Text

Rev 8 to Technical Requirements Manual
	ML20101N941
Person / Time
Site:	Comanche Peak
Issue date:	06/30/1992
From:	; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	;
Shared Package
ML20101N940	List: ML20101N937; ML20101N941;
References
	PROC-920630, NUDOCS 9207100210
	Download: ML20101N941 (126)
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CPSES TECHNICAL' REQUIREMENTS MANUAL (TRM))

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TECHNICAL REQUIREMENTS MAHUAL Q-V JRLLQF CONTENTS TECHNICAL REQUIREMENT NUMBER SYSTEM / TITLE (RelatedTechSpecifrequired) 0 Administrative Controls 0.1 (1.0) Definitions 0.2 (3/4.0) Applicability.

1.1(3/4.3.1) Reactor Trip Response Time 1.2(3/4.3.2) ESF Actuation Response Time 3

1.3 Moveable Incore Detection System 4

1.4 Seismic Instruments

-1.5 Loose Parts Detection System 2.1 (3/4.6.3) Containment Isolation Valves 3.1 (3/4.7.9) Snubbers 3.2 Station Service Water System 4

Feedwater Isolation Valve Temperature 3.3 Feedwater Isolation Valve Temperature.

4.1 (3/4.8.4) Containment Penetration Conductor Overcurrent-Protection Devices

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. TECHNICAL"REQllIREMENTSMANUAO(TRM) , ,

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i:.. Description of the Administrative Control Process Jm i1 i r._

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TECHNICAL KeQUIREMENTS MANUAL-(TRM)

( Description of the Administrative Control Process INTRODUCTION CFSES has relocated certain information from the Technical 2 Specifications to a separate controlled document based on the NUMARC Technical Specification Improvement Program, the Westinghouse Owners Group MERITS Program, and the Commission's Interim Policy Statement for improvement of-Technical Specifications for nuclear power plants 4 (52 FR 3788 of February 6, 1987).-_This information is now contained in a separate document to be called-the CPSES Technical Requirements Manual (TRM). The following is a description of the administrative program for control, distribution, updating, and amending the information contained in the TRM.

QQCljMENT CONTROL The TRM is considered a licensing basis document and as such, overall 2 control of the document is addressed by the site wide procedures for licensing document control.

DOCUMENT DISTRIBUTION The TRM is considered a controlled document and distribution is controlled by the Nuclear Licensing Department. Licensing specifies 2 Q

(V (by copy number) the proper distribution for the TRM. Distribution includes those personnel / locations which receives the CPSES Technical Specifications as well as any other groups which need access to the information contained in the TRM.

CHANGES / DELETIONS TO THE TRM Changes to the TRM are controlled by the procedure on licensing 2 document change control. This procedure addresses the administrative requirements necessary to change / amend CPSES licensing documents (e.g., Fire Protection Report, Offsite Dose Calculation Manual, etc.). For changes to the TRM, the procedure requires initiation of ,

a Licensing Document Change Request (LDCR). The LDCR is the -

mechanism whereby changes are tracked to ensure that appropriate reviews, approvals, and signatures are obtained. 1RM changes are evaluated per 10CFR50.59. TRM changes require a review by SORC and 2 the approval of the Vice President, Nuclear Operations.

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PLANT CHANGES THAT MAY EFFECT THE TRM Changes made at CPSES have the potential to affect (or be affected by) 3.

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f-the TRM. These include items such as' design' modifications;-procedure-changes, other -licensing document changes, etc.~. The TRM:has'been- ?2 identifiedLas*a CPSES licensing basis document _by=the 10CFR50.59 Program. The-10CFR50.59 ProgramLis' based on'the latest"NUMARC Guidelines for.50.59 evaluations. This_ program requires that:the TRM i 2!

be considered'in a manner similar to the-FSAR when screening changes to determine if an unreviewed safety question might be involved."

DISTRIBUTION OF TRM CHANGES / DELETIONS

Changes to'the TRM will be issued on a replacement page basisLto )

controlled document' holders promptly following approval of.theichange.-

1 REPORT OF TRM CHANGES / DELETIONS TO THE NRC l

Changes to the TRM will be reported to the NRC. annually as-part.of the SAR update. Related safety evaluations 1will be_ reported as-part'of ,

the 50.59 annual report.-

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Proposed TRM changes that are determined to: constitute an unreviewed-safety question (as defined by 10CFR50.59(a)(2)) will either not be .

made or will be submitted to'the NRC for prior review and approval.

UNIT 2-APPLICABILITY -8 The requirements (for Unit 2 are. effective upon-issuance of the- 8

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(,, operation license for Unit 2. The~ technical; requirements contain. c specific numbers which are yet to be confirmed for Unit:2. Those numbers still requiring design confirmation,-of applicability ~for Unit 2, have been enclosed within- brackets for: identification-purposes..

All numbers with brackets will.'be confirmed and-the' brackets removed; prior to Unit 2 fuel load.

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TECHNICAL REQUIREMENT 0.1 0EFINITIONS s This Technical Requirement contains.Section 1.0, DEFINITIONS, of the-Technical-Specifications, which are also applied to the-Technical-Requirements Manual except where otherwise specified. For the purpose of.this Technical-Requirement.Lthe1 Technical Requirements Manual terms specified below shal' be considered synonymous withethe 11sted'

-Technical Specification terms:

Technical Reauirements' Manual Technical S'oecifications L -OPERABILITY CRITERIA LIMITING CONDITION'FOR OPERATION COMPENSATORY MEASURE ,

ACTION i

TESTS / INSPECTIONS SURVEILLANCE REQUIREMENTS a TECHNICAL REQUIREMENT SPECIFICATION-NOTE: Although_the'CPSES Technical' Specification:is: repeated here, in part, care must be taken to overlook Technical Specification. requirements.

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I 1.0 DEFINITIONS The defined terms of this section appear in capitalized type and are applicable throughout these Technical Specifications.

ACTION 1.1 ACTION shall be that part of a Technical Specification which prescribes remedial measures required under designated conditions.

ACTUATION LOGIC TEST 1.2 An ACTUATION LOGIC TEST shall.be the application of various simulated input combinations in conjunction with each possible interlock logic state and verification of the required logic output.

The ACTUATION LOGIC TEST shall include a continuity check, as a minimu- of output devices. ,

ANALOG CHANNEL OPERATIONAL TEST 1.3 An ANALOG CHANNEL OPERATIONAL TEST shall be the injection of a simulated signal into the channel as close to the sensor as practicable to verify OPERABILITY of alarm,-interlock and/or trip functions. The ANALOG CHANNEL OPERATIONAL TEST shall include adjustments, as necessary, of the alarm, interlock and/or Tr" Setpoints such that the setpoints are within the required range and accuracy.

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(/ AXIAL FLUX DIFFERENCE 1.4 AXIAL FLUX DIFFERENCE shall be the difference in normalized flux signals between the top and bottom halves of a four section-excore neutron detector.

CHANNEL CAllB( Q QR 1.ti A CHANNEL CALIBRATION shall be the adjustment, as necessary, of the channel such that it responds within the required range and accuracy to known values of iaput. The CHANNEL CALIBRATION shall encompass the entire channel including the sensors and alarm, interlock an. - trip functions and may be performed by any series of sequential, clapping, or total channel steps such that.-the entire channel is s.a.ibrated.

CHANNEL CHECK 1.6 A CHANNEL CHECK shall be the-qualitative assessment of channel behavior during operation by observation. This determination shall include, where possible, comparison of the channel indication and/or status with other indications and/or status derived from independent instrument channels measuring the same parameter.

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y DEFINITIONS CONTAINMENT INTEGRITY 1.7 CONTAINMENT INTEGRITY shall exist when:

a. All penetrations required to be closed during accident I conditions are either:

1) Capable of being closed by an OPERABLE containment automatic isolation valve system, or

2) Closed by manual valves, blind flanges, or deactivated automatic valves secured in their closed positions, except as provided in Table 2.1.1 of-the Technical Requirements Manual.

b. All equipment hatches are' closed and sealed,

c. Each air lock is in compliance with the requirements of Specification 3.6.1.3,

d. The containment leakage rates are within the limits of Specification 3.6.1.2, and-

e. The sealing mechanism associated with each )e4etration (e.g., .

welds, bellows, or 0-rings) is OPERABLE. l CONTROLLED LEAKAGE 1.8 CONTROLLED LEAKAGE shall be that seal water flow supplied to the reactor coolant pump seals.

CORE ALTERATIONS 1.9 CORE ALTERATIONS shall be the movement or manipulation of any component within-the reactor pressure vessel with the vessel head removed and fuel in the vessel. Suspension of_ CORE ALTERATIONS shall not preclude completion of movement of-a component to a safe _-

conservative position.

DIGITAL CHANNEL OPERATIONAL-TEST ,

1.10 A DIGITAL CHANNEL OPERATIONAL TEST shall consist of exercising the digital computer hardware using data base manipulation and injecting simulated process data to verify OPERABILITY of a~1 arm and/or trip functions.

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DEFINITIONS T QQSE E0VIVALENT I-131 V

1.11- DOSE EQUIVALENT I-131 shall be that concentration of I-131 (microcurie / gram) which alone would produce the same thyroid dose as-the quantity and isotopic mixture of I-131, 1-132, 1-133, I-134, and 1-135 actually present. The thyroid dose conversion factors used for this calculation shall be those listed in Table III of TID-14844,

" Calculation of Distance Factors for Power and Test Reactor Sites" or Table E-7 of NRC Regulatory Guide 1.109. Revision 1, October 1977.

E - AVERAGE DISINTEGRATION ENERGY 1.12 E shall be the average (weighted in proportion to the concentration of each radionuclide in the sample) of the sum of the average beta and~ gamma energies per disintegration (MeV/d) for the radionuclideswithahalflifegreaterthanten(10)_ minutes _inthe sample.

ENGINEERED SAFETY FEATURES RESPONSE TIME 1.13 The ENGINEERED SAFETY FEATURES (ESF) RESPONSE TIME snall be that-time interval from when the monitcred parameter exceeds its ESF Actuation Setpoint at the channel sensor until the ESF equipment is capable of performing its safety = function (i.e.,'the valves travel to d their required positions, pump discharge pressures reach their required values, etc.). Times shall include diesel-generator starting and sequence loading delays where applicable.

FREQUENCY NOTATION 1.14 The FREQUENCY NOTATION specified for the performance of.

Surveillance Requirements shall correspond to the intervals defined in Table 1.1.

IDENTIFIED LEAKAGE 1.15 IDENTIFIED LEAKAGE shall be: !

a. Leakage (except CONTROLLED. LEAKAGE) into closed systems, such as-pump seal or valve packing-leaks that are captured and conducted to a sump or collecting tank .or l

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REFINITIONS IDENTIFIED LEAKAGE (Continued 1

b. Leakage into the containment atmosphere from sources that are

, both specifically loc:ted and known either not to interfere

. with the operation of Leakage Detection Systems or not to be PRESSURE B0VHDARY LEAKAGE, o*

c. Reactor Coolant System leakage through a steam generator to the Secondary Coolant System.

MASTER RELAY TEST 1.16 A MASTER RELAY TEST si,all be the energization of each master relay and verification of OPERABILITY of each relay. The MASTER RELAY TEST shall include a continuity check of each associated slave relay.

