Text

Proposed TS Section 3/4 Re LCOs & Surveillance Requirements During Operational Modes & TS Table 1.4.1, Seismic Monitoring Instrumentation
	ML20092B808
Person / Time
Site:	Comanche Peak
Issue date:	02/04/1992
From:	; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	;
Shared Package
ML20092B792	List: ML20092B789; ML20092B808;
References
	TXX-92050, NUDOCS 9202110144
	Download: ML20092B808 (76)
	v • d • e

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~ TXX 93050c LATTACHMENT,1 PAGE_2_Of_11

-3/4- LIMITING (ANDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS 3/4.0 APPLICABILITY LIMITING CONDITION FOR OPEMTION 3.0.1~ Compliance with the Limiting Conditions for Operation 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 0peration 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 SHUTOOWN 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 requiremente .are. stated in.the individual specifications.

This specification is not applicable in MODE 5 or 6.

'3.0.4 Entry into an OPERATIONAL MODE or other specified condition shall 'not be made when the conditions for the Limiting Conditions for-Operation are not met and the associated ACTION requires a shutdown if u ' hey are not met;within a specified time interval.

Entry into an L.

. OPERATIONAL MODE.or'specified condition may be made-in accordance with 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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/ j COMANCHE PEAK - UNIT 1 / ( 'o-15 REVISION 3 JULY ~20, 1990 9202110144 920204 PDR- ADOCM 05000445 )

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TXX 92050 ATTACHMENT 1 PAGE 3 0F 11' Insert A 3,0.5-Limiting Conditions for Operation including the associated ACTION requirements shall apply to each unit individually unless otherwise indicated as follows:

=a. Whenever ine Limiting Conditions for Operation refers to systems or components which are shared by both units. the action requirements will apply to both units simultaneously, unless specifically noted otherwise, and will be-denoted in the ACTION section of the specification:

b. Whenever the-Limiting Conditions for operation applies to only one

' unit, this will be identified in the APPLICABILITY section of the specification: and

c. Whenever certain portions of a specification contain operating '

parameters.-Setpoints, etc., which are different for each unit, this will be identified in parentheses, footnotes or body of the requirement, j

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E iTXX 92050 3/4- LIMITfNG CONDITf'ONS FOR OPERATf0N aND SURVEfLLANCE REOUTREMENTS LATTACHMENT-13/4.0 APPLICABillTV

'PAGE 4.0F 11 BASES kgeification 3.0.1 throuah 3.0.4 establish the general requirements applicable-to Limiting Conditions for Operation. These requirements are based on the requirements for Limiting Conditions for Operation stated in,-10CFR50.36(c)(2):

" Limiting conditions for operation are the lowest functional capability or performance levels of equipment required for safe operation of the facility. -When a limiting condition for operation of a nuclear reactor is not met, the-licensee shall shut down-the reactor or follow any remedial action permitted by

- the technical specification until the condition-can be met."

Soecification-3.0.1 establishes the Applicability statement within each individual- specification as the requirement for when (i.e., in which OPERATIONAL MODES-or other specified conditions) conformance to the Limiting Conditions for_ Operation is required for safe operation of the facility. The ACTION requi ements establish those remedia measures that must be taken within specified time limits when the requirements of a Limiting Condition for Operation are not met.

There are-two basic types of ACTION requirements. The first specifies the remedial measures that permit continued operation of the facility which-is not further restricted by the time limits of the ACTION requirements. In this case, conformance to the ACTION requirements provide an acceptable level of safety for unlimited continued operation as long as the ACTION requirements continue to be met. The secnnd type of ACTION requirement specifies a time limit in which conformance to the conditions of the Limiting Condition for Operation

must be met. This time limit is the allowable: outage time to restore an inoperable system or component to'0PERABLE status or for restoring parameters within specified limits. If these actions are not completed within 1 ~3 allowable outage time limits, a shutdown is required to place the facility in:a MODE or condition in which the specification nollonger. applies. It is:not intended that the shutdown- i ACTION requirements;be used as an operational' convenience which permits-(routine) voluntary removal of a-system (s) or component (s) from service-in lieu of other alternatives that would not result in redundant systems or components being. inoperable.

The. specified _tiine'. limits of the ACTION _ requirements are appitcable from'the point in. time.it is identified that a Limiting Condition-for Operation is not-met. The time limits of the ACTION requirements are,-

also applicable when a system or component is removed from service- for surveillance--testing or investigation of operational problems.

Individual specifications may--include a specified time limit for the -

completion of-a Surveillance Requirement when equipment is removed from service. In this case,. the allowable outage time limits of the O - i8 COMANCHE PEAK - UNIT I 'l /t OM

1KX40 K0 ATTACHHENT 1 APPllCABILITY PAGL S Of 11 SASES OIS Action requirements are applicable when this limit expires if the surveilla' ice has act been comple ed. When a shutdown is required to comply with ACTION requirements, 1'a plant may have entered a MODE in wnich a new specification becomes ecolicable. In this case, the time limits of the ACTION requirements would apply from the point in time that the new specification becomes applicaule if the requirements of the Limiting Condition for Operation are not met.

s Seecification 3.0.2 establishes that noncompliance with a i

specification existJ when the requirements of the Limiting Condition ^

for Operation are not met and the associated ACTION requirements have not been implemented within the specified time interval. The purpose of this specification is to clarify that (1) implementation of the ACTION requirements within the specified time interval constitutes comr,llanc.e with a specification and (2) completion of the remedial n.casuro of the ACTION requirements is not required when compliance with a Limiting Condition of Operation is *estored within the time interval specified in the associat , ACT): rtquirements.

Soecification 3.0 3, establishes the nutdown ACTION requirements that must be implemented when a Limiting Condition for Operation 14 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 wnich permits (routine) vcluntary removal of redur.Jant systems or components from service in lieu of other alternatives that would not result in redundant systems or components being inoperabie.

One hour is allowed to prepare for an orderly shutdown before initiating a change in plant operation. This time-permits the operr. tor to coordinate the reduction in electrical generation with the load dispatcher to ensure that stability and wailability 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 thtt is well within the specified ma::imum cooldown rate and within the cooldown capabilities of the facility assuming only the minime required equipment is OPERACLE. This reduces th M ' tresses on comNnents of the primary cool:nt system and the potent for a plant upset that could challenge safety systems under conditions for which this specification applies.

1 p-/7 .UN COMANCHE DEAK UNIT 1 13/4 0 -M-

T x x - 920'.>0 ATTACHMENT 1APollCABillTY Pari [ f. 11 pg If remedial measures paraitting limited continued operation of the f acility under the provistor* of the ACTION requirements are completed. the shutdown may .w terminated. The time limits of the ACTION rec *rements are appi aable from the point in time there was a failure 4 :et a Limiting Condition for Operation. Therefore the shutd" u be terminated if the ACTION requirements have been met or the o

.alts of the ACTION requirements have not expired, thus prov. .o9 en allowance for the completion of the required actions.

The tirre limits of Specification 3.0.3 allo.s 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months for the plant to be in the COLD SHUTDOWN MODE when a shutdown is requir&d during the POWER MODE cf 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 opt *ation 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 reu rn to POWER operation, a penalty is not incurred by having to reach lower MODE of operation in less than the total time allowed.

The same principle applies with regard to the allowable outage time limits of the ACTION requirements, if compliance with the ACTION requirements for one specification results in entry into a MODE or condition of operaticn for another specification in which the requirements of the Limiting Condition for Operation are not met. If the new specificaticq becomes applicable in less tf,ve than specified.

the difference may be added to the allowable outage time limits of the second specification. However, the allowable outage time limits of ACTION requirements for a higher MODE of operntion may not be uu.J to extend the allowable outage time that is applierble when a Limitir.g 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 5 and 6, because the ACTION requirements c f individual specifications define the remedial measures to be taken.

Soecification 3.0.4 establishes limitations on MODE changes when a Limiting Condition for Operation is not met. It precludes placing the fac.ility in a higher MODE of operation when the requirements for a l

O -EQ COMANCHE PEAK - UNIT I (f 3/4 0-]1.e_

TXX 920$0 A1TACHMENT APPLICABILITY PAGE 7 Of 11 BASES .

l-O Limiting Condition for Operation are not met and continued noncompliance to these conditions would result in a shutdown to comily with the ACTION requirements if a change in MODES were permitted. The purpose of this specification is to ensure that ficility operation is not initiated or that higher MODES of operation are not entered when corrective action is being taken to obtain compliance with a specification by restoring equipment to OPERABLE status or parameters to specified limits. Compliance with ACTION requirements that permit continued operation of the facility for an unlimited period of time provides an-acceptable level of safety for continued operation without regard to the status of the plant before or after a MODE change.

Therefore, in this case, entry into an OPERATIONAL MODE or other specified condition may be made in accordance with the provisions of the ACTION requirements. The provisions of this specification should not, however. be interpreted as endorsing the failure to exercise good practice in restoring systems or comonents to OPEPABLE status before plant startup.

When a shutdown is required to comply with ACTION requirements, the provisions of Specification 3.0.4 do not apply because they wculd delay placing the facility in a lower MODE of operation.

5 Soecifications 4.0.1 throuch 4.0Mestablish the general requirements applicable to Surveillance Requirements. These requirements are based on the Surveillance Requirements stated in the Code of Federal Regulations, 10 CFR 50.36(c)(3):

" Surveillance requirements are requirements relating to test, calibration, or inspection to assure that the necessary gaality of systems and components is maintained, that facilit/ operation will be within the safety limits, and that the limiting conditions of operation will be met."

Soecification 4.0.1 establishes the requirement that surveillances must be met during the OPERATIONAL MODES or other conditions for which the requirements of the Limiting Conditions for Operation apply unless otherwise stated in an individual Surveillance Requirement.

The purpose of this specification is to ensure that surveillances are performed to verify the operational status of systems and components and that parameters are within specified limits to ensure safe operation of the facility when the plant is in a MODE or other specified condition for which the associated Limiting Conditions for Operation are applicable. Surveillance Requirements do not have to be performed when the facility is in an OPERATIONAL MODE for which the requirements of the associated Limicing Condition for Operation do not b i hJS Gi?.T S t

o-21 COMANCHE PEAK UNIT 1 CB 3/4 OK

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o TXX 92050 i

ATTACHHENT 1 i

PAGC 8 Of 11 Insert B !

SeecificA.ticfL 3.0,5 delineates the applicability of each specification to Unit j 1 and Unit 2 operation.

l The valve identification numbers (tag numbers) contain a unit designator as i the first character, i.e. 105 8455 would be a Unit i valve with 2CS+8455 being the corresponding Uri+ 2 valve. The dual unit Technical Specifications utilire a convention cf identifying valves without the unit designator if the remainder of the tag number is applicable to both units, with the unit designator if the tag-is only applicable to one unit.

When a specification is shared per 3.0.0a, thi ACTION section contains the identifier *(Units 1-and 2)*.

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M WO #PPtIC 8fL!?v AVVACMHCNT 1 gggg PAGE 9 Of 11 apply unless otherwise specified. The Surveillance Requirements associated with a Special Test Exception are only applicable when the Special Test Exception is used as an allowable exception to the requirements of a specification.

SreciNeition a.0.2 establishes the limit for which the specified time interval for Surveillance Requirements may be extended. It permits an allowable extension of the normal surveillance interval to facilitate surveillance scheduling and consideration of plant operating conditions that may not be suitable for conducting the surveillance; e.g., transient conditions or other ongoing surveillance or maintenance activities. It also provides flexibility to accommodate the length of a fuel cycle for surveillances that are performed at each refueling ou. age and are specified with an 18 month surveillance interval. It is not intended that this as a convenience to extend surveillance. provision be usedthat intervals beyond repeatedly specified for surveillances that are not performed during refueling outages. The limitation of Specification 4.0.2 is based on engineering judgement and the recognition that the most probable result of any particular surveillance being performed is the verification of conformance with the Surveillance Requirements. This provision is sufficient to ensure that the reliability ensured through surveillance activities is not significantly degraded beyond that obtained from the specified surveillance interval.

Soncification 4.0.3 establishes the failure to perform a Surveillance Requirement within the allowed surveillance interval, defined by the provisions of Specification 4.0.2, as a condition that constitutes a r failure for to meet the OPERABILITY requirements for a Limiting Contiition Operation.

Under the provisions of this specificatio% systems and components are assumed to be OPERA 8LE when Surveillance Requirements have been satisfactorily performed within the specified time interval. However, nothing in this provision is to be construed as implying that systems or components are OPERABLE when they are found or known to be inoperable although still meeting the Surveillance Requirements. This specification also clarifies that the ACTION requirements are applicable when Surveillance Requirements have

-not been completed within the allowed surveillance interval and that the time limits of the ACTION requirements apply from the point in time it is identified that a surveillance has not been performed and not at the time that the allowed surveillance: interval was exceeded.

Completion of the Surveillance Requirement within the allowable outage ,'

time limits of the ACTION requirements restores compliance with the requirements of Specification 4.0.3. However, this does not negate the fact that the failure to have performed the surveillance within '

the allowed surveillance interval, defined by the provisions of Specification 4.0.2, was a violation of the OPERABILITY requirements of a Limiting Condition for Operation that is subject to enforcement ,

action. Further, the failure to perform a survoillance within the O ~ 2Z COMANCHE PEAK 4 UNIT 1 C8J/4 0.p4- APRIL 17, 1990

i hk y g?pPLICABILITV PAGE10OfthASES provisions of Specification 4.0 I la a .'iolation of a Titchnical Specification requirement and is, therefore, a reportable event under the requirements of 10CFR50.73(a)(?)(1)(B) because it is a cendition prohibited by the plant's Technical Specifications.

