 8 2M THED Motor Operated Valve 2-HV-4701 8 3G THED Motor Operated Valve 2-HV-5541 8 3M THED Motor Operated Valve 2-HV-5543 8 1M THED Motor Operated Valve 2-HV-6083 8 6F THED Motor Operated Valve 2-8808A 12 6M THED Motor Operated Valve 2-8808C 12 7M THED Containment Ltg. XFMR-18 8 (PNL 2SC1 & 2SC3) 8 8M THED Neutron Detector Well Fan-09 8 7F THFK Electric H2 Recombiner Power 8 Supply PNL-01 8 8RM THED Motor Operated Valve 2-HV-4075C 8 9RF THED Motor Operated Valve 2-HV-4782 8 9RM THED Motor Operated Valve 2-8811A 8 Primary protection is provided by Gould Tronic TRS fusible switch 8 with 3.2A fuse.

COMANCHE PEAK - UNITS 1 AND 2 4-25 Revision 12 July 15, 1993

~

TECHNICAL RE0VIREMENT 4.1 (continued) 8 TABLE 4.1.lb (continued _1 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 QyfRCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 480VAC From Motor Control Centers (continued) 8 3.4 Device Location - MCC 2EB4-2 Compartment numbers 12 listed below. 8 Primary and Backup - Unless noted otherwise, both 8 ;

primary and backup breakers have 8 identical trip ratings and are 8 located in the same MCC compt. 8 These breakers are General 8 Electric type THED or THFK with 8 thermal-magnetic trip elements. 8 MCC 2EB4-2 G.E. 8 COMPT. NO. BKR. TYPE SYSTEM POWERED 8 1M THED Altern. Feed to Motor 8 Operated Valve 2-8701B 8 8G THED Motor Operated Valve 2-8702A 8 8M THED Motor Operated Valve 2-8702B 8 4M THED Motor Operated Valve 2-8000B 8 4G THED Motor Operated Valve 2-HV-6075 8 3G THED Motor Operated Valve 2-HV-6077 8 3M THED* Motor Operated Valve 2-HV-6079 8 2G THED* Motor Operated Valve 2-HV-5562 8 2M THED* Motor Operated Valve 2-HV-5563 8 SF THED Motor Operated Valve 2-8808B 8 SM THED Motor Operated Valve 2-8808D 8 6M THED Containment Ltg. XFMR-19 8 I

(PNL 2SC2 & 2SC4) 8 1 7M THED Neutron Detector Well Fan-10 8 6F THFK Elect. H2 Recombiner Power 8 Supply PNL-02 8 8RF THED Motor Operated Valve 2-HV-4783 8 8RM THED Motor Operated Valve 2-8811B 8 8

Primary protection is provided by Gould Tronic TRS fusible switch 8 with 3.2A fase.

COMANCHE PEAK - UNITS 1 AND 2 4-26 Revision 12 July 15, 1993 l

s TECHNICAL REQUIREMENT 4.1 (continued) 8 lABLE 4.1.lb (continued) 8 UNIT 2 2 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 AND LOCATION POWERED 8

6. 125V DC Control Power Various 8

a. Primary Devices - N/A (Fuse) 8

b. Backup Breakers 8 GENERAL ELECTRIC 8 PANELBOARD NO. CKT. NO. BREAKER TYPE 8 XED1-1 6* TED 12 XED2-1 6* TED 12 2ED2-1 11,17,16 TED 8 2ED1-1 11,14 TED 8 202-3 6,10,11 TED 8 202-2 9 TED 8 2ED2-2 12 TED 8 2ED3-1 5 TED 8 2E01-2 7,8 TED 8 TBX-WPXILP-01 Main (LBK3)* FB(Westinghouse) 12

7. 120V AC Control Power from Isolation XFMR TXEC3 & TXEC4 8

a. Primary Devices - N/A (Fuse) 8

b. Backup Breakers - Square D Type QOB located in 12 Miscellaneous Signal Control Cabinet. 8

1) Panel Board A, Ckt. Bkr. connected at TB3-5 12

2) Panel Board B, Ckt. Bkr. connected at TB5-1 12

8. 12DV AC Power for Personnel and Emergency Airlocks 8

a. Primary Devices - N/A (Fuse) 8

b. Backup Breakers 8 GENERAL ELECTRIC 8 l PANELBOARD NO. CKT. NO. BREAKER TYPE 8 XEC1 12 TED 8 XEC2-2 3 TED 8

These circuits provide backup protection to both Units 1 and 2. 12 Testing of these breakers is controlled by Unit 1 surveillance '

program.

COMANCHE PEAK - UNITS 1 AND 2 4-29 Revision 12 July 15, 1993

ELffTRICAL EQUIPMENT Px0TECTIVE DEVICES (continued).

BASES 4.1 CONTAINMENT PENETRATION CONDUCTOR'0VERCURRENT PROTECTIVE DEVICES The bases for OPERABILITY and surveillance of these devices are contained in the CPSES Technical Specifications.

All Class 1E motor-operated valves' motor starters are provided with thermal overload protection which is permanently bypassed and provides an alarm function only at Comanche Peak Steam Electric Station.

Therefore, there are no OPERABILITY or Surveillance Requirements-for -

these devices, since they will not prevent safety-related valves from performing their function (refer te Regulatory Guide 1.105, " Thermal Overload Protection for Electric Motors on Motor Operated Valves,"

Revision 1, March 1977).