MEMBER (S1 0F THE PUBLIC 1.17 MEMBER (S) 0F THE PUBLIC snail include all persons who are_not occupationally associated with the plant. This category does not include employees of the licensee, its contractors, or vendors. Also excluded from this category are persons who_ enter the site to-service equioment or to make deliveries. This category does include persons who use portions of the site for recreational, occupational, or other purposes not associated with the plant.

0FFSITE DOSE CALCULATION MANUAL 1.18 The OFFSITE 00SE CALCULATION MANUAL (00CM) shall contain-the methodology and parameters used in the calculation of offsite doses resulting from radioactive gaseous and liquid effluents, in the calculation of gaseous and liquid effluent monitoring Alarm / Trip Setpoints, and in-the conduct of the Environmental Radiological Monitoring Program. TheODCMshallalsocontain.(1)theRadioactive Effluent Controls and_ Radiological Environmental Monitoring Programs required by Section 6.8.3 and (2) descriptions of the information that should be included in the Annual Radiological Environmental Operating--

and Semi-annual Radioactive Effluent Release Reports required by Specifications 6.9.1.3 and 6.9.1,4.

3 OPERABLE - OPERABILITY 1.19 A system. subsystem, train.-component or device shall be OPERABLE or-have OPERABILITY when it is capable of performing its specified function (s), and when all necessary attendant instrumentation, controls, electrical _ power, cooling or seal water, lubrication or other auxiliary equipment that are-required for the

. system, subsystem, train, component, or device to perform its function (s) are also capable of performing their related support function (s).

COMANCHE PEAK - UNITS 1 AND 2 0-7 June 30, 1992

4 DEF1HITIONS

-OPERATIONAL MODI - MODE 1.20 An OPERATIONAL MODE (i.e., MODE) shall correspond to any one inclusive conbination of core reactivity condition, power level, and average reactor coolant tet arature specified in Table 1.2.

PHYSICS TESTS 1.21 PHYSICS TESTS shall be those tests performed to measure the fundamental nuclear characteristics of the reactor core and related instrumentation: (1) described in Chapter 14.0 of the FSAR, (2) authorized under the provisions of 10CFR50.59, or (3) otherwise approved by the Commission.

PRESSURE BOUNDARY LEAKAGE 1.22 PRESSURE BOUNDARY LEAKAGE shall be leakage (except steam generator tube leakage) through a nonisolable fault in a Reactor Coolant System component body, pipe wall, or vessel wall.

PRIMARY PLANT VENTILATION SYSTEM 1.23 A PRIMARY PLANT VENTILATION SYSTEM shall be any system designed and installed to reduce gaseous radiciodine or radioactive material in particulate form in effluents by passing ventilation or vent exhaust O

gases througn charcoal-adsorbers and/or HEPA filters for the purpose d of removing iodines or particulates from the gaseous exhaust stream prior to the release to the environment. Such a system is not considered to have any effect on noble gas effluents.

PROCESS CONTROL PROGRAM 1.24 ThePROCESSCONTROLPROGRAM(PCP)shallcontainthecurrent formulas, sampling, analyses, tests, and determinations to be made to ensure that-processing and packaging of solid radioactive wastes based on demonstrated processing of actual or simulated wet solid wastes will be accomplished in such a way as to assure compliance with 10CFR Parts 20, 61, and 71, State regulations, burial ground requirements, and other requirements governing the disposal of solid radioactive

-waste.

PURGE - PURGING 1.25 PURGE or PURGING shall be any controlled process of discharging air or gas from a confinement to_ maintain temperature, pressure, humidity, concentration or other operating condition, in such a manner that replacement air or gas-is required to-purify the confinement.

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DEFINITIONS OUADRANT POWER TILT RATIO 1.26 QUADRANT POWER TILT RATIO shall be the ratio of the maximum upper half excore detector calibrated output to the average of the upper half excore detector calibrated outputs, or the ratio of the maximura lower half excore detector calibrated output to the average of the lower half excore detector calibrated outputs, whichever is greater. With ono.excore detector inoperable, the remaining three detectors shall be used for computing the average.

RATED THERMAL POWER 1.27 RATED THERMAL POWER shall be a total reactor core heat transfer rate to the reactor coolant of 3411 MWt.

REACTOR TRIP SYSTEM RESPONSE TIME i

1.28 The REACTOR TRIP SYSTEM RESPONSE TIME shall be the time interval from when the monitored parameter exceeds its Trip Setpoint at the channel sensor until loss of stationary gripper coil voltage.

REPORTABLE EVENT ORTABLE EVENT shall be any of those conditions specified in b SHUTDOWN MARGIN 1.30 SHUTDOWN MARGIN shall be the instantaneous amount of reactivity l by which the reactor is subcritical or would be subcritical from its presentconditionassumingallrodclusterassemblies..(shutdownand control)arefullyinsertedexceptforthesinglerodclusterassembly of highest reactivity worth which is assumed to be fully withdrawn.

SITE BOUNDARY 1.31 The SITE BOUNDARY shall be that line as shown in Figure 5.1-3.

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DEFINITIONS ,

SLAVE RELAY TEST-1.32 A SLAVE RELAY-TEST shall-be the.energization of each slave-relayc and verification of-0PERABILITY of each relay. The SLAVE RELAY. TEST -

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shall include a cont 1nuity- check, as'a minimuin,'of associated testable actuation devices. ,

SOURCE CHECK 1.33 A SOURCE CHECK shall be the qualitative assessment-of channel 4 response when the channel sensor is exposed to a source.of increased radioactivity.

- STAGGERED TEST BASIS f 1.34 A-STAGGERED TEST BASIS shall consist of

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a, A test schedule for n systems, subsystems, trains,-or-other designated components obtained_by dividing the specified test:

interval-into n equal subintervals, and

b. The testing _of one system, subsystem,-train,,or oth'er

, designated component at the beginning of each subinterval.

I THERMAL POWER 1.35 THERMAL POWER shall.be the total-c' ore' heat transfer rate to the reactor coolant.

TRIP ACTUATING DEVICE OPERATIONAL TEST-1.36 A TRIP- ACTUATING DEVICE OPERATIONAL TEST shall: consist' of operating the Trip Actuating-Device and verifyirig OPERABILITY'of-alarm, interlock and/or trip ~ fun _ctions._1The TRIP ACTUATING DEVICE-OPERATIONAL TEST shall include adjustment,Jas necessary, of the Trip .

Actuating Device _ such that-it actuates at the required setpoint within the_ required accuracy.

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DEE1HIHONS UNIDENTIFIED LEAKAGE 1.37 UNIDENTIFIED LEAKAGE shall be all leakage which is not IDENTIFIED LEAKAGE or CONTROLLED LEAKAGE.

UNRESTRICTED AREA 1.38 An UNPESTRICTED AREA shall be any area at or beyond.the SITE BOUNDARY access to which is not controlled by the licensee, for purposes of protectir of individuals from exposure to radiation and radioactive materials, or any area within the SITE BOUNDARY used for residential quarters oi for industrial, commercial, institutional, and/or recreational pieposes, yENTING 1.39 VENTING shall be the controlled process of discharging air or gas from a confinement to maintain temperature, pressure, humidity, concentration, or other operating-condition, in such a manner that replacement air or gas is not provided or required during VENTING.

Vent, used in system names, does not imply a VENTING process.

WASTE GAS HOLOUP SYSTEM 1.40 A WASTE GAS HOLOUP SYSTEM shall be any system designed and (s

L) installed to reduce "adioactive gaseous effluents by collecting Reactor Coolant System offgases from the_ Reactor Coolant System and providing for delay or holdup for the purpose of reducing the total radioactivity prior to release to the environment.

CORE OPERATING LIMITS REPORT 8 1,41 The CORE OPERATING LIMITS REPORT (COLR) is the unit-specific 8 document that provides core operating limits for the current operating reload cycle. These cycle-specific core operating limits shall be determined for each reload cycle in accordance with Specification 6.9.1.6. Unit operation within these operating limits is addressed in individual specifications.

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-TABLE 1.1 r-'s FRE00ENCY NOTATION ty NOTATION FRE0VENCY S At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months .

D At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

W At least once ptr 7 days.

M At least once per 31 days.

Q At least once per 92 days.

SA At least once per 184 days.-

SR At least once per 9 months.

R At least once per 18 months.

S/U Prior to each reacter startup.

N.A. Not applicable.

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TABLE 1.2 OPERATIONAL MODES

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AVERAGE REACTIVITY % RATED COOLANT RQQL CONDITION. Kerr THERMAL POWER

TEMPERATURE

1. POWER OPERATION 1 0.99 > 5% 1 3500F

2. STARTUP 3 0.99 5 5% 1 3500F

3. HOT STANDBY < 0.99 0 1 3500F

4. HOT SHUTOOWN < 0.99 0 3500F>Tavg

> 2000F

5. COLD SHUTDOWN < 0.99 0 5 2000F

6. REFUELING ** $ 0.95 0 5 1400F

Excluding decay heat.

- Fuel in the reactor vessel with the vessel head closure bolts les:

, than fully tensioned or with the head removed.

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TECHNICAL REQUIREMENT 0.2 APPLICABILITY A

'i s~,) This Technical Requirement contains Section 3.0/4.0, APPLICABILITY, of the Technical Specifications, which are also applied to the Technical Requirements Manual except where otherwise specified. For-the purpose of this Technical Requirement, the Technical Requirements Manual terms specified below shall be conridered synonymous with the listed Technical Specification terms:

Technical Requirements Manual Technical Specifications OPERABILITY CRITERIA LIMITING CONDITION FOR OPERATION COMPENSATORY MEASURE ACTION TESTS / INSPECTIONS SURVEILLANCE REQUIREMENTS TECHNICAL REQUIREMENT SPECIFICATION NOTE: Although the CPSES Technical Specification is repeated here, in part, care must be taken not to overlook Technical Specification requirements.

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3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS .

p- 3/4.0 APPLICABILITY LIMITING-CONDITION FOR OPERATION 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 Operation and associated ACTION requirements are not met within the specified time intervals.

If the Limiting Condition for Operation is restored prior to expiration of the specified time intervals, completion of the ACTION requirements is not required.

3.0.3 When a Limiting Condition for Operation is not met, except as provided in the associated ACTION requirements, within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it,as applicable, in:

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a. At least HOT STANDBY within the next 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months ,

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

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

Where corrective measures are completed that permit operation under the ACTION requirements, the action may be taken in accordance with the specified time limits as measured from the time of failure to meet the Limiting Condition for Operation. Exceptions to these requirements are stated in the individual specifications.

This specification is not applicable in MODE 5 or 6',

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 they are not met within a specified time interval. Entry into an 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 iequirements are stated in the ildividual specifications.

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3/4 LIMITING CONDITIONS FOR OPERATION AND SURVEILLANCE REOUIREMENTS 8 3/4.0 APPLICABILIJJ 8 b- LIMITING CONDITION FOR OPERATION 8 3.0.5 Limiting Conditions for Operation including the associated 8 ACTION requirements shall apply to each unit individually unless otherwise indicated as follows:

a. Whenever the Limiting Conditions for Operation refers to 8 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 8 only one unit, this will be identified in the APPLICABILITY section of the specification; and

c. Whenever certain portions of a specification contain L operating parameters, setpoir- 5, etc., which are different for each unit, this will be 1dentified in parentheses, footnotes'or body of the requirement.

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L APPLICABILITY

SuitVEILL ANCE REOUIREMCNTS 4.0.1 Surveillance Requirements shall be met during the OPERATIONAL L MODES or other conditions.specified for individual Limiting Conditions for Operation unless otherwise stated in an individual Surveillance !