If the allowable outage time limits of the ACTION requirements are less than 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or a shutdown is required to comply with ACTION '

requirements, e.g., Specification 3.0.3, a 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months allowance is provided to permit a delay in implementing the ACTION requirements.

This provides an adequate time limit to complete Surveillance Requirements that have not been performed. The purpose of this allowance is to permit the completion of a surveillance before a shutdown is required to comply with ACTION requirements or before other remedial measures would be required that may preclude completion of a surveillance. The basis for this allowance includes consideration for plant conditions, adequate planning, availability of personnel, the time required to perform the surveillance, and the safety significance of the delay in completing the required surveillance. This provision also provides a time limit for the completion of Surveillance Requirements that become applicable as a consequence of MODE changes imposed by ACTION requirements and for completing Surveillance Requirements that are applicable when an exception to the requirements of Specification 4.0.4 is allowed. If a surveillance is not completed within the 24-hour allowance, the time limits of the ACTION requirements are applicable at that time. When a surveillance is performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months 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.

Surveillance Requirements do not have to be performeri on inoperable equipment because the ACTION requirements define the remedial measures that apply. However, the Surveillance Requirements have to be met to demonstrate that inoperable equipment has been restored to OPERABLE status.

Soecification 4.0.4 establishes the requirement that all applicable

, surveillances must be met before entry into an OPERATIONAL MODE or

' other condition of operation specified in the Applicability staterunt.

The purpose of this specification is to ensure that system and i

component OPERABILITY requirements or parameter limits are met before entry into a MODE or condition for which these systems and components ,

ensure safe operation of the facility. This provision applies to-L changes in OPERATIONAL MODES or other specified conditions associated l

with plant shutdown as well as startup.

O -23 COMANCHE PEAK UNIT 1 Q3/4 0P l

1XX 92000 ATTACHMENT4 1 pptIcpg[LITV i: PAGE 11 0F 14 BASES Under the provisions of this specification, the applicable Surveillance Requirements must be performed within the specified surveillance interval to ensure that the Limiting Conditions for Operation are met durirg initial plant startup or following a plant outage.

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

Srecification 4.0.5 establishes the requirement that inservice -

inspection of ASME Code Clau 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 end 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 performing the inservice inspection and testing acti"ities required by Section 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.

Under the terms of this specification. the more restrictive requirements of the-Technical Specification take precedence.over the ASME Boiler and Pressure Vessel Code and applicable Addenda. The requirements of Specification 4.0.4 to perfcrm surveillance' activities before entry into an OPERATIONAL MODE or other specified condition takes precedence over the ASME Boiler and Pressure Vessel Code provision which allows pumps and valves to be tested up to one week after return to normal operation. The Technical Specification-definition of OPERABLE does not allow a grace period before a-component, that is not capable of performing its specified function, is declared inoperable and takes precedence over the ASME Boiler and Pressurs Vessel Code provision which allows a valve to be incapable of performing its specified function for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months before being

-declared inoperable.

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o -z4 COMANCHE PEAK UNIT 1

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i 6 i it TXX+92050 ;

ATTACHMENT 2 :

PAGE 1 01 6 l TECHhlCAl. RE0VIREMEH12- 1.4 Seismic Instruments jlDi PAGE # JUSTiflCATION :

2A 1 16 The seismic instrumentation is a shared system fer ;

'..itts 1 and 2. Add ' Units 1 and 2' after ~

' COMPENSATORY MEASURES *. ,

2B 1 17 Add note to Table 1.4.1 stating that Unit -1 and Unit 2 ,

control room alarms are connected to shared seismic i instruments which are located in Unit 1 and common -

structures. t 20 1 17 Sensor locations are updated to indicate the Unit 1 '

l 18 structure or the common structure.

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fit T pKNICAL RE0VIREPENT IJ M6 SEISMIC INSTRUMENTATION OPERABILITY CRITERIA 1.4 The seismic monitoring instrumentation shown in Tatile 1.4.1 shall

, be OPERABLE.

OPPLICABillTY: At all timer g e ~ ~ - -

02- COMPENSATORYMEASVPES$ A

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a. With one or more of the above required seismic monitoring instruments inoperable for mor: than 30 days, preparo 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 maltunction and the plans for '

l 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 _

TRI.4.1 Each of the above required seismic monitoring instruments shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL CAllBRATION. and ANALOG CHANNEL OPERATIONAL TEST at the frequencies shown in Table 1.1.2.

TRI.4.2 Each of the above required seismic monitoring instruments wu en is accessible during power operations and which is actuateo 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 CAllBRATION performed within 15 days following thS seismic event. Data shall be retrieved from l

actuated instruments and analyzed to determine the l 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 describing the magnitude, frequency spectrum, and resultant effect upon facility features important to i safety.

TRI.4.3 Each of the above seismic monitoring instruments which is actuated during a seismic event greater than or equal to 0.019 but is not accessible during power operation shall be restored to OPERABLE status and a CHANNEL CAllBRATION performed the next time the plant enters MODE 5 or below.

A supplemental report shall then be prepared and submitted to the Commission within 14 days pursuant to CPSES l Technical Specification 6.9.2 describing the additional data from these instruments, t

l COMANCHE PEAK - UNIT 1 1 16 REVISION 3 JULY 20, 1990

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i 1XX 92050 l ATTACHHUJT 2 !

PAGE 3 Of 6 TECHNIC AL RE00BENENT 1.4 (continued)

TABLE 1.4.1 SEISMIC MONITORING INSTRUMENTATIO,$ .W HIN! HUM INSTRUMENTS LMSTRUMENTS AND SENSOR LOCATIONS OPERABLE

1. Triaxial Time

History Accelerographs

a. Acceleromet el- 11 ding 1

- U L

b. Acceleromet ment 1

c. Accelerometer Electrical Manhole l 1

d. Seismic Trigger Fuel Building _

1*g 1

e. Recorder Unit, SHA 3 [dr);T l Cu[ra/ b 1

f. Playback Unit. SMP 1 (Ohl'f 1 Con Tri 1

2. Triaxial Peak Accelerographs v%

a. Pressurizer Lifting Trunion MN" I

b. Reactor Coolant Piping (Qn;ff ConTalnmfni) I

c. CCW Heat Exchanger [/vg;/lar 1

3. Triaxial Seismic Switch Fuel Building 1

4. Triaxial Response Spectrum Recorders

a. .ntl Building 1 Unif "j Bldg. Internal Structure O2C b. 3 fiir" 1

c. , uaros Building 1

5. Response Spectrum Annunciator p . _

p __- _-

1*h

!Y Y 05thef UN >

,hWith control room indication.

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_ COMANCHE P K- N!T 1 1 17 REVISION 1 SEPTEMBER 15,1989

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

i TXX 02050 i AVTACHMENT 2-l PAGE 4 Of 6

!- Insert C

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' Unit 1 and Unit 2 control roem alarms are connected to shared seismic

! instruments which are located in Unit 1 and common structures.

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1XX 92050 ATTACHMENT 2 PAGE 5 0F 6 TECHNICAL REQUlnEMENT 1.4 (continued)

LAELLLid illih1C H QM1QAIXLIX1T R V M E N T A T I O N 5 VAy111LA MCLMQV_llLM EMS ANALOG

CHANNEL CHANNEL CHANNEL OPERATIONAL 1![ilAVMENTS A@ SEN50!L10fAllQX1 CHECK LALIBRATION TEST

1. Triaxial Time History Accelerographs

a. Accelerometer Fuel Building H g $A zc ca;;iTI)

b. Accelerometerit5ht'41n-ment M R SA

c. Accelerometer Ele -

trical Hanhole (% H R SA

d. Seismic Trigger Fuel Building ** H R SA l1 e, rder ~

M R SA

(! mi 1 Central

f. __ La y c t EJt M - _s H R SA 0n2f_ _1 gi Cen7r

2. Triax a 7eak~Acce erog

a. Pressuriz iftin u e Trunion nit f Con $;p p f)N.A. R N.A.

- __ _J

b. Reac _J pi -

N.A. R N.A.

c. CCW H 4 W a -

N.A. R N.A.

091tileW OVE in

3. Triaxial ~ Seismic switch -

Fuel Building ** H R SA

Setpoint verification is not applicable.

- With control room indication.

COMANCHE PEAK UNIT 1 1 18 REVISION 1 SEPTEMBER 15,1989

TXX 92050 ATTACliHENT 2 -

PAGE 6 Of 6 IfCHNICAL REOUIREMENT 1.4 feontinuedl TABLE 1.4.2 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REOUIREMENTS ANALOG

CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS CHECK TEST CALIBRATION

4. Triaxial Response-Spectrum Recorders

a. , fuel Building N.A. R N.A.

uni 53)

O2-C b.,s}actorBldg.

tr cture Internal N.A. R N.A.

c(jaeguardsButiding N.\. R N.A.

5. Response Spectrum Annunciator ** H R SA (Unit 1 Confrol Boond

Setpoint verification is not applicable.

- With control room indication.

C0HANCHE PEAK - UNIT 1 1-19 July 21, 1989

s TXX 92050 ATTACHMENT 3 PAGE 1 Or 23 TECHNICAL REQUIREMENT: 2.1 Containment Isolation valve!

IJ18 PAGE # JUSTIFICATIOR .

3-A 24 Valve identificatteen numbers (tag numbers) contain a !

thru unit designator as the first character, i.e. 105 8455 1 2 24 would be a Unit 1 valve with 20S 6455 being the ;

corresponding Unit 2 volve. The dual unit Technical Specifications will utilite a convention of identifying valves without the unit designator if the remainder of the tag number is applicable to both 4 units, with the unit _ designator if the tag is only applicable to one unit, i

(See revised BASES for 3.0.5).

3 B. 2 13 Inserts Unit 2 valves (Airlock Hydraulic) into table.

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~

2

TXX 920$0 A11ACHMENT 3 PAGE 2 Or 23 TECHNICAL RE0VIREMENT 2.1 TABLE 2.1.1 t CONTAINMENT ISOLATION VALVES MAXIMUM ;

ISOLATION NOTES AND i FSAR TABLE TIME LEAK TEST !

y!_LYf,_.MQ. iSeconds)

REFEREN(L.RQ.* LINE OR SERVICE BLQu!REMENTS l

1. Phase 'A' Isolation Valves AhV 2154 20 Feedwater Sample 5 N.A. !

(FWtoStmGen#1) ,

JHV 2155 22 feedwater Sample 5 N.A. !

(FW to Stm Gen #2)

AhV 2399 27 Blowdown From Steam 5 N.A. [

Generator #3

/HV 2398 28 Blowdown From Steam 5 N.A.

Generator #2 4HV 2397 -29 Blowdown from Steam 5' N.A. I Generator #1 ;

/HV 2400 30 Blowdown from Steam 5 N.A.

Generator #4

/-8152 32 Letdown Line to 10 C Letdown Heat Exchanger I

/8160 32 Letdown Line to 10 .C Letdown Heat Exchanger-

/8890A 35 RHR to Cold Leg 15 C Loops #1 & #2 Test Line

,' ' /889.0B~ 36 RHR to Cold-Leg 15 C Loops #3 & #4

-Test Line'.

/-8047 41- Reactor Makeup -10_ C Watr. 7 to Preasure Relief Tank & RC Pump Stand Pipe -,

,[8843 42 $1 to RC System 10 N.A.

Cold Leg Loops #1, .

l #2, #3, #4 Test Line 1

i COMANCHE PEAX - UNIT 1 July 21. 1989 2-4

.m _ ._ - . . _ _ . . _ _ . . _ . _ _ - _ . . _ . _ _ _ _ . _ . _ . _ _ . _ . . , . _ . _ _ _ .

TXX 92050 ATTACHMENT 3 PAGL 3 Of 23 TECHNICAL REQUIREMENT 2.1 (continued)

IAplE 2.1.1 (Continutd1

(&NTA11 MENT ISOLAtl0N VALVES HAXIMUH ISOLATION NOTES AND FSAR TABLE TlHE LEAK TEST LA ky L S Q. REFERENCE N(L* LINE OR SERVICE 11econdsl plQ21RLMJ,311

1. Phase "A" Isolation Valves (Continued) 3.A f B881 43 51 to RC System 10 N.A.

Hot Loops #2 & l2

3 Test Line f 8024 44 Si to RC System 10 N.A.

Hot Leg loops #1 & l2

4 Test Line g 8823 45 SI to RC System 10 N.A.

Cold leg loops fl. l2

2, #3 & #4 Test Line

/ 8100 $1 Seal Water Return 10 C and Excess Letdown

/ 8112 51 Seal Water Return 10 C and Excess Letdown

(

)

l

/7136 52 RCDT Heat Exchanger 1C C to Waste Hold Up Tank LCV 1003 52 RCDT Heat Exchanger 10 C to Waste Hold Up Tank

/}iV 5365 60 Demineralized Water 5 C Supply

[ ./HV5366 60 Demineralized Water 5 C Supply

/HV5157 61 Containment Sump 5 C Pump Discharge

/HV-5158 61 Containment 5 C

, Sump Pump 1

l /HV3487 62 Instrument Air 5 C to Containment C0HANCHE PEAK UNIT 1 25 REVISION 2 JANUARY 15, 1990

- . . -w

TXX 92050 .

ATTACHMENT 3 ,- -

PAGE 4 0F 23 TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE 2.1.1 (Continued)

CONTAINMENT 15ptAT10N VALV[1 )

MAXIMUM ISOLATION NOTES AND J FSAR TABLE TIME LEAK TEST VALVE NO, .