4 l

l COMANCHE PEAK - UNITS 1 AND 2 4-31 July 15, 1993 l

r..,... - . .. . . . . . . . .

COMANCHE PEAK STEAM ELECTRIC-STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING BELOW IS A LEGEND FOR THE EFFECTIVE PAGE LISTING:

Original Submitted July 21, 1989 Revision 1 September 15, 1989 Revision 2 January 15, 1990 Revision 3 July 20, 1990 Revision 4 April 24,'1991 Revision 5 September 6, 1991 Revision 6 November 22, 1991 Revision 7 March 18, 1992 Revision 8 June 30, 1992 Revision 9 December 18, 1992 Revision 10 January 22, 1993 Revision 11 February 3, 1993 Revision 12 July 15, 1993 l

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l EPL-1 July 15, 1993

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I o y

l$ COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL-(TRM) i i

EFFECTIVE PAGE' LISTING-TRM-Tab ' Original TRM-Title Page. June 30. 1992-Table of Contents-Tab Original i Revision.'11 Administrative Controis-Tab Original ,

Administrative Controis-Title Page June 30,-1992 :I 0-1 Revision 12-0-2 January 22, 1993 0-3 -December-18, 1992 j 0-4 June 30, 1992 j 0-5 ' January 22, 1993--

0-6 January 22,'1993-0-7 -January, 22,-1993-0-8 January 22, 1993 0-9 January 22, 1993

~0-10 January 22, 1993-0-11 January. 22,-1993' 0-12 June 30, 1992 0-13 June 30, 1992-0-14 July.15, 1993-0-15 July 15, 1993 0-16 . January 22, 1993 0-17 January 22, 1993 0-18 Revision-12 0-19 Revision 8 20 July 15, 1993-0-21 July 15,;1993 0-22 Revision 8 0-23 Revision 8 0-24 Revision 8-0-25 July 15, 1993 0-26 . January 22,-1993 Technical Requirements-Tab Original Section 1-Tab .Driginal 1-1 June 30, 1992 1-2 Revision 12L 1-3 July:15, 1993 1-4 July 15, 1993 1-5 June 30,1992.

1-6 Revision 12 1-7. July 15, 1993 1-8 July 15,' 1993 1-9 July 15, 1993-1-10 July 15, 1993:

1-11. July 15, 1993 1-12 July 15, 1993-1-13 July 15, 1993 EPL-R July 15, 1993

-__-- _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ - _ _ _ _ -_ _ _ _ _ _ _ - _ __ _____________ _-_ a

COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING 1-14 July 15, 1993 1-15 Revision 12 1-16 June 30, 1992 1-17 Revision 12 1-18 July 15, 1993 1-19 July 15, 1993 1-20 July 15, 1993 1-21 July 15, 1993 1-22 Revision 12 Sec. 2-Tab Original 2-1 June 30, 1992 2-2 Revision 12 2-3 July 15, 1993 2-4 January 22, 1993 2-5 Revision 8 2-6 Revision 8 2-7 Revision 8 2-8 January 22, 1993 2-9 Revision 8 2-10 January 22, 1993 2-11 Revision 8 2-12 Revision 9 2-13 Revision 8 2-14 July 15, 1993 2-15 Revision 8 2-16 July 15, 1993 l 2-17 Revision 8 2-18 Revision 8 )

2-19 January 22, 1993 i 2-20 January 22, 1993 2-21 Revision 8 2-22 Revision 8 2-23 Revision 8 2-24 Revision 8 2-25 Revision 12 2-26 January 22, 1993 2-27 July 15, 1993 2-28 July 15, 1993 Sec. 3-Tab Original 3-1 June 30, 1992 3-2 Revision 12 3-3 Revision 12 3-4 July 15, 1993 3-5 July 15, 1993 3-6 July 15, 1993 3-7 June 30, 1992 3-8 July 15, 1993 EPL-3 July 15, 1993

I COMANCHE PEAK STEAM ELECTRIC STATION UNITS 1 & 2 TECHNICAL REQUIREMENTS MANUAL (TRM)

EFFECTIVE PAGE LISTING 3-9 June 30, 1992 3-10 Revision 11 3-11 Revision 11 Sec. 4-Tab Original 4-1 June 30, 1992 4-2 Revision 12 4-3 July 15, 1993 4-4 July 15, 1993 4-5 Revision 9 4-6 Revision 9 4-7 Revision 8 4-8 Revision 12 4-9 July 15, 1993 4-10 Revision 12 4-11 Revision 12 4-12 Revision 12 4-13 Revision 12 4-14 Revision 8 4-15 Revision 8 4-16 Revision 12 4-17 Revision 10 4-18 Revision 12 l l

4-19 Revision 12 4-20 Revision 8 4-21 Revision 12 4-22 July 15, 1993 4-23 Revision 12 4-24 Revision 12 4-25 Revision 12 4-26 Revision 12 4-27 Revision 8 4-28 Revision 10 4-29 Revision 12 4-30 Revision 10 4-31 July 15, 1993 EPL-Tab Original EPL-1 Revision 12 EPL-2 Revision 12 EPL-3 Revision 12 EPL-4 Revision 12 l

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EPL-4 July 15, 1993

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ML20056C789

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