Requirentnt.

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4.0.2 Each Surveillance Requirement shall be perfor ,ed within the .I i specified surveillance interval with a maximum allowable extension not 1 to exceed 25% of the specified surveillance interval. !

i Exceptions to this requirement are stated in the individual l 1- specifications, e L !

! 4.0.3 Failure to perform a Surveillance Requirement within the 'I' i allowed surveillance interval, defined by Specitication 4.0.2, shall 3- constitute noncompliance with the OPERABILITY requirements for a i- Limiting Condition-for Operation. The time limits of the ACTION. .

requirements are applicable at the time it is identified that a j Surveillance Requirement-has not been performed. The ACTION '

j- requirements may be delayed for up to 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months to permit the .,

completion ?f the surveillance when 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 . Surveillance !

l Requirements do not have to be performed on inoperable equipment. !

4.0.4 Entry into an CPERATIONAL MODE or other specified condition i-O., ( J shallnotbemadeunlesstheSurveillanceRequirement(s) associated i

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! with the Limiting Condition for Operation has been performed within j

, the stated surveillance interval or as otherwise specified. This -i l provisions shall not prevent passage through or,to OPERATIONAL MODES 1 as required to comply with AC110N requirements. Exceptions to these

! requirements are stated in the individual specifications.. I

! 4.0.5 Surveillance Requirements for inservice inspection and testing:

i of ASME Code Class 1, 2 aM 3.compontents shall be applicable as-follows: 1 L {

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C0ttANCHE PEAK;- UNITS 1 AND'.2.

0 17

! lune 30, 1992?

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4 i

h NCLICABILITY j SURVEILLANCE REOUIREMENTS (Continued) l

a. Inservice inspection of'ASME Code Class 1, 2, and 3 I 1 components and inservice testing of ASME Code Class 1, 2, and .

fl 3 pumps and valves shall be performed in accordance with :

Section'XI of the ASME Boibr anc Pressure Vessel Code and - i applicableAddendaasrequiredby10CFR50.55a(g),except ;

j ;

! wherespecificwrittenreliefhasbeengrantedby(theCommissionpursuan *

! (g)(6)(1);

! t

b. Surveillance intcrvalt specified in Section XI of-the ASME i i Boiler and Pressure Vessel Code and applicable Addenda for i'

tne in:*rvice inspection and testing activities required by the ASML Boller and Pressure Vessel Code and applicable i i Addenda shall be applicable as follows in these Technical- i Specifications: l

[

ASME Boiler and Pressure Vessel Required frequencies for Code and applicable-Addenda- performing inservice

terminology for inservice inspection and testing l insoection and testino activitiei activities 7

[ Weekly -At least once per 7 days- .

j Monthly At least once per 31 days- [

Quarterly or every 3 months At least'once per 92~ days 1 Semiannually or every 6 months- At least once per 184 days Every 9 months At least-once per 276 days j

! Yearly or annually At least'once per 366 days

+

. c. The provisions of Specification 4.0.2 are applicable-to the :

above required frequencies for. performing inservice

inspection and testing activities;- ,

d. Performance of the above-inservice inspection and testing.

i activities shall be in addition to'other specified , -

Surveillance Requirements; and i

e. Nothing in the ASME Boiler and Pressure Vessel Code shall be- i 4 construed-to supersede the requirements of any Technical

, Speciflcation.

I c.

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- COMAN(.HE PEAK - UNITS 1 AND' 2 0-18 June-30, 1992-

. .u. __. .. _ . -w . w . ;u , .. _ , , .,.; - . .. . ; . J.: _ , - . . .u ., u - _,.-.~.,.-,,-..._...---,...,..,,,,--~;-,a

d 3/4 LIMITING CONDITIONS FOR OPERA 110N AND SURVEILLANCE RE0VIREMENTS 8 3/4.0 APPLICABILITY 8 .

BASES , 8 8

joecification 3.0.1 throuch 3.0.4 establish the general requirements 8 1 applicable to Limiting conditions for Operation. These requirements 1 i are based on the requirements for Limiting Conditions for Operatien statedin.10CFR50.36(c)(2):

" Limiting conditions for operation are the lowest functional 8

capability or performance levels of equipment required for safe

operation of the facility. When a limiting condition for 4 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 iret."

l Specification 3.0.1 establishes the Applicability statement within 8 eachindividualspecificationastherequirementforwhen(i.e.,in whichOPERATIONALMODESorotherspecifiedconditions)conformanceto the Limiting Conditions for Operation is-required for safe operation

of the facility. The ACTION requirements establish those. remedial 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 8

, 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 ss the ACTION requirements continue to be met. The second type of ACTION requirement specifies a time limit in which conformance to the conditions of the limiting Condition for Operation must bo mot. This time liiuit is the allowable outage time to restore an inoperable system or component to OPERABLE status or for restoring parameters within specified limits. If these actions are not completed within the allowable outage time limits, a shutdown is required to place the facility in a MODE or condition-in which.the specification no longer applies'. It is not intended that the shutdown 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 e components being inoperable.

The specified timi limits of the ACTION requirements are applicable 8 from the point in time it is identified that a Limiting Condition for Operation is not iet. The time limits of the' ACTION requirements are also applicable whtn a system or component is_ removed from service _for surveillance testing or. investigation of operational prob bms.

Individual specifications may include a specified-time limit for the cornpletion of n Surveillance Requirement when equipment is removed from service. In this case, the' allowable outage time limits of the U

COMANCHE PEAK - UNITS 1 AND 2 0-19 Revision 8 June 30, 1992

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

i APPLICABILITY 8 MSIS_

8 A 8 l Action requirements are applicable when this limit expires if the 8 .

surveillance has not been completed. When a shutdown is required to !

comply with ACTION requirements, the plant may have entered a H00E in i i which a new specification becomes applicable. In this case, the time l

limits of the ACTION requirements would apply from tla point in time !

I that the new specification becomes applicable if the iequirements of ,

the Limiting Condition for Operation are not met. !

Soecification 3.0.2 establishes that noncompliance with a 8 specification exists 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 1 ACTION requirements within the specified time interval constitutes ,

, compliancewithaspecificationand(2)completionoftheremedial j measures of the ACTION requirements is not: required when compliance with a Limiting Condition of Operation is restored within the time

! interval specified in the associated ACTION requirements.

i:

Soccification 3.0.3 establishes the shutdown ACTION requirements that I 8 ,

must be implemented when a Limiting Condition for Operation is not met - -4 i 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 i

! convenience which permits (routine) voluntary removal of redundant-

! systems or-components from service in-lieu of other alternatives that

would'not' result in redundant-systems or components being inoperable.

One hour is-allowed to prepare for an orderly shutdown before -

initiating a change in plant operation. This time permits the.

' operator to coordinate the'..ouction in electrical. generation with the load dispatcher to ensure that~ stability and availability of the

electrical grid. The time . limits specified.to reach lower MODES of operation permit the shutdown 'o proceed in a _ controlled and orderly manner that is well within-the specified maximum cooldown rate and 4 _w ithin the cooldown capabilities.of the facility assuming only the

!. minimum required equipment is OPERABLE. This-reduces thermal ' t

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

y b .

k COMANCHE PEAK - UNITS 1 AND 2 0-20' Revision-Bl 1 June 30, 1992

1 APPLICABILITY 8 BASES 8 I

If remedial measures permitting limited continued operation of the 8 i facility under the provisions of the ACTION requirements are

completed, the shutdown may be terminated. The time limits of the i ACTION requirements are applicable from the point in time there was a

failure to meet a Limiting Condition for Operation. Therefore, the shutdown may be terminated if the ACTION requirements have been met or the time limits of the ACTION requirements have not expired, thus

, providing an allowance for the completion of the required actions, l The time limits of Specification 3.0.3 allow 37 hours4.282407e-4 days 0.0103 hours 6.117725e-5 weeks 1.40785e-5 months for the plant to 8 be in the COLD SHUT 00WN MODE when a shutdown is required during the POWER MODE of operation, if the plant is in a lower MODE of operation when a shutdown is required, the time limit for reaching the next lower MODE of operation applies. However, if a lower MODE of operation is reached in less time than allowed, the total allowable

time to reach COLD SHUTDOWN. or other applicable MODE.-is not reduced.

' For example, if HOT STANDBY is reached in 3 hours3.472222e-5 days 8.333333e-4 hours 4.960317e-6 weeks 1.1415e-6 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 return to POWER operation, a penalty is not incurred by

having to reach lower MODE of operation in less than the total time allowed.

.O The same principle applies efth regard to the allowable outage time limits of the ACTION requireaeris, if compliance with the ACTION 8

requirements for one specification results in entry into a MODE or

, condition of operation for another specification in which the i requirements of the Limiting Condition for Operation are not met. If the new specification becomes applicable in less time than specified, the difference may be added to the allowable outage time limits of the 4

second specification. However, the allowable outage time limits of ACTION requirements for a higher MODE of operation may not be used to extend the allowable outage time that is applicable when a Limiting Condition for Operation is not met in a lower MODE of operation.

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

Specification 3.0.4 establishes limitations on MODE changes when a 8 ,

Limiting Condition for Operation is not met. It precludes placing '

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

)

I 1

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1 COMANCHE PEAK - UNITS 1 AND 2 0-21 Revision B June 30, 1992

~ ~ . . _

APPLICABillTY 8 BASES Limiting Condition for Operation are not met and continued 8 noncomsliance to these conditions would result in a shutdown to comply with tie ACTION requirements if a change in MODES were permitted.

The purpose of this specification is to ensure that facility 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 H0DE change.

Therefore, in this case, entry into an OPERATIONAL H0DE or other specified condition may be made in accordance with the provisions of the ACTION requirements. The provisions of this specification _should nut, however, be interpreted as endorsing the failure to exercise good practice in restoring systems or components tu OPERABLE status before plant startup.

When a shutdown is required to comply with ACTION requirements, the 8 provisions of Specif..:ation 3.0.4 do not apply because they would de'ay placing the facility in a lower H0DE of operation.

Soecification 3.0.E delineates the applicability of each specification 8

/ to Unit 1 and Unit 2 operation.

The valve identification numbers (tag numbers) contain a unit 8 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 utilize a convention of identifying valves; without the unit designatoi' if the remainder of the tag number is applicable to both units, with the unit designator if the. tag is

orly applicable to one unit.

I When a specification is shared per 3.0.5a, the ACTION section contains 8-theidentifier"(Units 1and2)".

I l

COMANCHE PEAK

UNITS 1 AND 2 0-22 Revision 8 June 30, 1992

APPLICABillTY 8 '

BASES 8

~

Specifications 4.0.1 thr_ough 4.0.5 establish the general requirements 8 applicable to Surveillance Requirements. These requirements are ,

based on the Surveillance Requirements stated in the Code of Federal Regulations,10CFR50.36(c)(3):

" Surveillance requirements are requirements relating to test, '8 ,

calibration, or inspection to assure that the necessary quality of systems and components is maintained, that facility operation will be within the safety limits, and that the limiting conditions of operation will be met."

Specification 4.0.1 establishes the requirement that surveillances 8 must be met during the OPERATIONAL MODES or other conditions for which the requirements of the Limiting Conditions for Operc', ion 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 Limiting Condition for Operation do not apply unless otherwise specified. The Surveillance Requirements ,

associated with a Special Test Exception are only applicable when the O- Special Test Exception is used as an allowable exception to the requirements of a specification.