REFERENCE NO.* LINE OR SERVICE ISeconds) RE0VIREMENTS l

1. Phase "A" Isolation Valves (Continued) r 8825 034 63 RHR to Hot Leg Loops

2 & #3 Test Line 15 C sfHV-2405 73 Sample from Steam '

5 N.A.

Generator #1

-(kV 4170 74 RC Sample From 5 C Hot Legs

-AhV 4168 74 RC Sample From 5 C Hot Leg #1

,2kV-4169 74 RC Sample from 5 C Hot leg #4

,ThV 2406 76 Sample from Steam 5 N.A.

l Generator #2 l

s(HV 4167 77 Pressurizer Liquid 5 C

Space Sample

,fHV 4166 77 Pressurizer Liquid 5 C ,

Space Sample j(HV 4176 78 Pressurizer Steam 5 C +

Space Sample

,tkV 4165 78 Pressurizor Steam 5 C Space Sample

,thV-2407 79 Sample From Steam 5 N.A.

Generator #3 i ,tWV+4175 80 Accumulators 1

5 C I /NV4171 80 Sample From 5- C Accumulator #1 1

l l

C0KANCHE PEAX - UNIT 1 26 July 21, 1989

__,J.

1XX 92050 ATTACHMENT 3 FAGE 5 0F 23 TECHNICAL RE0VIREMENT 2.1 (continued)

IABLE 2.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAX 1 HUM ISOLATION NOTES AND !

FSAR TABLE TlHE LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) RE0VIREMENTS

1. Phase "A" Isolation Valves (Continued) 3- JHV 4172 80 Sample From 5 C Accumulator #2 41V-4173 80 Sample From 5 C Accumulator #3 JHV 4174 80 Sample From 5 C Accumulator #4 4HV-7311 81 RC PASS Sample 5 C Discharge to RCDT A V-7312 81 RC PASS Sample 5 C Discharge to RCDT

,MiV-2408 82 Sample from Steam 5 N.A.

Generator #4 y 8871 83 Acce~ulator Test 10 C and fill J 8888 83 Accumulator Test 10 C and Fill

/-8964 83 Accumulator Test 10 C and Fill JHV-5556 84 Containment Air 3 C PASS Return 4HV 5557 84 Containment Air 5 C PASS Return 4HV-5544 94 Radiation 5 C Monitoring Sample

,41V-5545 94 Radiation 5 C Monitoring Sample JHV-5558 97 Containment Air 5 C PASS Inlet COMANCHE PEAK - UNIT 1 27 July 21, 198il

TXX 92050 !'

ATTACHHENT 3 ~

PAGE 6 0F 23 TECHNICAL RE0VIREMENT 2 1-(continued) i TABLE 2.1.1 (Contingg t ,

CONTAINMENT ISOLATION VALVH f

MAXIMUM

!$0LAT!0N NOTES AND t FSAR TABLE TIME LEAK TEST VALVE NQ, REFERENCE NO.* LUile:tSERVICE iSeconds) RE0UIREMENTS i i

1. Phase "A" Isolation Valves (Continued) 97 Containment Air O3AJ14V5559_ PASS Inlet 5 C '

JiV 5560 100 Containment Air 5 C l PASS Inlet

MV5561' 100 Containment Air 5 C i PASS Inlet '

MV5546 102 Radiation Monitor- 5 C i ing Sample Return

/HV-5547 102 Radiation Monitor- 5 C ing Sample Return

/8880 104 N2 Supply to 10 C Accumulators

/ 7126 105 H2 Supply to 10 C RC Drain Tank

7150 105 H2 Supply to 10 C RC Orain Tank AiV 4710 111 CCW Supply to 5 N.A.

Excess Letdown

& RC Drain Tank Heat Exchanger L /HV 4711 112 CCW Return From 5 N.A.

Excen Letdowr t RC Orain Tank Feat Etchanger-JHV 3486- 113 Service Air 5 C to Containment COMANCHE PEAK UNIT 1 2-8 July 21 1989-

. a . 2. -- , . _ . . _ _ . _ . .. , , _ _ _ . _ - -

TXX 92050 ATTACHHEt4T 3 PAGE 7 0F 23 TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE _2.1.1 (Continuell ,

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND ESAR TABLE TIME LEAK TEST VALVE NO. REFERENCE il0.* LINE OR SERVICE f$econds.1 RE0VIREMENTS

1. Phase "A" Isolation Valves (Continued) l

.niV 4725 03A 114 Containment CCW Orain Tank Pumps 5 C i

Discharge 4HV-4726- 114 Containment CCW 5 C Drain Tank Pumps Discharge ;

1 J 8027 116 Nitrogen Supply 10 C to PRT

. # 8026 116 Nitrogen Supply 10 C to PRT AIV 6084 120 Chilled Water 10 C Supply to Contain-ment Coolers '

AiV 6082 121 Chilled Water 10 C Return from '

Containment Coolers AV 6083 121 Chilled Water 10 C Return From Containment Coolers hiV 40758 124 Fire Protection 10 C System Isolatior, A V-4075C. 124 Fire Protection 10 C System Isolation 2, Phase "B" Isolation Valves t

AV-4708 - 117 CCW Return-From 15 C g.

RCP'S Motors i

AV-4701 117 CCW Return From 15 C RCP's Motors-AV-4700- 118 CCW Supply to 15 C_ ,

RCP's Motors-COMANCHE PEAK - UNIT 1 2-9 July 21,=1989 o

l W-*- w v y s q- ,. ,py'q c wrg,w-s ys yy--+ye y'N v-9-r-%y+-vpwr-vg.-'-Py-- rp-w-wm -'-ip'--- w e p-v'- g-mi--'#'M.'ey-w* r em g7 'tm - 9 MIMT'

TXX 92050 A11ACHMENT 3 PAGC 8 Of 23 TECHNICAL RE0VIREMENT 2.1 (continued)

IABLE 2.1.1 (Continuedl CONTAINMENT ISOLATION VALVE $

MAXIMUM ISOLATION NOTES AND FSAR TABLE TlHE LEAK TEST VALVE NO. frFERENCE PiQ.* LINE OR SERVICE iSeconds) RE0VIREMENTS

2. Phase "B" Isolation (continued) 119 CCW Return from O3.A /HV 4709 RCP's Thermal 15 C Barrier fiV4696 119 CCW Return From 15 C RCP's Thermal Barrier

3. Containment Ventilation isolation Valves

,diV5542 58 Hydrogen Purge N.A. C Supply

/HV5543 58 Hydrogen Purge N.A. C Supply

/HV5563 58 Hydrogen Purge N.A. C Supply fiV5540 59 Hydrogen Purge N.A. C Exhaust

/riV5541 59 Hydrogen Puro9 N.A. C Exhaurt JhV-5562 59 Hydrogen Purge N.A. C Exhaust i 5536 JiV 109 Containment Purge 5 C Air-Supply l

JhV-5537 109 Containment Purge 5 C Air Supply J11V5538 110 Containment Purge 5 C Air Exhaust

/HV5539 110 Containment Purge 5' C Air Exhaust 1

COMANCHE PEAK - UNIT 1 2-10 July 21, 1989

TXX 92050 Al1 ACliHLHT 3 -

PAGE 9 0F 23 TECHNICAL REOUIPEMENT 2.1 (continued)

TABLE 2.1.1 (Contingd '

CONTAINMENT ISOLATION VALVES I

MAXIMUM ISOLAT!0ft NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NQ.* LINE OR SERVICE ISeconds) RE0VIREMENTS

3. Containment Ventilation Isolation Valves (Continued) 03A JhV5548 122 Containment Pressure Relief 3 C JiiV 5549 122 Containment Pressure 3 C Relief

4. Manual Valves j l

JhS 711# 4a TOAFW Pump Bypass N.A. N.A.

Warm up Valve

/MS 390 Sa N2 Supply to Steam N.A. N.A.

Generator #1

/MS-387 9a N2 Supply to Steam N.A. N.A.

Generator #2 JhS384 13a N2 Supply to Steam N.A. N.A.

Generator #3

/MS712# 17a TOAFW Pump Bypass N.A. N.A.

Warm up Valve JhS-393 18a N2 Supply to Steam N.A. N.A.

Generator #4 ffW106 20b N2 Supply to Steam N.A. N.A.

Generator #1

/FW104 22b N2 Supply to Steam N.A. N.A.

Generator #2 J'FW102 24b N2 Supply to Steam N.A. N.A.

Generator #3

/FW108 26b N2 Supply to Steam N.A. N.A.

Generator #4 J'-71358 52- RCOT Heat Exchanger N.A. C to Waste Holdup Tank COMANCHE PEAK UNIT 1 2-11 July 21, 1989 L

TXX*92050 VECHNICAL RE0VIREMENT 2,1 fcontinued)

ATTACHMENT 3 PAGE 10 0F 23 TABLE 2.1.1 (continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE ISeconds) RE0VIREMfull

4. Manual Valves (Continued) 03-A /SF Oll 56 Refueling Water Purification to N.A. C Refueling Cavity

/SF012 56 Refueling Water N.A. C Purification to Refueling Cavity

/SF021 67 Refueling Cavity N.A. C to Refueling Water Purification Pump

/SF022 67 Refueling Cavity N.A. C to Refueling Water Purification Pump

/SF053 71 Refueling Cavity N.A. C Skimmer Pump Discharge

/SF054 71 Refueling Cavity N.A. C Skimmer Pump Discharge

/SI8961# 83 Accumulator Test N.A. N.A. 3 and Fill 3 MV-2333Bf 2 MSIV Bypass from N.A. Note 1 Steam Generator #1

/HV2334B# 7 MSIV Bypass from N.A. Note 1 Steam Generator #2 l

[V-2335B# 11 MSIV Bypass from N.A. Note 1 Steam Generator #3

/HV2336B# 15 MSly Bypass from N.A. Note 1 Steam Generator #4 t-COMANCHE PEAK - UNIT 1 2-12 REVISION 3 JULY 20, 1990

TXX 92050 ATTACilHENT 3 TECWNICAL BE00fDEWEN7 2.1 (cent uued)

PAGE 11 Or 23 TABLE 2._L1 (centinued}

(CNTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME VALVE NO. DEFEDENCE NO.* LEAK TEST LINE OD SEDV10E f!ecordsl CEOUfoEutNTS 4, wanual valves (Continued) 185-0016# 130 Airlock Hydraulic N.A. N.A, 6 System 6l 1BS 0017f 130 Airlock Hydraulic N.A. N.A. 6 System '

6 3*A S 0030# 131 Airlock N.A. Notes 6 Hydraulically 5,6,7 6 Operated Equalization 6

fS-0025# 131 Airlock N.A. Notes 6 Hydraulically 5, 6, 7 6 Operated Equalization 6

S-0056# 131a Airlock Manual N.A. Notes 6 Equalization 5, 6 6 hBS-0044# 131a Airlock Manual N.A. Notes 6 Equalization 5, 6 6

[B5-0029# 131a Airlock Manual- N.A. Notes 6 Equalization 5, 6 6 fS-0015# 131a Airlock Manual N.A. Notes 6-Equalization 5, 6 6 hS0202# 132 Airlock Manual N.A. Notes 6 Equalization 5,6,7 6 hS-0203# 132 Airlock Manual N.A. Notes 6 Equalization 5 -6, 7 6

[ N.SCA T* O COMANCHE PEAK - UNIT 1 2-13 Revision 6 Novee er 22, 1991-

TXX 92050 l

ATTACifMENT 3 PAGE 12 Of 23 i a

insert 0 !

i 7

.$ Unit 2 Airlock Hydraulic System Yalves f

i

+

f I

?

t 4

t i

b 3

f 1

o ,

b l

TXX 92050 AllADIMllil 3 EEHNIESL PAGE 13 Of 23 EOUI EMENT 2.1 (continued TaELE 2.1.1 (centinuedl CENTAINWENT ISOLATIEN VALVES MAXIMUM ISCLAilCN NOTES AND FSAR TABLE TlWE stvE N? ErE EscE wo,* WEAK IEST L:NE CD SEDVICL L$ectnes) :E M::EWENTS

5. Pe.er-Crerateo Isolation valves 3-A @v-2452-1 4 "ain Steam to Au"- N.A. N.A.

FPT From Steam Line #1 b']pV-2325 5 Atmscheric Relief Steam Generator N.A. Note 3 '

l3 pV-2326 9 Atmospheric Relief N.A. Note 3 Steam Generator {3

[PV-2327 13 Atmspheric Relief N.A. Note 3 3 Steam Generator jfV-2452-2 17 Main Steam to Aux. N.A. N.A.

FPT From Steam Line Q[PV-2328 18 Atmospheric Relief N.A. Note 3 l3 Steam Generator HV-2491A 20a Auxiliary Feedwater N.A. N.A.

to Steam Generator il fV-2491B 20a Auxiliary Feedwater N.A. N.A, to Steam Generator il

((fiV-2492A 22a Auxiliary Feedwater N.A. N.A.

to Steam Generator I2

[HV-24928 22a Auxiliary Feedwater N.A. N.A.

to Steam Generator 92 f(IiV-2493A

~ 24a Auxiliary Feedwater N.A. N.A.

to Steam Generator

3 f/HV-2493B 244 Auxiliary feedwater N.A.

/ N.A.

to Steam Generator

3

)

COMANCHE PEAK - UNIT 1 2-14 November 22, 1991

l A iH NT 3 PAGE 14 0F 23 ?ECWWICAL DEOUIREWE37 2.1 (centinued)

TABLE 2.1.1 (centinued) l CONTAINutyi ISOLATION VALVES i

NAX1 MUM ISOLAT!ON NOTES AND FSAR TABLE yatvE NO. TIME LEAK TEST DEFEDENCE NO.* LINE 00 $EDVitE 1 f$eceres) DE00!DEuENTS

5. Power-Operated Isolation valves (Continued)

(

3 %V-2494A 26a Auxiliary Feedwater N.A. N.A.

to Steam Generator f4

%V24948 26a Auxiliary Feedwater N.A. N.A.

to Steam Generator

4

[8701B 33 RHR From Hot Leg N,A. C Loop #4

%8701A 34 RHR From Hot leg N.A. C Loop #1

[8809A 35 RHR to Cold leg N.A. Note 4 Loops #1 and #2 2

[B8098 36 RHR to Cold Leg N.A. Note 4 2 Loops #3 and #4

[8801A 42 Safety injection N.A. N.A.

to Cold Leg Loops

1, #2, #3, and-#4 h88018 42 Safety Injection N.A. N.A.

to Cold Leg Loops

1, #2, #3, and #4 f8802A 43 SI Injection to N.A. N.A.

RCS Hot Leg Loops

2 and #3

[88028 44 $! Injection to N.A. N.A.

RCS Hot Leg loops

1 and #4 -

[8835 45~ SI Injection to -

- N.A. N.A.

RCS Cold leg Loops

1, #2, H , and #4 -

4 COMANCHE PEAK - UNIT 1 2-15 g;g ynyLjgns _ _ . -

I I

TXX 92050 ATTACHMENT 3 PAGE 15 0F 23 TECHNICAL DEOUIDEWENT 2.1 (centinued)

HBLE 2.1.1 (centinued) !

CCNTAINWENT ISOL ATION VALVES MAXIMUM i ISOLATION NOTES AND i FSAR TABLE valve NO. :ErtcrNCE wo,e TIME LEAK TEST tlyt eq stoVICE fSecenes) D.(OUIQEwCWit . _

5. Power-Operated Isolation Valves (Continuev) i 3*A h-8351A 47 Seal Injection to N.A. N.A.

RC Pump (Loop #1)

[83518 48 Seal Injection to N.A. N.A.

RC Pump (Loop #2) h8351C 49 Seal Injection to N.A. N A.

RC Pump (Loop #3)

[83510 50 Seal Injection to N.A. N.A.

RC Pump (Loop f4) hV-4777 54 Containment spray N.A. Note'4 2 to Spray Header (Train 8) fV-4776 55 Containment Spray N.A. Note 1 2 to Spray Header (Train ~A) 63

[-8840. RHR to Hot Leg Loops #2 and #3 N.A. Note 4 2

[8811A 125 Containment N.A. N.A.

l Recire. Sump to RHR Pum '

(Train A) ps

%88118 126 Containment N.A. N.A.

Recire. Sump

! to RHR Pumps (Train 8) fV-4782 127 Containment N.A. N.A.

Recire, to Spray Pumps (TrainA) l fV4783- 128 Containment N.A. N.A.

! Recirc. to Spray Pumps (Train 8)

COMANCHE PEAK - UNIT 1 2-16 1

AT [E 4T 3 0 2. (con nued PAGE Js 0F 23 TABLE 2.1.1 (continuedl CCNTAINWENT ISOLATION VALVES

} i:

MAXIMUM

FSAR TABLC ISOLATION NOTES AND TIME LEAK TEST VALVE NO. D UEDENCE NO.*

LINE CA SEDVICE fSecones) DEOUl#EuENTS

[ 6. Check enives

[';- # $316; 35 RHR t Loia Leg N.A. N.A.

.gf VfG p> BBit; , 35 RHR to Cold leg N.A. N.A. .

Loop #2

%8818C 36 RHR to Cold Le;) N.A. N.A.

Loop #3 1 1

fB8180 36 RHR to Cold Leg N.A. N.A.

Loop #4

,79046 41 F Reactor Makeup H.A. C Water to Pressu-rizer Relief Tank and RC Pump Stand Pipe f1815 42 High Head Safety H.A. N.A.

Injection to Cold Leg Loops #1, 52,

3, and #4 f!-8905B 43 SI to RC System N.A. N A.

Hot Leg Loop #2 pl-8905C 43 SI to RC Systef, .4 N.A.

Hot Leg loop fi 44 SI to RC System fil-8905A N.A. N.A, =

Hot Leg Loop fl l

I-890SD 44 SI to RC System H.A. N.A.

Hot Leg Loop #4 f!-8819A 45 SI to RC Systetil N.A. N.A.

Cold Leg Loop #1 i

CDMANuiE PEAX - UNIT 1 ?-17

{

____ November 22, 199 E

_ _ __ w

-i TXX 92050 i

- ATTACHMENTi3 TECHNICAL RECUIREMENT 2.1 (conU nued)

PAGE-17 0F 23 TABLE 2.1.1 (centinued)

(DNTAINMENT_ ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST valve N A DEFEPENCE NO.*- LINE OR SERVICE (Seconds) DEOUIDEMENTS

6. Check Valves (Continued) 3-A (hl-88198 45 S! to RC System N.A. N.A.

Cold Leg Loop #2 p!-8819C 45 Si to RC System N.A. N.A.

Cold Leg Loop #3

/SI-88190 45 SI to RC System N.A. N.A.

Cold Leg loop #4 f8381 46 Charging Line to N.A. C Regenerative Heat Exchanger fS-8368A 47 Seal Injection to N.A. N.A.

RC Pump (Loop #1) 5-83688 48 Seal Injection to N.A. N.A.

RC Pump (Loop f2) fS-8368C 49 Seal Injection-to N.A. N.A.

RC Pump (Loop #3) p'CS-836BD 50 Seal Injection to N.A. N.A.

RC Pump (Loop #4)

[CS-8180 51 Seal Water Return N.A. C and Excess Letdown T * .a 54 Containment Spray N.A. N u'. a 4 2 to-Spray Header Ic (Tr. 8) 7 a

i

-COMANCHE PEAK -. UNIT 1 2-18

\^

November 22, 1991

TXX-92050-

-ATTACHMENT 3- TEtyNicat DE001REMENT 2.1 (centinued)

PAGE-;18 OF 23_

TagtE 2,-1,1.(continuedl-CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND-FSAR TABLE TIME-VALVE NO, REFEDENCE NO.* LEAK TEST LINE OR SERVICE (Seconds' #EOUIDEMENTS

6. Check Valves (Continued) 3A p/.T-142 55 Containment Sprr.y N.A. Note 4 - 2 to Spray Heldei*

(Tr. A) i (ICI-030 62 Instrument Aia r-- N.A. C- 1 to Containment

'[~-8841A 63 RHR to Hot Leg Loop #2 W . ,*

N.A.

f-8841B; 63 RHR to Hot Leg N.A.

Loop #3 N.A.

fSI-8968- 104 Ng Supply to N . A'. C Accumulators fA-016- 113 Service Air to N.A. C Cantainment fC-629. 117 CC Return From N.A. C -

RCP's Motors fCC-713 118 -CC Supply to RCP's N.A. C Motors C-831 119 CC lleturn From N.A. C RCP's Thermal '

Barrier H-024- 120 Chilled Water N.A. C Supply to Contain-

-ment-Coolers l h ,-

COMANCHE PEAK - UNIT 1 2-19

-a = - - - - , ' - - - - - - ' ~ ~ ~ -

I I

TXX 92050-- l ATTACilMENT 3 I

?ECHNICAL CEOUIREWENT 2.1 (continveci lPAGE 19 0F 23 i TABLE 2.1.1 (continuec)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE- TIME VALVE NO. REFEDENCE NO.* LEAK TEST LINE CD SEUVICE (Seconds) PEOUIDEMENTS .

7. Steam Line Isolation Signal 3.A f' V-2333A 1 Main Steam From 5 Note 2 & 3 Steam Genarator #1 f;V-2409 3 Orain From Main -5 N,A, Steam Line #1 6

fV-2334A- Main Steam From 5 Note 2 & 3 Steam Generator #2 8 Drain From Main fHV-2410 5 N.A.

Steam Line #2 10 fV-2335A Main Steam from 5 Note 2 & 3 Steam Generator #3

~fV-2411 -12 Orain From Main 5 .4, A ,

Steam Line #3 ff V-2336A 14 Main Steam From Steam Generator #4 5 Note 2 & 3 i 16 fV-2412 Orain From Main 5 N.A, Steam Line f4 J

COMANCHE PEAK - UNIT 1 2-20

. MSvembGr 22. 1991 .

.TXX 92050 ATTACHMENT 3 TECHNICAL DEOUIDEWENT 2.1 (continued)

PAGE 20 0F 23 TABLE 2.1.1 (centinued)

CONTAINNENT ISOL ATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST v LVE NO. DEFEDENCE NO

LINE OR SEDVICE [$econds) DEOUIREuENTS B. Feedwater Line Isolation Signal 3-A fV-2134 19 Feedwater to 5 Note 3 Steam Generator #1 pV-2193 20c Feedwater Preheat 5 Note 3 Bypass Line S.G. #1 20d fV-2185 Feedwater Bypass 5 Note 3 Line S.G. #1 fV-2135 21 Feedwater to 5 Note 3 Steam Generator #2 V-2194 22c

-/ - Feedwater Preheat 5 Note 3 Bypass Line S.G. #2 fV-2186 22d Feedwater Bypass b Note 3 Line S.G. #2 fV-2136 23 Feedwater to 5 Note 3 R

Steam Generator #3

/ftV-2195 24c Feedwater Preheat 7 5 Note 3 Bypass Line S.G. #3 fV-2187_ 24d Feedwater Bypass 5 Note 3 Line S.G. f3 fV-2137 25 Feedwater to 5 Note 3 Steam Generator #4 L

l fV-2196 26c Feedwater Preheat 5 Note 3 Bypass Line S.G. #4 fV-2188 26d Feedwater Bypass 5 Note 3 Line S.G. f4 L

COMANCHE PEAK - UNIT 1 2-21

TXX-92050 ATTACHMENT 3 E HNICAL REOUl#EWENT 2.1 (continued)

-PAGE:21 Of 23 TABLE 2.1.c fcenti'ved)

($4TAINMENT ISQLATION VALVES MAXIMUM '

ISOLATION NOTES AND FSAR TABLE TIME valve NO. DEFERENCE NO.* LEAK TEST LINE CR SERVICE (Secondtl CEOUIREMENTS

9. Safety Injection Actuation Isolation 3A $8105 46 Cnarging tin. to e to Regenerative .

Heat Exchanger I l

10. Relief Valves 33 f-87088 t

RHR From Hot N.A. C l Leg loop #4 3 34 h-8708A RHR From Hot N.A. C Leg Loop #1 i Sb fMS-021' Main Steam Safety N.A. Note 3 Valve S.G. #1-Sb fS-022- Main Steam. Safety Valve S.G. #1 N.A. Note 3 Sb l fMS-023 Main Steam Safety N.A. Note 3 Valve S.G. #1 fS-024 Sb Main Steam Safety N.A. Note 3 Valve S.G. #1 pS-025 Sb Main Steam Safety N.A. Note 3 Valve S.G. #1 pS-058 9b Main Steam Safety N.A. Note 3 1

Valve S.G. #2 9b fS-059 Main Steam Safety Valve S.G. #2 N.A. Note 3

[h45-060 9b Main Steam Safety N.A. Note 3

/

Valve S.G. #2 l-l i-COMANCHE PEAK - UNIT 1 2-22 November 221 1991

-TXX-92050 ATTACHMENT-3 TECHNICAL BEOUIREMENT 2.1 (continued)

PAGE 22 OF 23 TABLE 2.1'1 (continued)

CCNTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME VALVE NO. REFEDENCE ND.*

LEAK TEST LINE OR SERVICE [5E qngil CEOUIDEMENTS

10. Relief Valvet (Continued) 3-A $5-061 9b Main Steam Safety N.A. Nr.te 3 Valve S.G. #2 -,

pfS-062 9b Main Steam Safety N.A. Note 3 4 Valve S.G. #2 pS-093 13b Main Steam Safety N.A. Note 3 Valve S.G. #3 (IMS-094 13b Main Steam Safety N.A. Note 3 Valve S.G. #3 hS-095 13b Main Steam !sfety h.A. Note 3 Valve S.G. ;5

/MS-05c 13b Main Steam Safety N.A. Note 3 Valve S.G. #3 I

JMS-097 13b Main Steam Safetv N.A. Note 3 Valve S.G. #3

[MS-129 1Bb Main Steam Safety N.A. Note 3 Valve S.G. #4 fS-130 ISb Main Steam Safety L N.A. Note 3 t Valve S.G. #4 >

[NS-131 1Bb Hain Steam Safety N.A. Note 3 i Valve S.G. #4 fS-132 1Bb Main Steam Safety N.A. Notn 3 i Valve S.G. #4 l t MS-133 18b Main Steam Safety N.A. Noti 3~

Valve S.G. #4 i l

(

L 1 L

1 l

1 COMANCHE PEAK - UNIT 1 2-23 i

November 22cL1991' 1

TXX 92050 ATTACHMENT 3 PAGE 23 0F 23 TECHNICAL DEQUIDEMENT 2.1 (centinisedl TABLE 2.1.1 (continued _1 CONTAINWENT ISOLATION VALVES MAXIMUM ,

ISOLATION NOTES AND FSAR TABLE VALVE NO. TIME LEAK TEST DEFERENCE NO.* LlhL CQ SERVICE fSecondsl :EOUIDEVENTS 10,-Relief Valves (Continued) 3-AJRC-036 dia Penetration Trer- N.A.