Inecification 4.0.2 establishes the limit for which the specified time 8 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 tre performed at each refueling outage and are specified with an 18-month surveillance interval. It is not intended that this provision be used repeatedly as a convenience to extend surveillance intervals beyond that 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.-

COMANCHE PEAK - UNITS 1~AND 2 0-23 Revision 8 June 30,1992

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

i APPLICABILUX 8 BASES 8 :

3 O 8 Specification 4.0.3 establishes the-'ailure to perform a Surveillance 8 i Requirement within the allowed surveillance interval, defined by the ,

provisions of Specification 4.0.2, as a condition that constitutes a i failure to meet the OPERABILITY requirements for a Limiting Condition '

1

for Operation. Under the provisions of this specification, systems i and components are assumed to be OPERABLE when SurveillanM Requirements have been satisfactorily performed within tha specified 4

time interval. However, nothing in this provision is to be crnstrued

as implying that systems or components are OPERABLE when they are i 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 i in time it is identified that a surveillance has not been performed-and not at the time that the allowed surveillance interval was j exceeded.

Completion of the Surveillance Requirement within the allowable outage 8 i 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

O i

Specification 4.0.2, was a violation of the OPERABILITY requirements of a Limiting Condition for Operation that is subject to enforcement ,

4 action. Further, the failure to perform a surveillance within the provisions of Specification 4.0.2 is a violation of a Technical i Specification requirement and is, therefore, a reportable event under :

the requirements of 10CFR50.73(a)(2)(1)(B) because it is a condition prohibited by the plant's Technical Specifications.

If the allowable outage time limits of the ACTION requirements are 8 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-hour 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 conditicas, adequate planning, availability of personnel, the time required to-perform the surveillance, und 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 COMANCHE PEAK - UNITS 1 AND 2 0-24 Revision'8-

-June 30 1992--

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

APPLICABillTY 8 BASES a surveillance is not completed within the 24-hour allowance, the time 8 limits of the ACTION requirements are applicable at that time. When a surveillance is performed within the 24 hour2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months allowance, and the a

Surveillance Requirements are not mot, the time limits of the ACTION requirements are applicable at the time that the surveillance is terminated.

! Surveillance Requirements do not have to o'e performed on inoperable 8 j equipment because the ACTION requirements define the remedial measures t

that apply. However, the Surveillance Requirements have to be met to

demonstrate that inoperable equipment has been restored to OPERABLE status.

Specification 4.0.4 establishes the requirement that all applicable 8 surveillances must be met before entry into an OPERATIONAL MODE or ,

other condition of operation specified in the Applicability statement.

The purpose of this specification is to ensure that system and component OPERABILITY requirements or parameter limits are met before entry into a MODE or condition for which these systems and components

ensure safe operation of the facility. This provision applies to 8 changes in OPERATIONAL MODES or other specified conditions associated with plant shutdown as well as startup.

(j Under the provisions of this specification, the applicable 8 V Surveillance Requirements must be performed within the specified surveillance interval to ensure that the Limiting Conditions for Operation are met during initial plant startup or following a plant outage.

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

~'

Specification 4.0.5 establishes the requirement that inservice 8 inspection of ASME Code Class 1, 2, and 3 components and inservice.

testing of ASME Code Class 1, 2, and 3 pumps and valves shall be performed in accordance with a periodically updated version of Section XI of the ASME Boiler and Pressure Vessel Code and Addenda as required by 10CFR50.55a. These requirements apply except when relief has been provided in writing by the Commission.

This. specification includes a clarification of the frequencies for 8 performing the inservice inspection and testing activities required by Section XI cf 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.

.O G COMANCHE PEAK. . UNITS 1 AND 2 0-25 Revision 8 June 30, 1992

i i

APPLICABILITY 8 l 4

~ .!

BASES 8 i l

Under the terms of this specification, the more restrictive- 8 ;

requirements of the Technical Specification take precedence over the !

ASME Boiler and Pressure Vessel Ccde and applicable Addenda. The i requirements of Specification 4.0.4 to perform surveillance activities i before entry into an OPERATIONAL MODE or other specified condition

takes precedence over the ASME Boiler and Pressure Vessel Code l l provision which allows _ pumps and valves to be tested up to one week l t after return to normal operation. The Technical Specification !

i definition of OPERABLE does not allow a grace period before a.

component, that is not capable of performing its s ncified function, ;

is declared inoperable and takes precedence over tw ASE Boiler and ,

j Pressure Vessel Code provision which allows a valve to be incapable of >

j 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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COMANCHEPEAK-UNITS.1-AND2 0-26

" Revision 8- i June 30,:1992 -1

TECHNICAL REQUIREMENT 1.1 REACTOR TRIP RESPONSE T!HE 4

NOTE: This Technical Requirement contains the Reactor Trip Response Time Table, Although the CPSES Technical Specification is r repeated here, in part, care must be taken not to overlook l Technical Specification requirements.

9 5

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.J COMANCHE PEAK - UNITS 1 AND 2 1-1 June 30, 1992

3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 4 3.3.1 As a minimum, the Reactor Trip System instrumentation channels !

. and interlocks of Table 3.3-1 shall be OPERABLE. i APPLICABILITY: As shown in Table 3.3-1.* 8

ACTION

As shown in Table 3.3-1.

SURVEILLANCE REOUIREMENTS I

4.3.1.1 Each Reactor Trip System Instrumentation channel and interlock and the automatic trip logic shall.be demonstrated OPEP.ABLE by the performance of the Reactor Trip System Instrumentation Surveillance Requirements specified in Table 4.3-1.

. 4.3.1.2 the REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip function shall be deconstrated to be within its limit at least once per 18 months. Each test shall include at least one train such that both trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once every N times p

g 18 months where N is the total number of redundant channels in a specific Reactor trip function as shown in the " Total No. of Channels" column of Table 3.3-1.

1 Unit 2 requirements are effective upon issuance of the' Unit 2 8 operating license.

O COMANCHE PEAK - UNITS 1 AND 2 1-2 Revision 8 June 130, 1992

TECHNICAL REOUIREMENT 1.1 Table 1.1.1

() EEACIOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES RESPONSE TIME E.UNCTIONAL UNIT

1. Manual Reactor Trip N.A.

2. Power Range, Neutron Flux 5 0.5 second*

3. Power Range, Neutron Flux High Positive Rate N.A.

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

5. Intermediate Range, Neutron Flux N.A.

6. Source Range, Neutron Flux 5 0.5 second*

7. Overtemperature N-16 5 7 seconds *f

8. Overpower N-16 5 7 seconds *#

9. Pressurizer Pressure-Low 5 2 seconds

10. Pressurizer Pressure-High 5 2 seconds

() 11. Pressurizer Water Level-High N.A.

Neutron / gamma detectors are exempt from response time testir.g.

Response time of the neutron /ganne flux signal portion of the channel shall_be measured from detector output or input of first electronic

component in a channel.

fResponse time includes the thermal well response time.

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.O G

COMANCHE PEAK --UNITS.1 AND 2 1-3 June 30, 1992 - ,

TECHNICAL REOUIREMENT 1.1 (continued)

Table 1.1.1

REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT BLSEONSE TIME t

12. Reactor Cociant Flow-Low ,

i

a. SingleLoop(AboveP-8) 5 1 second

b. TwoLoops(AboveP-7andbelowP-8) 5 1 second

13. Steam Generator Water Level--Low-Low 1 ? seconds

14. Undervoltage - Reactor Coolant Pumps 1 1.5 seconds

- 15. Underfrequency - Reactor Coolant Pumps 5 0.6 second

16. Turbine Trip

a. Low Fluid Oil Pressure N.A.

b. Turbine Stop Valve Closure N.A.

17. Safety injection Input from ESF N.A.

18. Reactor Trip System Interlocks N.A.

19. Reactor Trip Breakers N.A.

20. Automatic Trip and Interlock Logic H.A.

BASES 1.1 REACTOR TRIP SYSTEM RESPONSE TIMES i

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

~

Technical Specifications. The measurement of response time at.the specified frequencies provides assurance that the Reactor trip

. actuation associated with each channel is. completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response times indicated as not applicaple. Response time may be demonstrated by any series of sequential, r'verlapping, or total channel test measurements provided that such tests demonstrate the total channel response time as-

+

defined. Sensor response time verification may be demonstrated by either:-(1)inplace,onsite,oroffsitetestmeasurements,or(2) utilizing replacement sensors with certified response time.

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L COMANCHE PEAK.- UNITS 1 AND 2 1-4 June 30, 1992-

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

TECHNICAL REQUIREMENT 1.2 ESF ACTUATION SYSTEM RESPONSE TIME NOTE: This Technical Requirement contains the ESF Actuation System Response Time Table. Alt'iough the CPSES Technical

O Specification is repeated here, in part, care must be taken not to overlook Technical Specification requirements.

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m COMANCHE PEAK - UNITS 1 AND 2. 1-5 .

. June-30, 1992 l- . . - . . :. . . , - , -,

. . - . - . . - . ~ . , , - .:--, . . . - .

k INSTRUMENTATijy!

3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 TheEngineeredSafetyfeaturesActuationSystem(ESFAS) instrumentation channels and interlocks shown in Table 3.3-2 shall be

OPERABLE with their Trip Setpoints set conststent with the values

, shown in the Trip Sctpoint column of Table 3.3-3.

APPLICABILITY: As shown in Table 3.3-2* 8 ACTION:

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

consistent with the Trip Setpoint value.

1

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

1. Adjust the Setpoint consistent with the Trip Setpoint value of Table 3.3-3 and determine within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months that Equation 2.2-1 was satisfied for the affected chtnnel, or 2

2. Declare the channel inoperable and apply the applicable ,

ACTION statement requirements of Table 3.3-2 until the channel is restored to OPERABLE status with its'Setpoint adjusted consistent with the Trip Setpoint value.

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

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

j.

Unit 2 requirements are effective upon issuance of the Unit 2 8 operating license.

O COMANCHE PEAK - UNITS 1 AND 2 1-6 Revision 8 June 30, 1992-

I INSTRUMENTAtlf)ff ACTION (Continued) ,

r

. f S= Either the "as measured" value (in percent span) of the sensor error, or the value from Column 5 (Sensor Error) of Table 3.3-3 for the affected channel, and TA = The value from Column TA (Total Allowance) of Table 3.3-3 for the affected channel. .

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

SURVEILLANCE REQUIREMENTS ,

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

4.3.2.2 The ENGINEERED SAFETY FEATURES RESPONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 months. Each test shall include at least one train such that >

both trains are tested at least once per 36 months and one channel per function such that all channels are tested at least once per H times 18 months where N is the total number of redundant channels in a specific ESFAS function as shown in the " Total No. of Channels" column of Table 3.3-2.

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v COMANCHE PEAK - UNITS 1 AND 2 1-7 m E 1992

TECHNICAL REOUIREMENT 1.2 j TABLE 1.2.1 l

[MINEERED SAFETY FEATURES RESPONSE TIMES f INITIATION StG9AL AND FUNCTION RESPONSE TIME IN SECONDS .

i

1. Manual Initiation

a. Safetyinjection(ECCS) N.A.

l

b. Containment Spray (Phast "B" i Isolation and Containment Vent i Isolation) N.A. ,

c. Phase"A" Isolation (Containment .