C mal Relief hP-7176 52a Penetration Ther- N.A. C mal Relief i

60a f00-430 Penetration Ther- N.A. C mal Relief p0-907 61a Penetration Ther- N.A. C

, mal Relief JDPS-503 74a Penetration Ther- N.A. C mal Relief

.%PS-501 77a Penetration Ther- N.A, C mal Relief hPS-502 78a Penetration'Ther- N.A. C mal Relief

'/PS-500 80a Penetration Ther- N.A. C mal Relief-pP-7177 81a Penetration Ther- NA. C mal Relief fSI-8972 83a Penetration Ther-l- N.A. C L mal Relief CC-1C57 Il4a Penetration Ther- N.A. C mal Relief JCH-271- 120a Penetration Ther- N.A. C mal R(lief

'fH-272 121a Penetration Ther- N.A. C mal Relief s COMANCHE PEAK - UNIT 1-- 2-24 L

N',n~~Yr238LJfG

._. -_ .-- . . r..._.____-._._.. _m _ - . _ -. . _ - _ . . . _

-TXX 92050

-ATTACHMENT 4 pAGE 1 0F.3 TECHNICAL REQUIREMENT: 3.3 feedwater Isolation Valve Temperature

'11LB -PAGE #. JUSTiflCATION A 3 12 Instrument identification numbers (tag numbers' contain a unit designator as-the first character, i.e.

1-TI-21C2-1 would be a Unit 1 instrLment with 2-TI-2152 1 being the corresponding Unit 2 instrument.

The dual unit Technical Specifications will utilize a convention of identifying instruments without the unit designator if the remainder of the tag rumber is applicable to both units, with the unit des'gnator if

' the tag is only applicable to one unit.

L (See revised BASES for 3.0.5),

4B 3-13 Valve identification numbers (tag numbers) contain a

-unit designator as the first character, i.e. 105 8455

- would be a " Unit I valve with 2CS-8455 being the

= corresponding Unit 2 valve, The dual unit Technical

- Specifications will utilize a convention-of identifying valves without the unit designator if the

- remainder of the tag number is applicable to both units, with the unit designator if thel tag is only applicable to one unit.

(See revised BASES for-3.0.5).

p y

l _.

n l.

4

. ._- . m.. ., - , .w, . . , , ~ - . - - - ,

TXX 92050 G 3 TECHNICAL RE0VIREMENL1 J ffED'JATER ISOLATION VALVE TEMPERATURE QfERABILITY CRITER!A 3.3 Each main feedwater isolation valve shall be greater than or 3 eqi:al to 904, when feedwater line pressure is greater than 675 psig. 3 APPlICABILIT): MODES 1*, 2, 3 and during pressure testing of the 3 steam generator or main feedwater line, COMPENSATORY MEASURES:

With one or more main feedwater isolation valves outside of the above 3 limits:

e. Restore main feecNater isolation valve pressure and/or 3 temperature to within the limits within 30 minutes, and

b. Perform an engineering evaluation to determine the cffect of 3 the overpressure on the structural integrity of the main feedwater isolation valve (r) and determine that the main feedwater isolation valve (s) remains acceptable for continued operations within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Complete this determination each time this compensatory measure is entered.

l

c. Otherwise, be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in 3 HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

l TESTS /INSPETIONS TR3.3 Each main feedwater isolation valve shall be determined 3 to be greater than or equal to 900F at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months *. 3

~R eadings shall be taken usin he following instruments: Q3TI-2152-1, hA TI-2152-2, TI-2162-3 and TI-2152 4. If any of these instruments re inoperab@le, a surface eter pyr may be used to determine valve

temperature, 1

i

Except in MODE 1 with the feedwater isolation valve open, 3 temperature readings are not required. 3 COMANCHE PEAK - UNIT 1 3-12 REVISION 3 JU:.Y 20, 1990

- .- - - - -- - _ . - . . _ _ . - - . . . - . - .~ ~

i i

IXX 92050:

ATTACHMENT 4 I

~ ~

TECHNICAL REQUIREMENT 3.3 (Continued)

SASES' 3 FEEDWATER ISOLATION VALVE TEMPERATURE

. f Supplemental impact testing performad on portions of representative ,

samples of the-valve body.. neck and bonnet of the feedwater isolation valves (FIV'st yielded.results which were not in accordance with the -

ASME code requirements for fracture toughness'for material (NC-23001 based on a minimum service temperature of 400F. .The results or the supplemental testing _ are discussed in Engineering Report E_R DBE ME-

-045. In addition-a fracture mechanics analysis is detailed in _.

Calculation le345 ME(B) 274 R/1 "Re istance.of-Feedwater. Valves to Brittle Fracture".

As indicated in_the engineering report, the fracture toughness

. requirements are satisfied with a metal temperature of 900F for the valve body and neck, therefore, these portions will be maintained a'we:this- temperature prior to full pressurization of the valves.

-T M valve bonnet fracture toughness has been demonstrated by the f'acture analysis; calculation-in conjunction with a Volumetric Non-D structive Exam?which determined that there are no significent m.terial flaws-which could lead to fracture propagation.

is-a result of the conclusions drawn in Engineering Report ER*DBE ME -

04 i is;necessary that minimum temperature limitations be imposed N upo?. dr Nedwater Isolation Valves IHV-1134 2135. -2136 and *2137. As L \ stated-in DBE-ME-203 Section 4.3.7_" Operator interface requirements",

j the feedwater isolation vsives must be veriffed to be above 900F p*ior~to entering MODE 3 RCS T avg 1 3500F. This corresponds to a prtssurizati_on_at the_ valve of approximately 140 150 psig. The maxiaum' pressurization during enid conditions (valve temperature

< 900F) should be limited to no more than 20% of the valve-

. hydrostatic test pressure-(3375 psig x 20% --675 psig) which exceeds-L the condensate pump dead head discharge pressure (Ref.-ER-DBE-ME 045).- '

During plant' start up. fit is possible to cold pressurize the valves from the condensate pumps / feed pumps or from back pressurization-from the Steam Generators. Imposing the MODE 3 limitation will prevent the l

lack pressurization from the generators.

' Cold pressurization from the condensate pumps is normally prevented due to the manual isolation valves upstream of each FIV being closed anytime the feedwater headers are pressurized during lung cycle L condensate full flow flushing ope' ration or condensate pump minimum

[ fiow operation.

l

. Steam' turbine driven feed pumps arc startt.d durihg-HODE 2 when sufficient steam is available for pump operation. Pressurization-of the FIV.from'the Main Feed Pumps will therefore-occur only after .

MODE 3 with the metal temperature of the FIV's being at or above 900F.

COMANCHE. PEAK - UNIT 1 3-13 Revision E vanuary 15, 1990.

lz

~ + . - _ . - - . . .- - - - - . - _ . - -

TXX 92050

- ATTACHMENT 5 PAGE 1 0FJ27-

- TECHNICAL REQUIREMENT: -4;1 Containment Penetration Conductor Overcurrent Protection Devices 1118 PAGE e JUSTIFICATION 5-A 45 Updates Table 4.1.1 by separating Unit I devices into thru Table 4.1.la.

4-17 5B 4-18 Updates Table'4.1.1 by separating Unit 2 devices into thru' Table 4.1.lb.

14-30 I

i' V

J

, s .e e.e , ,.4.i . -- ..e , v.. e,, - - - , ,_._.m,r

TXX-92050 ATTACHMENT 5 PAGE 2 Of 27 TECHNICAL REOUIREMENT 4.1 TABLE 4.1.lg CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICEE DEVICE NUMBER SYSTEM AND LOCATION POWERED

1. 6.9 KVAC from Switchgears

a. Switchgear Bus lAl RCP #11

1) Primary Breaker IPCPX1 a) Relay 50M1-51 b) Relay 26 c) Relay 86M d) Relay SIM2 e) Relay 50N

2) Rackup Breakers lAl 1 or lAl-2 a) Relay 51M3 b) Relay 51 for IAl-1 c) Relay 51 for lAl-2 d) Relay 86/lAl

b. Switchgear Bus lA2 RCP #12

1) Primary Breaker IPCPX2 a) Relay 50H1-51 b) Relay 26 c) Relay 86M d) Rela) SIM2 e) Reiay 50N

2) Backup Breakers lA2-1 or lA2-2 a) Relay SlH3 b) Relay 51 for IA2-1 c) Relay 51 for IA2-2 d) Relay 86/lA2 COMANCHE PEAK - UNIT 1 4-5 July 21, 1989

TXX-92050 ATTACHMENT 5 PAGE 3 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued) hlT TABLE 4.1. Continued)

CONTAINMENT PENETRATION CONOVCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

1. 6.9 KVAC from Switchgears (Continued)

. Switchgear Bus lA3 RCP #13

1) Primary Breaker IPCPX3 a) Relay 5CMI-51 b) Relay 26 c) Relay 86M d) Relay SIM2 e) Relay SON

2) Backup Breakers 1A31 er IA3-2 a) Relay 51M3 b) Relay 51 for IA3-1 c) Relay 51 for lA3-2 d) Reiay 86/1A3

c. Switchgear 9us lA4 RCP #14

1) Primary Breaker IPCPX4 a) Relay 50M1-51 b) Relay 26 c) Relay 86M d) -Relay SIM2 e) -Relay 50N 2 Backup Breaker 1A4-1 or 1A4-2 a) Relay 51M3 b) Relay 51 for IA4-1 c) Relay 51 for IA4-2 h d) Relay 86/lA4

2. 480 VAC ftom Switchgears 2.1 Device Location - Containment 480V Switchgears IEB1, IEB2, Recire. Fans 1EB3 and lEB4 and CRDM Vent Fans

a. Primary Breakers - IFNAV1, IFNAV2, IFNAV3, IFNAV4, IFNC81 and IFNCB2 COMANCHE PEAK - UN'T 1 4-6 July 21, 1989

TXX-92050 ATTACHHENT 5 PAGE 4 0F 27 TECHNICAL RE0VIREMENT 4.1 (cq!dinued)

TABLE 4.1. ontinued)

~

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTI\E DEVICES DEVICE NUMBER SYSTEM AND LOCAiION POWERED

2. 480 VAC from Switchgears (Continued)

D. Backun Breakers - 1EB1-1, lEB2-1, lEB3-1 and IEB4 1, BT-lEB13 and BT-lEB24

1) Long Time & Instantaneous Relays

Bfll (lEB1-1) MZ5.1 ()EB2-1)

IFNAVI IFNAV2 B/ll (lEB3-1) ML51 (lEB4-1)

IFNAV3 IFNAV4 5.!J151 (lEB3-1) 59/J1 (IEB4-1)

IFNCBI IFNCB2

2) Time Delav Relays

Shi (lEB1-1 51 -11 (IFNAVI)

IFNAVI and IFNAVI BT-lFB13) 51-1 (lEB2-1 52-11 (IFNAV2)

IFNAV2 anu IFNAVO

'BT-lEB24)

Shl (IEB3-1 57 _11 (IFNAV3)

IFNAV3 and IFdAV3 l'T-lEB13)

SL-1 (IEB4-1 51-11 (IFNAV4) 1FNAV4 and IFNAV4 BT-lEB24) 52..1 (lEB3-1 52-L1 (IFNCB1)

IFNCB1 and IFNCBI BT-lEB13)

Shi (lEB4-1 ball (IFNCB2)

IFNCB2 and IFNCB2 BT-lEB24)

Associated circuit breaker sFown in parentheses; e.g., IEB1-1, is backup breaker for IFNAVI.

COMANCHE PEAK - UNIT 1 4-7 July 21, 1989

-TXX 92050 ATTACHHENT S .

PAGE S!OF 27 TECHNLC.AL RE0VIREMENT 4.1 (continued TABLE 4.1. ontinueO 9A {u=tuir D

~e --

> ^

CONTAINMENT PENETRATION CONDUCTOR

-Q11RCURRh: PROTECTIVE DEVICES

.0EY!CE NUMBER SYSTCH AND LOCATION POWERED 2.2 Device Location 480V Containment Switchgear IEB4 Polar Crane

a. Primary Breaker ISCCPI

b. Backup Breaker 1EB4 1 and BT 1EB24

1) Lono Time Delay-Relav l1 51 _ 1 ISCCPI 1

2) Time Delay and Instantaneous Relavs*

-l1 62 (IEB4 1 and 62X (ISCCP1) 1 ;

ISCCPI BT 1EB24) ISCCP1 1

3. 480VAC from Hoto- Control Centers 3.1 Device Location MCC 1EB1-2 Containment Numbers listed belod.

1 l= Prii.ary 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.

b li L.

: Associated circuit breaker (s) shown in paranthe'ses: e.g. IEB4 1 and BT 1EB24 are backup breakers for 15CCPl.

)

' COMANCHE PEAK - UNIT 1 48 REVISION 1 SEPTEAMER.15,1989 i

TXX-92050 t ATTACHHENT 5 PALE 6 0F 27 -T ECHNIC AL , REQUIREMENT 4.1 (tontinued) r.

h -

TABLE 4.1.1 1 Continued).

(9NTAINHENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480 from Motor Control Centers (Continued)

MCC 1EB1 2 G.E.

COMPT. NO. [;LKR. ger SYSTEH POWERED 4G THED Hotor Operated Valve 1-TV 4691 4H THED Hotor Operated Valve 1 'V 4693 3F THED Containment Drain Tank Pump 03 9H THED Reactor Cavity Sump Pump-01 9H THED Reactor Cavity Sump Pump 02 7H THED Containment Sump #1 Pump-01 7H THED Containment Sump #1 Pump-02 6H THED RCP #11 Hotor Space Heater-01 6H THED RCP #13 Motor Space Heater-03 8B THED Incore Detector Drive "A" 8D THED Incore Detector Drive "B" 70 THED Incore Detector Drive "F" 3B THED Stud Tensioner Hoist Outlet 01 70 THED Hydraulic Deck Lift 01 48 THED Reactor Coolant Pump Hotor Hoist Receptacle-42 8H THED RC Pipe Per.etration Cooling Unit 01 8H THED RC Pipe Penetration Cooling Unit 02 5H THED RCP #11 Oil Lift Pump 01 5H THED RCP #13 U11 Lif t Pump-03 108 THED Preaccess Filter Train Package Receptacle-17 SB THED Containment Ltg. XFHR-14 (PNL C3) 10F THED S.G. Wet Layup Cire. Pump 01 (CPI-CFAPRP-01) 12H THED S.G. Wet Layup Circ. Pump 03 (CPI CFAPRP-03) 12H THED Containment Ltg. XFMR-28 (PNL C11 & C12) l2 l

l COMANCHE PEAK - UNIT 1 4-9 Revision 2 January 15, 1990

TXX 92050-iATTACHMENT PAGEt 7 0F. 27 TECHNICAL RE0VIREMENT 4.1-(continued) ontinued) su g m r p TABLE 4.1 -

CONTAINMENT PENETRATION CONDUCTQB OVERCURRENT PROTECTIVE DEVICES d DEVICE NUMBER AND LOCATION 3,

480VAC from Motor Control Centers (Continued)

MCC lEB1-2 G.E. '

COMPT. NO. BKR. TYPE SYSTEM POWERED 6D THED Refueling Machine (Manipulator '

Crane 01) 2M THED RC Drain-Tank Pump No. 1 2F THED. Containment Ltg. XFMR-16 (PNL C7 a'C9) 1M THED Containment Ltg. XFMR-12 (PNL Cl & C5) 3M THED Preaccess. Fan No -ll-SD. THED Fuel Transfer System Reactor Side Cont. Pnl for TBX FHSTTS-0 3.2 Device Location- - MCC lEB2-2 Containment Numbers listed below.

- Primary and Backup - Both primary and backup breakers have Breake,s identical trip ratings and are located in the same MCC compt. These breakers are General < Electric type THED and THFK with thermal-magnetic trip elements; MCC IEB2-2 G.E..

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED M'otor 0perated Valve 1-TV-4692-

! 4M: THED Hotor 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 No. 12= Motor Space Heater ,

6M THED RCP No.14_ Motor Space Heater-04 5B THED Incore Detector Drive "C"-

2B THED Incore Detector Drive "D" 78- THED Incore Detector Drive "E" SD'- THED Containment fuel Storage Crane-01 38- -THED Stud Tensioner Hoist 10utlet-02 L -4B THED Containment Solid Rad Waste 7 Compactor-01 CDMANCHE-PEAK UNIT 1 4-10 July 21, 1989 L

- ==

TXX 92050 ATTACHMENT 5 PAGE 8 0F 27 TECHNICAL REQ 1!1REMENT 4.1 (continued) l hourt i) .>

TABLE 4.1.

^

ontinued) fj)NTAINMENT PENETRATION CONDUCTOR QyERCURRENT PROTECTIVE DEVICES DEVICE-NUMBER AND LOCATION

3. 480VAC from Motor Control Centers (Continued)

MCC IEB2-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 10B THED RCC Change Fixture Hoist Drive-01 10F THED Refueling Cavity Skimmer Pump 01 128 THED Power Receptacles (Cont. El 841')

IN THED S.G. Wet Layup Circ. Pump 02 (CPI-CFAPRP-02) 12M THED S.G. Wet Layup Circ. Pump 04 (CPI-CFAPRP 04) 8H THED RC Pipe Penetration fan-03 8M THED RC Pipe Penetration Fan-04 5H THED RCP #12 011 Lift Pump 02 5H THED RCP #14 011 Lif t Pump-04 12H THED Preaccess Filter Train Package Receptacles - 18 60 THED Containment Auxiliary Upper Crane-01

!- 2F THED Containment Ltg. XFMR-13 (PNL C2) 70 THED Containment Elevator-01 l 2D THED Containment Access Rotating l

P1atform-01 2M THED Reactor Coolant Drain Tank i%mp-02 9F THED Containment Ltg.XFMR-17 (PhL C8 & C10) l 9H THED Containment Ltg XFMR-15 (PNL C4 & C6) 3M THED Preaccess Fan-12 IG THFK Containment Welding Machine Power Supply Unit 3.3 Device Location - MCC IEB3-2 Containment numbers-listed below.

Primary and Backup - Unless noted oth w. vise, both primary and backup breakeis have identical trip ratings and are located in the same nCC compt. These breakers are General Electric type THED or THFK with thermal-magnetic trip elements.

COMANCHE PEAK - UNIT 1 4-11 July 21, 1989

TXX-92050 ATTACHHENT 5 PAGE 9 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued TABLE 4.1. ContinueG 5A h' IT-' 1]. CONTAINMENT PENETRATION CQNDUCTOR OVERCURRENT PROTECTIVE DEVIC 11 DEVICE NUMBER SEQ __LQCATION 3.

480VAC from Motor Control Centers (Continued)

MCC lEB3-2 G.E.

(Qi!.PT. NO. BKR. TYPE SYSTEM POWERED 8RF THED JB-IS-1005, Altern. Feed to l% tor Operated Valve 1-8702A 1G THED Motor Operated Valve 1-8112 i 1

9G THED Motor Operated Valve 1-8701A i

9M THED Motor Operated Valve 1-87018 SM THED Motor Operated Valve 1-8000A l

SG THED Motor Operated Valve 1-HV-6074 1 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 Operated Valve 1-HV-4701 3G THED* Motor Operated Valve 1-HV-5541 3M !: LED

Motor Operated Valve 1-HV-5543 1M THED Motor Operated Valve 1-HV-6083 6F THED Motor Operated Valve 1-HV-8808A 6M THE0 Motor Operated Valve 1-HV-8808C l

7M THED Containment Ltg. XFMR-18 (PNL SCI & SC3) 8M THED Neutron Detector Well Fan-09 7F THFK Electric H2 Recombiner Power Supply PNL-01 8RM THED Motor Operated Valve 1-HV-4075C 9RF THED Motor Operated Valve 1-HV-4782 9RM THED Motor Operated Valve 1-8811A Primary protection is provided by Gould Tronic TR5 fusible switch with 3.2A fuse.

COMANCHE PEAK - UNIT 1 4-12 January 15, 1990

TXXe92050 ATTACHMENT 5 PAGE 10 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1. Continued) pA UN IT 1 -

CONTAINMENT PENETRATION CONDUCTOR QVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION 3.

480VAC from Motor Control Centers (Continued) 3.4 Device Location - MCC IEB4-2 Containment numbers listed beluw.

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 IE84-2 G.E.

COMPT NO. BKR. TY,PJ SYSTEM POWERED IM THED JB IS 1230G, Altern. Feed to Motor Operated Valve 1-87018 8G THED Motor Operated Valve 1-8702A BM THED Motor Operated Valve 1-87028 4M THED Motor Operated Valve 1-80008 i 4G THED Motor Operated Valve 1 HV-6075 l

3G THED Motor Operated Valve 1 HV-6077

3H THED* Motor Operated Valve 1-HV-6079 2G THED Motor Operated Valve 1-HV-5562 2M THED* Notor Operated Valve 1-HV-5563 SF THED Motor Operated Valve 1-88088 SM THED Motor Operated Valve 1-88080 6M THED Containment Ltg. XFMR-19 (PNL SC2&SC4) 7M THED Neutron Detector Well Fan-10 6F THFK Elect. H2 Recombiner Power Supply PNL-02 BRF THED Motor Operated Valve 1-HV-4783 8RM THED Motor Operated Valve 1-88118 i

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

COMANCHE PEAK - UNIT 1 4-13 July 21, 1989

TXX 92050 ATTACHMENT 5 lECHNICAL REOUIRFMENT 4.1 (continued)

PAGE 11 -0F 27 pn=

TABLE 4.1. . Continued) 5-A 1.

( U Al rrCj CONTAINMENT PENETRATION CONDUCTOR OVERCU?E;JT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

4. 480VAC from Panelboards For Pressurizer Pressurizer Heaters Heaters (1) groups A, B & D

a. Primary Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. & Location - Ckt. Nos. 2 thru 4 of Panelboards IEB2-1-2, IEB3-1-2, IEB4-1-1, 3 IEB4-1 2 and Ckt. Nos. 2 thru 5 3 of Panelboards IEB2-1-1 and 3 lEB3 1-1. 3

b. Backup Breakers - General Electric Type THJS with longtime and insts.' solid state trip devices with 400 Amp. sensor.

Breaker No. & Location - Ckt. No, I of Panelboards IEB2-1-1, IEB2-1-2, IEB3-1-1, 3 IEB3-1-2, iEB4 1-1 and IEB4-1-2. 3 1

(2) group C

a. Primary Breakers - General Electric Type THED breakers.

Breaker No. and Location - For both IEB1-1-1 & IEB1-1-2 3 are located at Ckt. Nos. 2 thru 4.

- b. Backup Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No. and Location - Ckt Nos. 2 thru 4 of Switch- '2 boards IEB1-1-1 & IEB1-1-2. 3

5. 120V Space Heater Circuits Containment from 480V Switchgears Rectre. Fan and CROM Vent.

Fan Motor Space Heaters l

COMANCHE PEAK - UNIT 1 4-14 REVISION 3 JULY 20, 1990

TXX-92050 ATTACHMENT 5 PAGE 12 Of 27 TECHNICAL RE0VIREMENT 4.l (continued)

TABLE 4.1. ontinued) 5-A UM rr 1;] .:- a CONTAINHENT PENETRATION CONDUCTOR QyERCURRENT PROTECTIVE DEVl(El S. 120V 5 pace Heater Circuits from 480V Switchgears (Continued)

a. Primary Device) - N/ A ( Fuse) l2

b. Backup Breakers l2 BKR. LOCATION WESTINGHOUSE

& NUMBER __.

BKR. TYPE ___

Swgr. IEEl.

EB1010 Cubicle 3A.

CPI-VAFNAV 01 Space Heater Bkr.

Swgr. IEB2, EB1010 Cubicle 3A, CPI VAFNAV 02 Space Heater Bkr.

Swgr. 1EB3 EB1010 Cubicle 9A, CP1-VAFNAV 03 Space Heater Bkr.

Swgr. 1EB4, EB1010 Cubicle 9A.

CPI-VAFNAV 04 Space Heater Bkr.

Swgr. IEB3, EB1010 Cubicle 8A.

CPI-VAFNCB 01 Space Heater Bkr.

Swgr. 1EB4, EB1010 Cubicle 8A, CPI-VAFNCB 02 Space Heater Bkr.

COMANCHE PEAK - UNIT 1 4 15 Revision 2 January 15. 1990

TXX-92050 ATTACHHENT 5 AG Of 27 TECHNICAL RE0VIREMENT 4.1 (untinued)

Tp1Lf,L (_9gtigitted]

A 5-A Q=dM 'T ^ lj--

CONTAINMENT PMETRATION CONDUCTOR QVERCURR.MT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AM LQC ATION PRGLQ

6. 125V DC Control Power Various

a. Primary Devices - N/A (Fuse)

b. Backup Breakers

, GENERAL ELECTRIC f_A arf 1MARD NO. CKT. NO. ___MEAKER_IYPE XEDl 1 1,6 TED XED2-1 1,3,6 TED XD2 3 8 IED2 1 14,17 TED TED l1 lEDl-1 14 102-3 7,10 TED TED l2 102-2 9 TED LED 2-2 12 TED lE03-1 5 TED IEDl-2 7,8 TED TBX-WPXILP-01 Hain (LBK3) FB(Westinghouse) 1

7. 120V AC Control Power from Isolation XFHR TXEC3 & TXEC4 l1

a. Primary Devices N/A (Fuse) I

b. Backup Breaker - Square D Type Olt located in 1 Hiscellaneous Signal Control Cabinet 1

8. 120V AC Power for Perscnnel and Emergency Airlocks

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC P_MELMARD NO. CKT. NO. BREAKER TYPE XEC2 34 )

XECl-2 2 ItD COMANCHE PEAK - UNIT 1 4-16 Revision 2 January 15, 1990

TXX 42050 ATTACHMENT 5 PAGE 14 0F 27 TECHNICAL RE0VIREMENT 4.1 (continuidl TABLE 4.1. Continued) 5 U LhT x

_- - - 1 ; CONTAINMENT PENETRATION CONDUCTOR QyIRCURRENT PROTECTIVE DEVl{il DEVICE NUMBER A

A N D t Q{_AJJ 03

9. 118V AC Control Power

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE IC2 22 TED IPCI 10.13 TED 1PC4 6.10 TED l IEC1 / TED 2 1EC2 7 TED 2 IEC5 8 TED IEC6 3,8 TED

10. Emergency Evacuation System Warning Lights Power

a. Primary Devices N/A (Fuse)

b. Backup Breakers SOUARE D PANELBOARD NO. CKT. N 0_._ BREAKER TYPE XEC3 3 9, 10 FAL 12020 1 1

11. DRPI Data Cabinet Power Supplies

a. Primary Breakers 2 2

SOUARE D 2 PANELBOARD NO. CKT. NO. BREAKER TYPE 2 1C14 1,2 FA-14050A l2

b. Backup Breakers 50VARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 1C14 Main Pnl. Bkrs. FA-14070A l2 Iz COMANCHE PEAK - UNIT 1 4-17 %

Revision 2 January 15, 199'

TXX-92050 ATTACHMENT 5 i

PAGE 15 0F 27 TECHNICAL REGUIREMENT 4.1 TABLE 4.1.1h 1 -

LONTAINMENT PENETRATION CONDUCTOR gyERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SfSTEM AND L0 CAT 10N PQ}]{fEQ

l. 6.9 KVAC from Switchgears

a. Switchgear Bus 1 RCP # 1 2

1) PrimaryBreakurgPCPX1 a) Relay 50H1 51 b) Relay 26 c) R*!1ay 86M d) Relay SIM2 e) Relay SON 2 2

2) BackupBreakersIAl-1orgAl-2 a) Relay SIM3 b) Relay 51 for 1-1 c) Relay 51 for 1-2 d) Relay 86/ gal 2 2 Z

b. SwitchgearBush2 l

2 RCPf

1) PrimaryBreaker(PCPX2 a) Relay 50MI-51 b) -Relay-26 c) Relay 86M d) Relay 51M2 e) Ralay SON

2) Backup Breakers A2-1 or 2-2 a) Relay SIM3 2 b) Relay 51 for IA2-1 c) Relay 51-for A 2-2 d) Relay 86/$2 2 2

l 18 COMANCHE PEAK - UNIT 1 4[ July 21, 1989

'TXX 92050-

.AVTACHMENT 5 PAGE 16 0F 27

-TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1. Continued 1 05-8-(Uu rr- '2) ^ '

CONK!NMENT PENETRATION DUCTORCON OVERCURRENT PROTECTIVE biVICES DEVICE NUMBER SYSTEM E(0 LOCATION POWERED

1. 6.9 KVAC from Switchgears (Continued) 2

c. SwitchgearBus$A3 RCP (2 3

1) Primary BreakerkCPX3 a) Relay 50H1-51 b) Relay 26 c) Relay 86M d) Relay SIM2 e) Relay SON 2 2

2) BackupBreakers$A31ork3-2

a) Relay SIM3 b) Relay 51 for 3-1 '

c) Relay 51 for 2 d) Relay 86/$3 2 2

d. 2 SwitchgearBush4 RCPf4

1) PrimaryBreakerMPCPX4 a) Relay 50H1-51 b) Relay 26 c) Relay 86M d) Relay SIM2 e) Relay 50N 2 2 2 BackupBreakerM4-1or@4-2 a) Relay 51M3 b) Relay 51 for 4-1 c) Relay 51 for 4-2 d) Relay 86/gA4 2

2. 480 VAC from Switchgears 2.1Devicelocation-f .