, VentIsolation) N.A.

i i d. Steam Line Isolation N.A.

e. FeedwaterIsolation(SI) N.A.

{

f. AuxiliaryFeedwater(SI) -N.A.

[

g. StationServiceWater(SI) N.A.

h. ComponentCoolingWater(SI) N.A.

i 1. Control Room Emergency Recirculation (SI) N.A. '

j. Reactor Trip H.A.

k. Emergency Diesel Generator Operation N.A.

1. Essentic.)VentilationSystems(SI) H.A.

m. Turbine Trip H.A.

1 i

O COMANCHE PEAK - UNITS 1 AND 2 1-8 June 30,'}992

..+,;.-.,---.-.:....,-.-.a.-. .

TECHNICAL REOUIREMENT 1.2 (continued)

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

2. Containment Pressure--High-1

a. Safety Injection (ERCS) 527(1.5a)/127(4,5b)] 8

b. Reactor Trip 52

c. Feedwater Isolation 16.5

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

e. Containment Ventilation Isolation N.A.

f. Auxiliary Feedwater [560] '8

g. Station Service Water N.A. '

h. Component Cooling Water N.A. l 1 Ess6ntial Ventilation Systems N.A. ,

i

j. Emergency Diesel Generator 5 12 Operation

k. Turbine Trip N.A. l

1. Control Room Emergency Recirculation N.A.

m. ContainmentSprayPump(7) 5 17/27 lO L

COMANCHE PEAK - UNITS l AND 2- 1-9' Revision 8 '

June 30, 1992 l

TECHNICAL REOUIREMENT 1.2 (cantinuedi TABLE 1.2.1 -

ENGINEERED SAFETY FEATURES RESPONSE TIMLS INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

3. Pressurizer Pressure--Low -

a. Safetyinjection(ECCS) 527(1.Sa)/[27(4,5b)) 8 i

b. Reactor Trip 52 I

c. Feedwater Isolatior. 57

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

e. Containment Ventilation Isolation [s5(6)] 8

f. Auxiliary feedwater [560] 8

g. Station Service Water N.A.

h. Component Cooling Water N.A.

i. Essential Ventilation Systems N.A.

j. Emergency Diesel Generator O Operation 5 12

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A. ,

m. ContainmentStrayPump(7) N.A.

O COMANCHE PEAK - UNITS 1 AND 2 1-10 Revision 8 June 30,: 1992 '

1 TECHNICAL REQUIREMENT 1.2 (continued)

TABLE 1.2.1 ENGlHEERED SAFETY FEATURES RESPONSE TIMES

!()

i INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

! 4. Steam Line Pressure--Low

a. Safetyinjection(ECCS) 537(3,5b)/27(4,5b)

b. Reactor Trip 52 .

! c. Feedwater Isolation [$ 6.5) 8 J d. Phase "A" Isolation 517(2)/27(1) )

1

e. Containment Ventilation )

Isolation N.A.

f. Auxiliary Feedwater [s 60) 8 f g. Station Service Water N.A. j

]

h. Component Cooling Water N.A.

i. Essential Ventilation Systems N.A.

j. Emergency Diesel Generator O Operation 5 12 3

k. Turbine Trip H.A, l 1. Control Room Emergency Recirculation N.A.

m. ContainmentSprayPump(7) N.A.

n. Steam Line Isolation [s 6.5) 8 1

i.

4 s

COMANCHE PEAK - UNITS 1.AND 2 1-11 Revision 8 June 30, 1992-

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

i TECHNICAL.REOUIREMENT1.2(continuedl TABLE 1.2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES

]

INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS

5. Containment Pressure--High-3

a. Containment Spray Pump H.A.

, i 4 b. Phase "B" Isolation N.A. l

c. Containment Spray Pump Discharge !

Valve [5119] 8

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

7. Steam Line Pressure - Negative Rate-High Steam Line Isolation [57] 8

8. Steam Generator Water Level - High-High

a. Turbine Trip N.A.

b. Feedwater Isolation 1 11

. 9. Steam Generator Water Level - Low-Low

- a. Motor-Driven Auxiliary Feedwater Pumps 5 60

b. Turbine-Oriven Auxiliary Feedwater Pump 's 85- 4

10. Loss-of-Offsite Power i

Auxiliary Feedwater- [ N . A'. ]' 8

~

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

i b.O 1 COMANCHE PEAK - UNITS 1 AND 2 1-12 -Revision 8 June 30, 1992 g ---w g e- p u+ y --g--- g ,, y e- g y-- -9 r- 9 y g+,-,y yy-- , ,y- r-w--+ r_ g

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

i TECHNICAL.RE0VIREMENT1.2(continuedl ,

j TABLE 1.2.1 1

ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONOS

12. RWS1 Level - Low-Low Coincident with j Safety injection j Automatic Initiation of ECCS 5 30 -

~

Switchover to Containment Sump 4 13. Loss of Power (6.9 KV and 480V Safeguards SystemUndervoltage)

, e. 6.9 KV Preferred Offsite Source [12(8)] 8 Undervoltage l

! b. 6.9 KV Alternate Offsite Source [52(8)] 8 '

Undervoltage

{ ^

c. 6.9 KV Bus Undervoltage [52(8)] _8

d. 6.9 KV and 480V Degraded Voltaga with Safety injection [s10(8.9)] 8 without Safety injection [563(8,9)] 8 $

lO 4 e. 480 V Low Grid Undervoltage [563(8,9)] 8

?

i i

e 4

W COMANCHE PEAK - UNITS 1 AND 2 1-33 Revision 8 June 30, 1992

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

. - - - . . . .- .. - ..-. ~

TECHNICAL RE0VIREM[NT 1.2 (cont inuedl TABLE 1.2.1 TABLE NOTATIONS

, (1) Diesel generator starting and sequence loading delays included.

(t) Diesel generator starting delay 021 included. Offsite power 1 available.

4 (3) Diesel generator starting delay included. Only centrifugal charging pumps are included.

(4) Diesel ger. orator starting and sequence loading delays DQ1 included. Only centrifugal charging pumps are included.

4 (Sa) Sequential transfer of charging pump suction from the VCT to

! the RWST (RWST valves open, then VCT valves close) is not 4 included.

(Sb) Sequential transfer of charging pump suction from the VCT to the RWST (RWST valves open, then VCT valves close) i:

included.

(6) Includes containment pressure relief line isolation only.

_ (7) Response Time limit is up through pump breaker closure onib Both times shown include sequencer loading delays and the larger number also includes diesel generator starting delsy.

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

(9) Two a6ditional seconds allowable for alternate cffsite source breaker trip functions.

1.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM RESPONSE TIMES The bsses for the Engineered Safety Features Actuation System are contained in the CPSES Technical Specifications. The measurement of response time at the specified frcquencies provides assurance that the Engineered Safety Features actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses-for those channels with response times indicated as not applicable. Response' time may be demonstrated by any series of sequential, overlapping, or total channel test-measurements provided that such tests demonstrate the total-channel response time as defined. Sensor. response time verification may be demonstrates iy either. (1) in place, onsite, or offsite test measurements,or(2)utilizingreplacementsensorswithcertified response time.

J COMANCHE PEAK - UNITS-1 AND 2 1-14 June 30, 1992-

j TECHNICAL RE0VIREMENT 1.3 MOVABLE E DRE~DETEC10RS OPERASILITY CRITERIA 1.3 The Hovabic Incore Detection System shall be OPERABLE with:

a. At least 75% of the detector thimbles, '

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

c. Sufficient movable detectors, drive, and readout equipment to map these thimbles.

4 APPLICABILITY: When the Movable Incore Detection System is vsed 8 4

for*:

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

b. Monitoring the OVADRANT POWER TILT RATIO, or c.- Measurement of FjH FQ (Z) and Fxy.

COMPENSATORY MEASURES:

, With the Movable Incore Detection System Inoperable do not use.the 3 system for the above applicable monitoring or calibration functions.

The provisions of Technical Requirement 0.2 Operability Criteria 3.0.3 3 2 and 3.0.4 are not applicable.

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

- required detector and determining the acceptability of its voltage curve when the system is required for:

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

b. Monitoring the QUADRANT POWER TILT-RATIO, or

c. MeasurementofFfH,f(Z)andFxy. Q BASES j

1.3- MOVABLE INCORE DETECTORS The OPERABILITY of_ the movable incore detectors with'the specified minimum complement of equipment ensures that the measurements obtained~

from use of this system accurately represent the spatial neutron flux

. distribution of.the core. The OPERABILITY of this system is demonstrated by irradiating each detector used and determining the acceptability of its voltage curve.

Unit 2 requirements are effective upon issuance of.the Unit 2 8-

. operating license.

i .

COMANCHE PEAX - UNITS-1 AND 2 1-15 Revision 8

i. June 30, 1992 -

- . , , ,c.w,.-..e,s_--. ,,=7m,me.-.r.~, m..- - -- -u ., .y y - , .,

TECHNICAL REOUIREMENT 1.3 (continued 1 MOVABLE INCORE DETECTORS SASES(continued O __

ForthepurposeofmeasuringF(Z)orFfgafullincorefluxmap Q is used. Quarter-core flux maps, as defined in WCAP_8648, June 1976, -

may be used in recalibration of the Excore Neutron Flux Detection System, and full incore flux maps or symmetric incore thimbles may be used for monitoring the QUADRANT POWER TILT RATIO when one Power Range channel is inoperable.

O o

COMANCHC PEAK - UNITS 1 AND-2 1-16 June 30,:1992 l

TECHNICAL REQUIREMENT 1.4 SEISMIC INSTRUMENTATION 4

i OPERABillTY CRITERIA 1.4 The seismic monitoring instrumentation shown in Table 1.4.1 shall be OPERABLE. '

APPLICABILITY: At all times.* 8 COMPENSATORY MEASURES (UNITS 1 AND 2h 8

a. With one or more of the above required seismia monitoring instruments inoperable for more than 30 days, prepare and submit a Special Report to the Commission pursuant to CPSES Technical Specification 6.9.2 within the next 10 days 3

outlining the cause of the malfunction and the plans for restoring the instrument (s) to OPERABLE status.

I

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 4

shall be demonstrated OPERABLE by the performance of the i CHANNEL CHECKr CHANNEL CAllBRATION, and ANALOG CHANNEL OPERATIONAL TEST at the frequencies shown in Table 1.4.2.

TRI.4.2 Each of the above required seismic monitoring. instruments which is accessible during power operations and which is 4

actuated during a seismic event greater than.or equal to 0.019 shall be restored to OPERABLt status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 15 days following the seismic event. Data shall be retrieved from

. actuated instruments and analyzed to determine the magnitude of the vibratory grouno 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 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 CALIBRATION performed thc next time the plant enters MODE 5 or below, A supplemental report shall then be prepared and s.bmitted to the Commission within=14 days pursuant to CPSES Technical Specification 6.9.2 describing the additional.

data from these instruments,

Unit-2 requirements are effective upon issuance of the Unit 2 8 l

' operating license. '

COMANCHE PEAK - UNITS 1 AND 2 1-17 Revision 8 June 30, 1992-

-~ - - - - - ,-,

TECHNICAL REOUIREMENT 1.4 (continued)

TABLE 1.4.1 SEISHIC MONITORING INSTRUMENTATION

MINIMUM INSTRUMENTS INSTRUMENTS AND SENSOR LOCATIONS OPERABLE

1. Triaxial Time-History Accelerographs

a. Accelerometer-Fuel Building 1

b. Accelerometer-Unit 1 Containment 1 8

c. Accelerometer-ElectricalManhole(Yard) 1 8

d. Seismic Trigger-Fuel Building 1** 8 l

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

f. PlaybackUnit.SMP-1(Unit-1ControlRoom) 1 8 ,

2. Triaxial Peak Accelerographs

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

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

c. CCWHeatExchanger(AuxiliaryBuilding) 1 8

3. Triaxial Seismic Switch Fuel Building 1** 8

4. Triaxial Response-Spectrum Recorders

a. Fuel' Building 1

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

c. Unit 1 Safeguards Building 1 8

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

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

- With control room indication. 8 O

O COMANCHE PEAK - UNITS 1 AND 2- 1 Revision 8 June 30,1992

TECHNICAL REQUIREMENT 1.4 (continued)

TABLE 1.4.2 7'~T

4 SEISMIC MONITORING INSTRUMENTATION SURVElltANCE REOUIREMENTS

ANALOG **

CHANNEL CHANNEL CHANNEL OPERATIONAL CAllBRATION INSTRUMENTS AND SENSOR LOCATIONS CHECK TEST

1. Triaxial Time-History Accelerographs

a. Accelerometer-Fuel M R SA Building

b. Accelerometer-Unit 1 M R SA 8 Containment

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

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

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

~ gl% Playback Unit, SMP-1 d kg f.

(Unit 1 Control Room)

M R SA 8

E j 2. Triaxial Peak Accelerographs

a. Pressurizer Lifting H.A. R N.A. 8 4 Trunion - Unit 1 Containment 8

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

Unit 1 Containment 8

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

Auxiliary Building 8

.] 3. Triaxial Seismic Switch

Fuel Building *** M R -SA 8

Unit 1 and Unit 2 control room alarms are connected to shared seismic 8 instruments which cr* located in Unit 1 and conson structJres.

- Setpnint verification is not applicabit. 8

- - With control room indication. 8

.3 fu,l COMANCHE PEAK - UNITS 1 AND 2 1-19 Revision 8 June 30, 1992

TECHNICAL RE0VIREMEyT_,1.4-(continued)

TABLE-1.4;2 SEISMIC MONITORING INSTRUMENTATION SURVElllANCE RE0VIREMENTS*

()T ANALOG **

CHAWNEL CHANNEL CHANNEL OPERATIONAL 1!Lbst aC AND F2NSOR LOCATIONS CHECK CA1,lBRATION TEST

4. Triaxial Response-Spectrum Recorders

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

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

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

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

.A

. \m >

Unit 1 and Unit 2 control room alarm 3 are connected to shared seismic 8 instruments which are located in Unit 1 and common structures.

- Setpoint verification is not applicable. 8

- - With control room indication. 8 N.j COMANCHE PEAK - UNITS 1 AND 2 1-20 Revision 8-June 30, 1992 o

BASES 1.4 SEISMIC INSTRUMENTATION

( The OPERABILITY of the-seismic instrumentation ensures that sufficient i capability is available to promptly~ determine the magnitude of a seismic event and evaluate the response of those features importe.nt to safety. This capability is required to permit comparison of the measured response to that used in the design basis for the facility to determine if plant shutdown is required pursuant 1to Appendix A of 10CFR100. The instrumentation is consistent with the recommendations of Regulatory Guide 1.12. " Instrumentation for Earthquakes,"' April 1974.

4 E

4 i

i 1

r3

, ).

COMANCHE PEAK'- UNITS 1 AND 2. 1-21 June 30, 1992

TECHNICAL REOUIREMENT 1.5 LOOSE-PART DETECTION SYSTEM f'1 OPERABILITY CRITERIA iV 3 1.5 The Loose-Part Detection System shall be OPERABLE.

APPLICABILITY: MODES 1 and 2.* 8 COMPENSATORY MEASURES:

a. With one or more Loose-Part Detection System channels inoperable for more than 30 days, prepare and submit a Spe-ial Report to the Commission pursuant to CPSES Technical

Specification 6.9.2 within the next 10 days outlining the cause of the malfunction and the plans for restoring the channel (s) to OPERABLE status.

I

b. The provisions of Technical Requirement 0.2 Operability 3 Criteria 3.0.3 and 2.0.4 are not applicable.

. TESTS / INSPECTIONS- . _ .

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

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

O b. An ANALOG CHANNEL OPERATIONAi. TEST

at least once per 31 days, and

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

Setpoint verification is not applicable.

BASE 3 s

1.5 LOOSE PARTS DETECTION SYSTEM The OPERABILITY of the Loose-Part Detection System ensures-that sufficient capability is available to detect loose metallic parts ~in the Reactor System and avoid'or mitigate damage to Reactor System components. The allowable out-of-service times and surveillance requirements are-consistent with the recommendations _of Regulatory Guide 1.133, " Loose-Part Detection Program for the Primary System of Light-Water-Cooled Reactors," May 1981.

()

/- ~

Unit 2 requirements are effective upon issuance of the Unit 2 8-operating license.

COMANCHE PEAK -' UNITS 1 AND'2 1-22 Revision 8-June 30, 1992

~ - ,

TECHNICAL REQUIREMENT 2.1 CONTAINMENT ISOLATION VALVES fT - NOTE: This Techr.lcal Requirement contains the listing of Containment

\- / ' Isolation Valves,;and their respective testing requirements, which are subject to CPSES Technical Specification 3.6.3.

Although the Technical Specification is repeated here, care must be taken not to overlook Technical Specification-requirements.

1 4

4 0

O e

i

[ ,

\J COMANCHE PEAK - UNITS 1 AND 2 2-1 June 30,1992

CONTAINMENT SYSTEMS b 3/4.6.3 CONTAINMENT ISOLATION VALVES ,

1 LIMITING CONDITION FOR OPERATION 3.6.3 The containment isolation valves shall be OPERABLE.I APPLICABILITY: MODES 1 2, 3, and 4. ## 8 ACTION:

With one or more of the_ containment isolation valve (s) inoperable, maintain at least one isolation valve OPERABLE in each affected penetration that is open and:

a. Restore the inoperable valve (s) to OPERABLE status within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months , or

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

c. Isolate each affected penetration within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least one closed manual valve or blind flange, or

'( '

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

SURVEILLANCE REOUIREMENTS 4.6.3.1 The containment isolation valves shall be oemonstrated OPERABLE prior to returning the valve to service after_ maintenance, repair or replacement work is performed on the valve or its associated actuator, control or power circuit by performance of a cycling test, and verification of isolation time, I

The requirements of specification 3.6.3 do not apply for those valves covered by Specifications 3.7.1.1,'3.7.1.5, 3.7.1.6 and 3.7.1.7.

1. Unit 2 requirements are effective upon issuance of the Unit 2 8 operating license.

CAUTION: The inoperable isolation valve (s) may be part of a system (s). Isolating the affected penetration (s) may affect the

('))

x_ - use of the system (s). Consider the technical specification requirements on the affected system (s) ar.d act accordingly.

COMANCHE PEAK - UNITS l'AND 2 2-2 Revision 8 June 30, 1992

CONTAINMENT SYSTEMS

\_/ SURVEILLANCE REOUIREMENTS (Continued) 4.6.3.2' Each containment isolation valve shall be demonstrated OPERABLE during the REFUELING MODE or COLD SHUTOOWN at_least once per 18 months by:

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

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

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

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

i L/9 Q

,V-('l COMANCHE PEAK - UNITS 1 AND 2 2-3 June 30. 1992~

-TECHNICAL L REOUIREMENT-2:1'(continued)!

1-

-< TABLE 2.1.1'(continued)

! CONTAINMENT ISOLATION VALVES 'i

~

MAXIMUM-. _

ISOLATION ~ NOTES AND-

FSAR TABLE '

. TIME . LEAK TEST. - ,

-VALVE NO. REFERENCE NO.* LINE OR' SERVICE --(Seconds) RE0UIREMENTS' s-t

1. Phase "A" Isolation ~ Valves HV-2154 20 feedwater Sample 5 N.A. 8 f (FW to Stm Gen #1)-

i HV-2155 22 Feedwater Sample -.. 5 N.A. 18.

l (FW to Stm Gen-#E) 5 HV-2399 27 Blowdown From: Steam- 5 - N . A =. 8 Generator.f3 I HV-2398 28 -Blowdown From Steam-- ;5 N.A. .8 Generator-#2 p 1 HV-2397 29' Blowdown From Steam .

5 N.A.= 8' Generatorif1-i

-HV-2400 30 Blowdown Froni Steam 25 N.A. 8 g Generator #4 8152 32 ' Letdown Line:to 10 C 84

,. Letdown Heat l Exchanger-j :- 8160 32 Letdown 'Line to'

.10 ?- CL 8 Letdown Heat--

Exchanger _.

8890A 35 'RHR-to-Cold Leg- '15- -

C 8-LLoops #1 & #22 Test Line 88908 36 RHR to Cold Leg- 15 C 8-

-Loops #3:& #4-Test.Line:

8047 41 -Reactor-MakeJp-. .10 C' 8

' Water to Pressure Relief Tank'& RC

' Pump. Stand: Pipe-

.8843 42 SI:-to'RC-System

-10 N.A. '8

. Cold. Leg: Loops.#1,:

2, #3,.f4. Test Line-

' :V .:p r

COMANCHE-PEAK - UNITS 1 AND 2 2-4 Revision-8

. June 30, 1992

-2.

d

. TECHNICAL- ' RE0VIREMENT - 2.1 : (cont inued) .

l TABL(-2.1'.1-(continued) -

~

' CONTAINMENT ISOLATION VALVES

~

4 MAXIMUW L : ISOLATION.- NOTES AND--

,_ _ FSAR TABLE . _ TIME.. LEAK-TEST-

VALVE NO. REFERENCE NO.* LINE OR SERVICE _(Seconds _), BEOUIREMENTS i k 1. Phase "A" Isolation Valves

- 8881 43 SI to RC System .10 L N.A. -8 Hot Loops #2_&: .

3 Test Line- ! 8824 44 SI to RC System 10- N.A. ~8 ,

i Hot Leg loops #1 &

l- #4 Test Line 2 l 8823 _45 L . SI to:RC System. 10~ N.A. -8

(- Cold Leg Loops #1', m~

2, #3 &!i4 Test Line t 2

[

j- 8100 :51 - Seal Water Return -10 C 18 ~-

and Excess Letdown:

i 8112 51 Seal-Water Return 10i C .8 l - and Excess Letdown-h' 7136 52 RCDT Heat Exchanger 10E C_ 8 to_ Waste Hold Up Tank-

. LCV-1003 52- RCOT-Heat; Exchanger 10_ C toWasteHoldUpTankt

HV-5365- 60 - Demineraliz'ed Water. 5= C. - 8? '

. Supply _ -

HV-5366 60- DeSineralized Water- -:5 __ C - '8.

Supply-HV-5157: 61: - Containment Sump:

~

5. C. 8.

j Pump ~ Discharge;

HV-5158 61 Containment' . 5 '- _C_' 8E

.. Sump Pump.

l HV-3487' 62 Instrument Air. 5 C. '81 -

F to:Containmenti f

JOL

COMANCHE PEAK - UNITS 1 AND 2 .