Containment-J4 OV Switchgears @EB1,JiCB2, Recire. Fans RB3andfB4 2 I-'

and CROM 2 Vent Fans 2

a. akers-$FNAV1, 2PrimaryBr}FN3V3,dfNAV4, FNAV2,#

l 2 p(FNCBI and gFNCB2'2 COMANCHE PEAK - UNIT 1 2, 4f July 21, 1989 I4

TXX-92050 ATTACHMENT 5 PAGE 17 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1. Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

2. 480 VAC from Switchgears (Continued) 2- 2

b. BackupkBreakers-@EB1-1, 2pE32-1,TEB3-1anddEgl, BT-%EB13andBT-$EB24 2, 2 1

1) Long Time & Instantaneous Relays

Z 2

%EB1-1) $EB2-1)

2. @f'FNAVIL/JR 2.

@1Q/11 FNAV2 2

(fB31) (hB41) 2- 2 M/ (fEB3-1) 19/_11 (hB4-1)

2. 7 NCBI JFNCB2 C

2) Time Delav Relays

2 2 g_- l (fEB1-1 ($NAV1) 2pFNAVI and 2 BT-fjB13) @61 11 NAVI l

5M- (MEB2-1 52-lX kNAV2)

2.@FNAV2 and IkNAV2

' BTgB24) 2 2 gL-L ($EB3-1 54-lX 2 @FNAV3 and (fFNAV3) 2ffRAV3 BT-$EB13)

{ ffEB4-1 2-lX ffNAV4) 3 AV4 and 2 NAV4 BT-gEB24) hEB3-1 51_1 51-11 (gFNCB1) 2 @FNCBI and i

2kNCBI BT-fjB13) 2 gL-l B4-1 52-1X (hNCB2) 2.gFNCB2 and F-8FNCB2 BT-$EB24) t 1

2 Associatedcircuitbreakershowninparentheses;e.g.,hEB1-1,is backup breaker for #FNAVI.

COMANCHE PEAK - UNIT 1 2 4 July 21, 1989

\

20

_.___-__,_._.__m . _ . . _ _ - . . _ , _ . - . . . _ __ _ _ _

TXX 92050 LATTACHMENT 5 PAGE f8-0F 27 -TECHNICAL REQUIREMENT 4.1 (continued)

TA Continued) 58 5 BLE 4.1 Courr7_PCONTAINMENT DENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES I DEV!CE NUMBER SYSTEM A10 LOCATION P0wEkED 2.2 Device Location - 480V Containment Switchgear$EB4 Polar Crane 2

a. Primary Breaker - CCP1

b. BackupBreakerhEB41andBTIEB24 z 2

1) Lena Time Delav Relay l1 1 51 1-2 $5CCP1 1

2) Time Delay and Instantaneous Relays *

-l1 2 ?

62 (kB41and 62X fCCP1) 1-2gSCCP1 BT- B24) $ CCPI 1

3. 480VAC.from Motor Control Centers 2

3.1 . Device Location HCC'[EB12ContainmentNumbers listed below.

Primary and Backup Both primary and backup. breakers Breake's have identical trip ratings and are in the same MCC Compt. These breakers are General Electric type THCD or-.THFK with thermal-magnetic trip elements.

2 '.

Associated circuit breaker (s) showninparanthe'ses;e.g.hEB4-1and

, BTjEB24arebackupbreakersfordSCCPl.

2 2 L

COMANCHE PEAK UNIT 1 4fb REVISION 1 SEPTEMBER 15,1989

. _. _ _ _ . . _ _ . - ~ . _ . _ _ _ _ . . _ _ . . . . . _ . . . . _ _ - - . . _ _ . _ . _ . . _ .

-TXXf92050

ATTACHMENT 5

PAGE 13'0F 27

' TECHNICAL' REQUIREMENT 4.1 (continued)

TABLE 4.1.

nit h Continued) 56 '

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480 from Motor Control Centers (Continued)

MCCIEB12 G.E.

COMPT. NO. gKR. TYPJ SYSTEM POWEREQ 2

4G THED Hotor Operated Valvi - T V - 4 691, 2 4M THED Hotor Operated Valve V 4693-3F -THED Containment Drain ' ank Pump 03 9H THED. . Reactor. Cavity Surp Pump 01 9M THED Reactor Cavity Su'sp Pump 02 7H THED Containment Sump #1 Pump 01 7H THED g _- containment Sump #1-Pump 02 6H THED RCP_ l'Hotor Space Heater-01.

6H THED 2 RCP Motor Space Heater-03 8B THED- Incore Detector Drive "A" 80 THED Incore Detector Drive "B" 78 THED Incore Detector Drive "F" 3B THED

' Stud Tensioner Holst Outlet 01 7D THED Hydraulic Deck Lift-01 4B THED Reactor Coolant Pump Notor Holst Receptacle 42 BH THED RC Pipe Penetration Cooling Unit 01 ,

8M THED RC Pipe Penetration Cooling 2- Unitt02 5H THED RCP 1 Oil Lift Pump-01 SH THED 2~ RCP 3 011 Lift Pump 03 10B THED Preaccess-Filter Train Package Receptacle-17 SB THED Containment Ltg. XFMR-14

.(PNL C3)

-10F THED S.3. Wet Layup Cire. Pump 01 2 (C CFAPRP 01) 12M THED S.;yWetLayupCirc,

a. Pump 03 2 .(C%CFAPRP 03) 12H THED Containment Ltg. XFMR 28

[2 (PNL ,C11 & ,C12) z a l

COMANCHE PEAK - UNIT 1 Revision 2 4h $7 January- 15, 1990

._ . _ _ 7 _

TXX 92050-

-ATTACHMENT 5

-PAGE 20 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued) r_ - e g TABLE 4.1. ontinued 5-8 u 9 er 2 > ^-

CONTAINMENT PENETRATION CONDUCTOR-Q1ERCURRENT PROTECTIVE DEVICES DEVICE NUMBER ,

AND LOCATION 3.

2480VAC.from Motor Control Centers (Continued)

-MCC$EB1-2 G.E.

COMPT. NO. -BKR. TYPE SYSTEM POWERED 60 THED Refueling Machine (Manipulator Crane 01) 2M THED RC Drain Tank Pump No- 1 1 2F. THED_ N ntainment Ltg. XFMR-16 (PNL'C7 & C9) h IN THED 3M t,ontainment Ltg. XFMR-12 (PNL ,C1 & 45)

THED Preaccess Fan No. 11 2 SD THED Fuel Transfer System Reacto Side i Cont. Pnl. for $ .FHSTTS-3.2 Device Location-Q C

--MCC F B2-2 Containment Numbers listed l 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 and THFK with thermal-magnetic trip elements.

MCC882-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 2

L 4G THED~ TV-4692 4M THED MotorOperatedValve@TV4694 Motor _ Operated Valve gE 3F THED Containment Drain Tank' Pump-04 g

7H THED Containment _ Sump No. 2 Pump-03 7H 6H THED 2 c nttinment Sump-No. 2_ Pump-04 THED RCP( Motor Space Heater-02 6M THED RCP ( Motor Space-Heater-04 5B THED 2 Incore Detector Drive "C" 2B THED Incore Detector Drive "D" 78 THED- Incore Detector Drive "E" u-SD THED Containment Fuel Storage Crane-01 38 THED Stud Tensioner Hoist Outlet 4B THED Containment Solid Rad Waste Compactor-01 j

COMANCHE PEAK - UNIT 1 4@23 July 21, 1989

h TXX 92050

~ ATTACHMENT 5 PAGE 21 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued) ,

-m

_ TABLE 4.1.1 Continued) s-s cumt - 2,4 t

CONTAINMENT PENETRATION CON 00CTOR CVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION 3.

480VAC from Motor Control Centers (Continued)

MCC B2-2 G.E.

COMPT NO. BKR. TYPE SYSTEM POWERED 10B THED RCC Change Fixture Holst Drive 01 10F THED Refueling Cavity Skimmer Pump-01 12B THED IM THED Power S.G. WetRecQ Lt., O Circ.

.les (Cont. El. 841')

2 Pump 02 (C T CFAPRP-02) 12M THED .

g _ S.G.; Wet layup Cire. Pump 04 ,

(CFy CFAPRP-04) '

8H THED RC Pipe Penetration Fan-03 E K Pipe Penetration Fan 04 8M THED SH THED RCP 7 2 Oil Lift Pump 02 SM THED 2 _ RCPD 011 Lift Pump 04 12H THED Preaccess Filter Train Package Receptacles 18 6D THED Containment Auxiliary Upper Crane 01 2F THED 7D Containment Ltg. XFMR 13 (PNL C2)

THED Containment Elevator-01 20 THED Containment Access Rotating Pl_atform 01 2M THED Reactor Coolant Drain Tank Pump-02 9F THED Containment Ltg.XFMR-17 (PNL C8 & C10)_

9M THED r 3M Contafrment Ltg.XFMR 15 (PNL C4 & CS)

THED- Preaccess Fan 12 THFK -Containment Welding _ Machine Power 1(g Supply Unit 3,3 Device Location

- MCC EB3-2 containment numbers listed below.

Primary and Backup - Unless noted otherwise, both primary.

p 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 -_ UNIT 1 4 July 21, 1989

. TXX 92050 !

~

ATTACHMENT 5 -

~PAGE 22 0F 27 TECHNICAL RE0VIREMENT 4.1 (continuedi l BLE 4.1.

Continued)

- (Qt[TAlhMLNT pENFTRATJON CONDUCTOR I OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION 3.

2 480VAC from Motor Control Centers (Continued)

MCCdEB3-2 G.E.

COMPT. NO. BKR. TYPE 11 STEM POWERED 2 ;

SRF THED JBfS-1005,Altern Feed to Motor 1G THED Operated Valve - 702A g Motor Operated Valve p-8112 9G THED Motor Operated Valve k$8701 A s4 9M THED Motor Operated Valve 7 87018 j

~

SM THED Motor Operated Valve 8000A SG THED Motor Operated Valve -6074 4G THED Motor Operated Valve V-6076 i 4M THED* Motor Operated Valve HV-607 f 2G THED Motor Operated Valve 2M THED Motor Operated Valve HV-4694//

V-4 701/

3G THEDN Motor Operated Valve HV-554 3M THED P Motor Operated Valve F-HV-554 IM /

THED Motor Operated Valve fHV-6083/)

6F THED - Motor 0perated Valve #'HV-6608A/

6M THED Motor Operated Valve F HV-8808C 7M THED Containment Ltg. XFMR-18 BH (PNL SCl & SC3)

THED Neutron Detector Well Fan-09 7F THFK Electric H2 Recombiner Power Supply BRM PNL-01 -2 THED Motor Operated Valve d V-4075C /

9EF THED Motor Operated Valve FTHV-4782 /

9RN THED MotorOperateoValveg"8811A 1-Primary protection is provided by Gould Tronic TR5 fusible switch with 3.2A fuse.

COMANCHE PEAK - UNIT 1 4- @ z 5 January 15, 1990

4 TXX 92050

. ATTACHMENT 5 PAGE 23 0F 27 TECHNICAL RE0VIREMENT 4.1 (continued)

TABLE 4.1. Continued) 5-6 uurr

-- M a : "

CONTAINMENT PENETRATION CONDUCTOR Q1EkCURRENT FROTECiiVE DEVICE 5 OEVICE NUMBER AND LOCATION

3. 480VAC From Motor Control Centers (Continued) 2 3.4 Device Location -MCC$EB4-2Containmentnumberslisted 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 themal-magnetic trip elements.

MCCMB4-2 G.E.

COMPT. NO. SKR. TYPE SYSTEM POWER _EQ 23'Go*0G g IM THED JBJ11. m ua, Altern. Fe to Motor Operated Valve 87018 BG THED Motor Operated Valve -~ 02A j BM THED Motor Operated Valve 028 dj 4M THED Motor Operated Valve 80008 /

l 4G THED Motor Operated Valve .HV-607 l 3G THED Motor Operated Valve (J.L-607)7 l

3M Motor Operated Valye ENV 6079.

2G Motor Operated Valve V 5562 2M ' THEDQsrar Motor Operated Valve y_- 5 56_3 SF THED Motor _ Operated Valve __ 80881 2 SM THED Motor Operated Valve F8808D 4 6M THED Containment Ltg. XFMR-19 (PNL 5C2&SC4) 7M THED Neutron Detector Well Fan-10 ,z 6F THFK Elect. H2 Recombiner Power Supply PNL-02 -2 BRF THED Motor Operated Valve @ HV-4783 BRM THED Motor Operated Valve @8811B E

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

COMANCHE PEAK - UNIT 1 4-h July 21, 1989 2b

TXX 92050 TECHNICAL REOUIREMENT 4.1 (continued)

ATTACHMENT E PAGE 24 - 7

,, T A BL E 4.1.T,"7'C on t i nued )

54 uw -

z e

CONTAINMENT PENETRATION-CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEY!CE P.L'P.EE". b o itM AND LOCATIOS POWERED 4 480VAC Erom Panelboards For Pressurizer Pressurizer Heaters Heaters (1) groups A, B, & D

a. Primary Breakers - General Electric Type TJJ Thermal Magnetic breakers.

2 7 Breaker No. & Location2 - Ckt. Nos. 2 thru 4 o Panelboards EB2-1-2, EB3-1-2, B4-1 1, 3 2 EB4-1-2 and Ckt. Nos. 2 thru 5 3 ofPanelboardsgEB2-1-1and 3 2.$EB3-1-1. Z 3

b. Backup Breakers - General Electric Type THJS with longtime and insts. solid state trip devices with 400 Amp. sensor.

2 2 Breaker No. & Location - Ckt. No. Ilof Panelbgo s 2 EEB2-1-1, #EB2-1-2, FtB3-1-1, 3 g.$EB3-1-2,@EB4-1-1and$EB4-1-2. 3 (2) group C

a. Primary Breakers - General Electric Type THED breakers.

2 BreakerNo,andLocation-ForbothhEB1-1-1&hEB1-1-2 3 are located at Ckt. Nos. 2 thru 4.

b. Backup Breakers - General Electric Type TJJ Thermal Magnetic breakers.

Breaker No, and Location - Ckt Nos. 2 thru 4 of Switch- 2 boardsAEB1-1-1&$EB1-12. 3

5. 120V Space Heater Circuits 2 2 Containment from 480V Switchgears Reci.c. Fan and CRDH Vent.

Fan Motor Space Heaters COMANCHE PEAK - UNIT 1 4h27 REVISION 3 JULY 20,1990

TXX 92050.. '

' ATTACHMENT 5 PAGE 25 0F 27 TECHNICAL RE0VIREMENT 4.1 (centinuedl SD 5-8 (Um-N rr z -

-) -

TABLE 4.1.1.(Continued)

CONTA1NHENT PENETRATION CONDUCTOR OYEPC"PPENT PDOTEGT!VE Ei.(1G1

5. 120V Space Heater Circuits from 480V Switchgears (Continued)

. a, Primary Devices N/A (Fuse) a l2

b. Backup Breakers j2 BKR. LOCATION WESTINGHOUSE

& NUMBER _,,

BKR. TYPE ,

Swgr. Bl. Eb1010 Cubicle V.6 2 Q VAFNAV-Ol' Space-Heater Bkr.

2 Swgr.@EB2. EB1010 2 FNA 2 Space Heater Bkr.

2 Swgr.IEB3, EB1010 g ,1 Qicle 9f.6 CPp VAFNAV-03 Space Heater Bkr.

T.

Swgr.$EB4 EB1010 Cbicle9g.8 b, C -VAFNAV 04 Space Heater Bkr.

2 Swgr.$EB3, EB1010 ,

E -V FN 01 Space Heater Bkr.

Swgr.$EBd. EB1010 g A bicle 8(.0 C -VAFNCB-02 Space Heater Bkr.

i I

!~

l C0HANCHE PEAK - UNIT 1 4h g Revision 2 January 15. 1990

TXX 92050 ATTACHMENT $

PAGE 26.0F 27 T(CHNICAL REQUIR[ T 4.1 (continued 1 m- --

5-8 23 _ TABLE 4.1.1 Acontinn dl

(=L uir

^

CONTAINHENT PENETRATION CONDUCTOR '

OVERCURRENT_ PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION P OW E E' E0

6. 125V DC Control Power Various

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. (KT. NO. BREAKER TYPE XEDI 1 %6 TED

~

X.E D2 - 1 002 3 W. 6 TED 2 @ED2-1 e TE M l1 11,14.17 TED 2 @EDI-1 n ,14 TED 2/)D2-3 (o , 10,31 TED l2 2dD2-2 9 TED 2 JED2-2 12 TCD EpED3-1 5 TED 2 BED 1 2 7.8 TED ,

TBX-WPXILP 01 Main (LBK3) FB(Westinghouse) l1

7. 120V AC Control Power from Isolation XFHR TXEC3 & TXEC4 l1

a. Primary Devices N/A (Fuse) l1

b. Backup Breaker - Square D Type 01L located in 1 Miscellaneous Signal Control Cabinet 1 B, 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 t V XECg 34. 12 TED XECF-2 2)3 TED 2

l l

COMANCHE PEAK - UNIT 1 4h d Revision 2 January 15. 1990

[

l l

TXX 92050 !

ATTACHMENT 5 PAGE 27 0F 27 TECHNICAL REQUIREMENT 4.1 (continued)

TABLE 4.1. Continued)

Utd lT 2 JNTAINMENT PENETRAT!01_ CONDUCTOR J

O ERCURRENT PROTECTIVE DEVICES DEv!CE NUMBER AND LOCATION

9. 118V AC Control Power

a. Primary Devices - N/ A (Fuse)

b. Backup Breakers GENERAL ELECTRIC P ANELBOARD NL CKT, NO. BREAKER TYPE 2 $2 22 TED 2 C1 10.13 TED l1 2 C4 6.10 TED 2 C1 7 TED 2 g EC2 7 TED 2 2 EC5 8 TED 2 EC6 3.8 TED

10. Emergency Evacuation System Warning Lights Power

a. Primary Devices N/A (Fuse)

b. Backup Breakers 500ARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 4

XEC[-3 9, 10 FAL-12020 1

~ 1

11. DRPI Data Cabinet Power Supplies

a. Primary Breakers 2 2

SOUARE.D 2 PANELBOARD NO. CKT. NO. BREAKER TYPE 2 2$C14 1,2 FA-14050A l2

b. Backup Breakers 500ARE D PANELBOARD NO. CKT. NO. BREAKER TYPE 2 h14 Main Pol. Bkrs FA-14070A l2 l2 l

j COMANCHE PEAK - UNIT 1 4h3O Revision 2 January 15, 1990

E

, TXX 92050 j ATTACHMENT 6 PAGE 1 of 6 i

l- Justification L: - The' technical-requirements in this attachment cc'itain plant specific numbers l which are'yet to be confirmed. Those numbers still requiring design

confirmation, of' applicability for: Unit 2, have been enclosed within brackets

i. for identification purposes, i

4-i -

i i

?

l-1 4-l i ,

_1 l

i b

e e

,i l

l' r ,

f f

e- t l

i

'b

,-~w* +,-,,- ... e._.-,.,. ,_.w...-.,,,,,,...,-,em,,,,.m,w,, .r ..q-y ,.e, - m m , yn ne- w M *-N 4 2e-*"M"+wT"T- Y4' N-'"m

r Y "- =Y Y'

TXX 92050 ATTACHMENT 6 PAGE 2 0F 6 _

IECHNICAL RE0VIREMENT 1.2 (continued)

TABLE 1.2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

2. Containment Pressure High-1

a. Safety injection (ECCS) 127(1,5a)/[27(4,5b}

b. Reactor Trip 52

c. Feedwater Isolation 16.5

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

e. Containment Ventilation isolation N.A.

f. Auxiliary Feedwater

}t 6k

g. Station Service Water N.A.

h. Component Cooling Water N.A.

1. Essential Ventilation Systems N.A.

J. Emergency Diesel Generator 1 12 Operation

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump (7) 1 17/27 COMANCHE PEAK - UNIT 1 1-9 July 21, 1989

TXX 90050 ATTACHMENT 6 PAGE 3 0F 6 IFCHNICAL RE0VIREMENT 1.2 (continued)

TABLE 1.2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SEf.ANM

3. Pressurizer Pressure--Low

a. Safety Injection (ECCS) s27(1,5a)/[27(4,5b]

b. Reactor Trip i2

c. Feedwater Isolation 17

d. Phase "A" Isolation s 17(2)/27(1)

e. Containment Ventilation Isolation [15(6[_

f. Auxiliary feedwater

[1 60[

g. Station Service Water N.A.

h. Component Cooling Water N.A.

1. Essential Ventilation Systems N.A.

J. Emergency 01esel Generator Operation 5 12 -

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump (7) N.A.

COMANCHE PEAX - UNIT 1 1-10 July 21, 1989

TXX 92050 ATTACHMENT 6 PAGE 4 0F 6 TECHNICAL RLOUIREMENT 1.2 (continued)

TABLE 1.2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTIQB RESPONSE TIME IN SECONOS

4. Steam Line Pressure--Low

a. Safety injection (ECCS) 137(3.5b)/27(4,5b)

b. Reactor Trip 52

c. Feedwater Isolation F s 6.5 L ,

d. Phase "A" Isolation s 17(2)/27(1)

e. Containment Ventilation Isolation N.A.

f. Auxiliary Feedwater [s 60[

g. Station Service Water N.A.

h. Camponent Cooling Water N.A.

i. Essential Ventilation Systems N.A.

J. Em::gency Diesel Generator Operation s 12

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

m. Containment Spray Pump (7) N.A.

n. Steam Line Isolation s 6.5 COMANCHE PEAK - UNIT 1 1 11 July 21, 1989

TECHNICAL R'E0VIREMENT 1;2 (continued)

TXX-92050 ATTACHMENT 6 TABLE-1.2.1 PAGE 5=0F 6-ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION. RESPONSE TIME-IN SECONDS 5, Containment Pressure -High-3 i

a. . Containment Spray Pump N.A.

b. Phase "8' Isolation - N.A.

c. Containment Spray Pump Discharge - -

Valve- s 119

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

7. Steam Line Pressure - Negative Rate High Steam Line Isolation s7

~ ~

8. Steam Generator Water Level - High-High

a. Turbine Trip N.A.

b.--Feedwater Isolation s 11 7

9. Steam Generator Water Level - Low-Low

a. Motor-Driven Auxiliary ,

Feedwater Pumps s 60 t

b. Turbine-Driven Auxiliary Feedwater Pump 1 85 4 :

10. Loss-of-Offsite Power '

Auxiliary Feedwater -N.A.

111.- Trip of All Main Feedwater Pumps-All Auxiliary Feedwater Pumps - N.A.

COMANCHE PEAK - UNIT 1 1-12 REVISION 4 APRIL 24, 1991

TXX-92050 ATTACHMENT 6 PAGE 6 Of 6 TECHNICAL RE0VIREMENT 1.2 (continued)

TABLE 1.2.1 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 s 30 Switchovt. to Containment Sump

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

~

a. 6.9 KV Preferred Offsite Source 12(8)

Undervoltage - -

~

b. 6.9 KV Alternate Offsite Source s2(8I Undervoltage - ~

c. 6.9 KV Bus Undervoltage }2(8f _

d. 6.9 KV and 180V Degraded Voltage

~

with Safety Injection [110(8,9) without Safety injection [$63(8,9f _

~

L

e. 480 V Low Grid Undervoltage s 61(8,9)~

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COMANCHE PEAK - UNIT 1 1-13 July 21, 1989 L

TXX 92050 ATTACliMENT- 7 PAGE 1 of 1 ,

Several Technical Requirement Manual changes are currently being considered for CPSES Units 1 and 2. Many of these changes are not directly attributable to the licensing of Unit 2 and are not included in Attachments 1 through 8 It is however, desirable that CPSES Unit 2 be licensed incorpcrating many of these changes. As stated in the cover letter any changes submitted prior-to June 30, 1992, will be transmitted by the normal process. The TRH changes currently in the TU Electric internal review process are: ,

A. Update definition Technical Requirement 0.1 to include the

definition for the Core Operating Limits Report (COLR).

B. Revise Table 1.2.1 Technical Requirement 1,2 to reflect changes made to the Technical Specifications regarding DG undervoltage testing.

C. Update Technical Requirement 1.2, item 10 of Table 1.2.1, to revise the response time for auxiliary feedwater injection f ollowing loss of offsite power. :

i D. Revise Technical Requirement 1.3, 'Hoveable incore Detectors.' to delete the reference to Fxy.

E. Update Table 2.1.1 of Technical Requirement 2.1 to add bonnet relief valves to containment sump recirculation isolation valves.

F. Update Technical Requirement 3.3 to clarify which Nondestructive Examinations were used in the fracture analysis to demonstrate the fracture toughness of the feedwater isolation valve.

G. Revise Technical Requirement 4.1 to swap G.E. breater type for pressurizer heater primary and backup circuit breakers, H. Revise Table-4.1.1 of Technical Requirement 4.1 to describe changes in the penetration protection resulting from addition of distribution panel in the Reactor Containment Building.

1. Update Table 4.1.1 of Technical Requirement 4.1 to revise the breaker type from *0ll' to *00B' J. Adds clarificatlon to containment penetration conductor overcurrent

-protective devices list (Technical Requirement 4.1). The change is based upon the-guidanc6 provided in Generic letter 91-08.

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, _, _ _,_ _ _ , _. _ _ _ ___._ _ _ _ _ .- __

ML20092B808

Text

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