2-5 Revision'8-

' June 30,-1992:

2 re ,v, a.- , ,,,e, ,-4n.,.,,,,, - , , ,, , . , ~ ~ . e , .w , e o~ ', , - + - , n ...,.,.an.o , - , n u- a ,,,,,--....~is. .:d , e , - . ~ . - , , , . - - - , .

TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE 2.1.1 (continued).

O b CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE- TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVItt (Seconds) REQUIREMENTS

1. Phase "A" Isolation Valves (Continued) 8825 63 RHR to Hot Leg Loops 15 C 8

2 & #3 Test Line HV-2405 73 Sample from Steam 5 N.A. 8 Generator #1 HV-4170 74 RC Sample From 5 C 8 Hot Legs HV-4168 74 RC Sample From 5 C 8 Hot Leg #1 HV-4169 74 RC Sample From 5 C- 6 Hot Leg #4 g) HV-2406 76 Sample from Steam Generator #2 5 N.A.- 8 HV-4167 ,, Pressurizer Liquid 5 C 8 Space Sample HV-4166 77 Pressurizer Liquid 5 C 8

_ Space Sample HV-4176 78 Pressurizer Steam 5 C 8 Space Sample HV-4165 78 Pressurizer Steam 5 C 8 Space Sample HV-2407 79 Sample From Steam 5' N.A. 8 Generator #3 HV-4175 80 Accumulators 5 C 8 HV-4171 80 Sample From 5- C 8 Accumulater #1

}

\__/

COMANCHE PEAK - UNITS 1 AND 2 2-6 Revision 8 Jane 30, 1992

s- .. . . . . _ . . . _ . _ ._

L F TECHNICAL. RE0VIREMENT 2.1-(continued) t I

IM LE 2.1.1 (continued)' q h . CONTAINMENT ISOLATION-VALVES j HAXIMUM. -i

ISOLATION ~ NOTES AND-- .i-i FSAR: TABLE TIME :LEAX TES1' VALVE NO.- REFERENCE NO.* LINE OR' SERVICE:.. (Seconds)- RE_0UIREMENTS - ,,

1. Phase"A":IsolationLValves(Continued)-

I HV-4172 : 80 Sample From 5 C- 18 d

Accumulator #2'

!~- -

HV-4173 80 Sample From- 5 .C -- - 8 _--

' Accumulator #3 l- HV-4174 80 Sample From- 5' C 8

-Accumulator-#4-i': HV-7311 81 RC_ PASS: Sample 5 C. 8 i- Discharge to.RCOT-i .. 'HV-7312~ 81 -RC PASS Sample'. 5 C 8 [

'; ' Discharge.to;RCOT--_

l HV-2408- 82 . Sample from-Steam: .' N . A .- 8.

1- Generator-.#41 8871 83 Accumuletor Test 10 C- 8-and Fill

8888 83 : Accumulator Tert 10 C -8 l- and Fill--

i 8964 - 83 Accumulator 1 Test __ 10 -- .C- 8

- and Fill-V ,

.HV-5556 84. Containment Air _.- 5- C 8 PASS:-Return'

$ HV-5557 84 Containment = Air- 5 0 .8-

-PASS Return-

. HV-5544 94 15- C --

~Monitoring Radiation; Sample ~ z 8-i: HV-5545 Radiation. 5- C- 8-4 Monitoring' Sample c

! HV-5558 97 ' Containment Air: 5 C- -8' i

+

PASS' Inlet 1

COMANCHE PEAK - UNITS 1 AND 2g _2 Revision 8:

n -

Junes30,e1992 '

L --. - L. - . . - . - - . .. .. - , ,,. - . - . . ~ . - , - . . - - . - . - ... - - - - . :..

TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE-2.1.1-(continued)

(3

(_,) CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REOUIREMENTS

1. Phase"A"IsolationValves(Continued)

HV-5559 97 Containment Air 5 C 8 PASS Inlet HV-5560 100 . Containment Air 5 C 8-PASS Inlet HV-5561 100 Containment Air 5 C 8 PASS Inlet HV-5546 102 Radiation Monitore 5 C 8 ing Sample Return HV-S547 102 Radiation Monitor- 5 C 8-ing Sample Return 8880 104 N2 Supply to 10 8

()

,_ C Accumulators 7126 105 H2 Supply to 10 C 8 RC Drain Tank-7150 105 ,

-H2 Supply to 10 C R. Drain Tank HV-4710 111 CCW Supply to 5 N.A. 8 Excess Letdown

. & RC Drain Tank Heat Exchanger HV-4711 112 CCW Return From 5- N.A. 8 Excess Letdown &

RC Drain Tank' Heat Exchanger HV-3486 113 Service Air 5 C 8 to Containment l

/^' l k )\ l COMANCHE PEAK - UNITS 1 AND 2 2-8 Revision 8-June 30, 1992:

l-i :- .,

4 TECHNICAL REQUIREMENT 2.1L(continued)

-TABLE 2il 1EIcontinued)

CONTAINMENT ISOLATION VALVES -

MAXIMUM _ .

~1 SOLATION NOTES AND ,

I . . . FSAR TABLE . - -

-- TIME-: - LEAK =. TEST

! - VALVE NO. REFERENCE NO.*- LINE OR SERVICE -(Secondsi REOUIREMENTS

+

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

i HV-4725 114 Containment'CCWL -- 5 C' 8' t Drain Tank Pumps

j. . Discharge-

!: HV-4726 '114 Containment CCW 5- C 8' :

Drain Tank: Pumps =

l- discharge 8027- 116 Nitrogen. Supply- T10 - -C- = 81

to PRTL 1 ..

8026 116 Nitrogen Supply 210 C- 8

-to PRT.-

- HV-6084 120 Chilled-Water- 10 C- 8:

I~ Supply to Contain-ment Coolers HV-6082 121 -Chilled Water 10 C -8 *

[ Return From- ;

Containment Coolers _

l- HV-6083 12L : Chilled Water--- L10 -- C -- :8 -

. Return From'

Containment 1 Coolers-r l HV-40758 124 Fire Protection 1 -10: :

C- "8-

, System Isolation b HV-4075C- 124 Fire Protection '10_

C~

8)

System Isolation

~

4 i 2.-Phase "B" Isolation Valves g

n HV-4708 :117 .CCW: Return From 15 C- 8:

! RCP'S; Motors:

e . HV-4701 -117' CCW Return From_- l: 15 -- 'C '81 i '

RCP 's.. Motors -

F HV-4700 118- CCW Supply _to C 8L C RCP.'s' Motors -

ji

{

COMANCHE' PEAK -TUNITS'1:AND 2-9 LRevision 8.- -

June 30,:1992-

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

TECHNICAL RE0VIREMENT.2.1 (continuedl TABLE 2.1.1 (continued) rh

' i s_ ,) CONTAINMENT ISOLATION VALVtS MAXIMUM ISOLATION ~ NOTES AND FSAR-TABLE: TIME- LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) RE0VIREMENTS 2.-Phase "B" Isolation (continued)

HV-4709 119 CCW Return From 15 C 8 RCP's Thermal Barrier HV-4696 119 CCW Return From 15. C 8 RCP's Thermal Barrier

3. Containment Ventilation Isolation Valves HV-5542 58 Hydrogen Purge N.A. C l' '8 Supply HV-5543 58 Hydrogen Purge N.A. C 8 Supply-(~

' As)

HV-5563 58 Hydrogen Purge N.A. 'C- 8 Supply HV-5540 59 Hydrogen Purge N.A. C 8 Exhaust-HV-5541 59 Hydrogen Purge N.A. C 8 Exhaust HV-5562 59 Hydrogen Purge N.A. C 8 Exhaust HV-5536 109 Containment Purge 5 _C 8 Air Supply HV-5537 109 Containment Purge 5- C 8 Air Supply-HV-5538 110 Containment Purge 5 0 8 Air Exhaust.

HV-5539 110 Containment Pu,ge 5- C 8 Air Exhatst h(m-COMANCHE PEAK : UNITS 1 AND 2 2-10 Revision 8 June 30, 1992

TECHNICAL REOUIREMENT 2.1 (continued)

TABLE 2.1.1-(continued)

()

L/ CONTAINMENT ISOLATION VALVES-MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST

' VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) RE0UIREMENTS 3.ContainmentVentilationIsolationValves(Continued)

HV-5548 122 Containment 3 C 8L Pressure Relief HV-5549 122 Containment 3 C 8 Pressure Relief

4. Manual Valves MS-711# 4a TDAFW Pump Bypass N.A. N.A. 8 Warm-up Valve MS-390 Sa N2 Supply to Steam N.A. N.A. 8 Generator #1 MS-387 9a N2 Supply to-Steam- N,A. N.A. 8 Generator 12 g)

\,

MS-384 13a N2 Supply to Steam 'N.A. N.A. 8 Ger+rator #3 MS-712# 17a TDAFW Pump Byoass N.A. H.A. 8 Warm-up Valve MS-393 18a N2 Supply to Steam Generator #4 -

N . A. _ H.A. l8 FW-106 20b N2 Supply to Steam N.A. LN.A. 8 Generator #1-FW-104 22b N2 Supply to Steam N.A. N.A.

l.8 Generator #2 FW-102 24b N2 1upply to Steam N.A. N.A. 8 Generator-#3 FW-108 26b N2 Sunoly to Steam N.A. N.A. -8 Generu.or #4 7135I 52 RCDT Heat Exchanger N.A. C- 8

'to Waste Holdup Tank O

O \

L COMANCHE PEAK - UNITS 1 AND 2 2-11 Revision 8-l June 30,.1992-

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

i-

-TECHNICAL'REOUIREMENT 2.1 (continuedl- #

-TABLE 2.1.1-(continuedL CONTAINMENT, ISOLATION VALVES

, MAXIMUM _ . . .

ISOLATION NOTES AND !

FSAR TABLE ' TIME - - LEAK TEST-

VALVE NO. REFERENCE NO.* LINE-OR SERVICEJ (Seconds) -RE0UIREMENTS-

4. Manual _ Valves (Continued) 3 SF-011 55 -

Refueling Water _ lN.A. 'C 8. l Purif_ication to: :

Refueling Cavity; ,

SF-012 56 Refueling Water' 'N.A.- C 8

,. Purification to :

Refueling Cavity-

SF-021 67 Refueling Cavity- N.A. -C 8 to Refueling; Water:

Purification Pump; ,

-SF-022 67 Refueling Cavity N . A '.- C 8-

-to Refueling. Water l Purification _ Pump; 71 (Refueling _ Cavity: 8- i i -

(SF-053 N . A .' C)

Lg Skimmer Pump; l~'

Discharge l

[SF-054 71 Refueling Cavity N . A'. - C] 8 >

L. Skimmer Pump.

Discharge.

SI-8961# -83 Accumulator =Te:t' TN.A. N.A. -- 8 and Fill ,

3 l

j HV-2333B# 2 MSIV Bypass.from

. N . A , .. Note Is 8

.-Steam Generator #1 -

HV-2334B#: 7- -MSIV Bypassifrom __ ;N. A.-. : Note'li .8 s

. Steam Generator #2 HV-2335Bf 11 MSIV; Bypass fr.om N.A. Note 1-. 8 Steam Generator #3 HV-2336B# 15 -MSIV-Bypass from. H.A. Note.1 8 -

4 Steam Generator #4-

-COMANCHE PEAK - UNITSLIIAND-2 _2-12 : -Revision 8

, -June 30,-1992i n _m2._ - . _ _ _ . x ,_; _ . _ . . - . . . . . _ , -..._..m . _._ _ ..,._.. . .. ..m __ a

TECHNICAL. RE0VIREMENT 2.1 (continued)-

TABLE 2.1.1 (centinued)

(QNTAINMENT ISOLATION VALVES MAXIMUM-ISOLATION -NOTES .'JD FSAR TASLE TIME - LEAK TEST VALVE NO. BFFERENCE NO 2

LINE OR SERVICE 11econds) RE0VIREMENTS ;

4. Manual Valves (Continued) 185 0016# 130 Airlock Hydraulic N.A. N.A. 6

, System 6 185-0017# 130 Airlock Hydraulic H.A. N.A. 6 System 6 1BS-0030# 131 Airlock H.A. Notes 6 Hydraulically 5, 6, 7_ 6 Operated: Equalization 6 18S-0025# 131 Airlock N.A. Notes 6 Hydraulically 5,6,7 6 Operated Equalization 6 1BS-0056i 131a Airlack Manual N.A. Notes 6 Equalization. 5, 6 T

\

185-0044# 131a Airlock Manual N . A.- Notes i Equalization 5, 6 6 1BS-0029# 131a Airlock Manual N.A. hotes 6 Equalization 5, 6 6 18S-0015# 131a Airlock Manual N.A. Notes 6 Equalization 5, 6 6 BS-0202# 132 Airlock Manual N.A. Notes 8 Equalization 5, 6, 7 -

6 BS-0203# 132 Airlock:. Manual N.A. Notes 8 Equalization 5, 6, 7- 6 285-0016# 133 Airlock Hydraulic N.A. Notes 8 System- 5, 6 8 2BS-0017# 133 Airlock Hydraulic N.A. ,

Notes 8 System 5, 6 28S-0039# 133 Airlock Hydraulic N.A. Notes C

_ System- 5, 6- -8 285-0040# 133 Airlock Hydraulic- N.A. Notes 8 System 5,- 6 8 COMANCHE PEAX - UNITS 1 AND~2 2-13 Revision 8-June 30, 1992 s , y % - ..y , --,en, ,

TECHNICALRE0VIREMENT 2.1 (continuedV TABLE 2.1.1 (con 11nued) b CONTAINMENT ISOLATION VALVES MAXIMUM' ISOLATION NOTES AND--

FSAR TABLE - TIME ~ LEAK TEST _ .

VALVE NO. REFERENCE NO.* LINE OR SERVICE;'LSeconds) REOUIREMENTS 285-0030# 134 Airlock N.A. Notes 8 Hydraulically 5,6,7 8 d

Operated Equalization 8 ,

2BS-0025# 134 Airlock N.A. Notes 8 Hydraulically 5,6,7 8 Operated Equalization 8 28S-0056# 134a Airlock Manual N.A. Notes 8 Equalization 5, 6 8 2BS-0044# -134a A*riock Manual N.A. Notes 8 Equalization 5, 6 8 2BS-0029# 134a Airlock Manual N.A. Notes 8-Equalization 5, 6 8

. 28S-0015# 134a Airlock-Manual H.A. Notes 8

. Equalization: 5, 6 8

5. Power-Operated Isolation Valves 1HV-2452-1 4 Main Steam to Aux. N.A. N.A.

FPT From Steam Line #1 PV-2325 _5 Atmospheric Relief- N.A. Note-3 8 Steam Generator-PV-2326 9 Atmospheric Relief H.A. ' Note 3 8 Steam Generator 3 PV-2327 13 Atmospheric Relief N.A. Note 3- -8 Steam Generator 3 HV-2452-2 17 Main Steam to Aux.- NiA. N.A. 8 FPT From Steam-Line- .

PV-2328 18 -Atmospheric Relief N.A. Note.3 8 Steam Generator 3 HV-2491A 20a Auxiliary Feedwater N.A. H.A. 8 Steam Generator COMANCHE PF.AK - UNITS 1 AND 2 2-14 Revision 8 June 30, 1992

~ . - . . - . - . . . __ . . . . ..

1 i

l

' TECHNICAL RE0VIREMENT'2.1-(continued) :)

l

.TfJLE 2.1'.1 (continued)'

CONTAINMENT ISOLATION VALVES- :

MAXIM'W

. ISOLATION NOTES AND' FSAR TABLE TIME LEAK - TEST--

VALVE N L REFERENCE NO.* LINE OR SERVICE- (Seconds)- REOUIREMENTS-

5. Power-OperatedIsolation_ Valves (Continued)- ,

HV-2491B 20a -Auxiliary Feedwater N.A. . N.A. 8 i to Steam Generator

1 1 HV-2492A 22a Auxiliary Feedwater N.A. N.A. L8-

-to Steam Generator 92 .c HV-2492B 22a Auxiliary feedwater N.A. -N.A. -8:

to Steam Generator -

2 HV-2493A 24a- Auxiliary Feedwater N.A.- N . A. - 8 to Steam Generator-

3-HV-2493B 24a . Auxiliary Feedwater N.A. N .' A . 8 k to Steam Generator-

3 -

HV-2494A 26a _ Auxiliary Feedwater N.A. N . A '. -

to-Steam Generator-

4 HV-24948 26a . Auxiliary Feedwater N.A._ N. A. - 8

.to Steam Generator 14 .

8701B 33 RHR From Hot Leg

4

'N . A..- 'C 8_ _

Loop _#4--

-8701A- 34 RHR From Hot Leg- ; N. A.. .C. 8 Loop #1' '

8809A 35 RHR-to Co_ld; Leg'- N.A. LNote4 l 8

Loops #1 and-#2: 2-8809B 36 RHR'to Cold Leg. N.A. .*-te 4 8 Loops #3 and.'f4 2 8801A 42 Safety Injection:- .N.A. N.A.. -l V

-p

-to_ Cold Leg Loops - '

A

1, #2,7 f3,.;and.f4 m

COMANCHE PEAK UNITS 1 AND 2 2 Revision-8= -

June 530,-1992l

.-..--.a. . ~ . . - - - - - ... - .- .- .

, ~.,

TECHNICAL REOUIREMENT 2;1 (continued)

TABLE 2.1.1=(continued)-.

CONTAINMENT ISOLATION VALVES MAXIMUM H'

. ISOLATION- NOTES AND_

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

5. Power-Operated Isolation Valves (Continued);

8801B 42 Safety Injection -N.A. N.A. 8' to Cold Leg Loops-

1, #2,.f3, and #4 8802A 43 -SI Injection to N.A. N.A. 8 RCS-Hot-Leg Loops -

f2.and #3-8802B 44: SI Injection to N.A. :N.A. 18-I RCS-Hot Leg-Loops' ~

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

1~ #2, #3,<and-#4 8351A 47 Seal. Injection to N.A. N.A. 8 L

RCPump-(Loop;#1) 8351B 48 Seal. Injection-to. N.A.- N k'.' 8-RCPump-(Loopf2)-- o 8351C 49 SealiInjection to N.A. N.A.: 8 RCPump.l(LoopLf3);

o' 8351D 50 Seal . Injection to'.:- N; A.c iN. A. . 8-

'_RCPump('. cop #4):-

-HV-4777 54 Contain. ment Spray N.A.: -Note 4- =8 to Spray Header

-(1rainB)' 2 HV-4776 55 _ Containment. Spray. N.A. . Note 4 8:

_to Spray _ Header:

(Train _A) .2 8840 63 fair tc HotLLeg,_ N.A. Note'4.- Si Loops #2 and.f3- 2 --

8811A -125 Containment- N.A. N.A. 6

' Recire. Sump

- 'i to RHR Pumps. ,

(TrainA)

COMANCHE PEA'K -: UNITS:1:AND 2 2216 Revision 8- -l

. June 30,-1992

TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE 2.1.1 (continued)

O CONTAINMENT ISOLATION VALVES

MAXIMUM ISOLATION: NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO

LINE OR SERVICE (Seconds) RE0VIREMENTS

5. Power-Operated Isolatio,1 Valves (Continued) 88118 126 Containment N.A. N.A. 8 Recirc. Sump to RHR Pumps (TrainB)

HV-4782 127 Containment N.A. N.A. 8 i

Recirc. to Spray Pumps (Train A)

HV-4783 128 -Containment N.A. N.A. 8~

Recirc.-to Spray Pumps (Train B)

O 4

1 d

-t. A);

~ COMANCHE PEAK - UNITS .1 AND 2 2-17 Revision 8 June 30, 1992

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

7..~ ,

~

TECHNICAL REOUIREMENT 2.1 (coptinuedi:

. TABLE 2.1.1 (continued)

CONTAINMENT ISOLATION VALVES MAXIMUM:

' ISOLATION NOTES AND-

, FSAR TABLE - TIME- LEAK TEST-VALVE NO. REFERENCE'NO.* LINE OR SERVICE -(Seconds) REOUIREMENTS t

2

6. Check Valves-c .

8818A 35 RHR'to Cold Leg ' N . A. - N.A. -8

[

Loop #1"

- - r

!- 8818B' 35 RHR to Cold Leg -N.A. N.A. 8 Loop f2

_ 8818C 36 RHR to Cold _ Leg, N.A. N . A . .- 8 '

i Loop;#3; 8818D 36 ~ RHR to Cold Leg: .N.A. . N;A. 8 j Loop.#4

, 8046 41 Reactor Makeup' .N.A.. C- 8-Water to Pressu--

! rizer Relief Tank-and RC Pump Stand ,

Pipe-

~

4 8815 42- High H_ead Safety N. A. . N;Al 8-

! Injection to Cold

!: . Leg Loops #1,-#2, '

l- #3,-and:#4 i

SI-8905B 43 SI to'RC'.SystemL N.A. N.A. ~ 8-Hot Leg. Loop #2 i . SI-8905C 43 '

SI1to RC System-:. - N . A .' ;N.A.

. Hot Leg' Loop #3; ll"8

[ SI-8905A. -44 SI to RC System! N . A . -- N.A.

8.

- Hot Leg Loop-#1 SI-89050 44: SITto RC' System - TN.A. : N2A. 8-Hot Leg loop f41 L - SI-8819A. 45 LSI to'RC System M.A. : N.A. 8 L - Cold Leg Loop #1-4 e - COMANCHE' PEAK - UNITS 1 AND. . 2-18 Revision 81 June-30, 1992

[ -/t- @ g-- f -r b -PP- f = '77 TPr'g e rr- g gmp 9 ys qqwg og ?if,-W&yem+ = e my g g s7. p p g g y,.g.,ng y.qq g.9 r'N 8= T-M'F*e' Wr-' # $ M' 18- WF**M& grP ly g. Y M g

TECHNICAL REQUIREMENT 2.1 (continued)-

TABLE 2.1.1 (continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE N0. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS 6.CheckValves(Continued)

S1-8819B 45 SI to RC System N.A. N.A. 8 Cold Leg Loop #2 SI-8819C 45 SI to RC System N.A. N.A. 8 Cold Leg Loop #3 SI-88190 45 SI to RC Syetem H.A. N.A. 8 Cold Leg loop #4

^

8381 46 Charging Line to N.A. C 8 Regenerative Heat Exchanger CS-8368A 47 Seal Injection to N.A.- N.A. 8 RC Pump (Loop #1)-

CS-8368B 48 Seal Injection to N.A. N.A. 8

[]

L RC Pump (Loop #2)

CS-8368C 49 Seal Injection to N.A. N.A. 8 RC Pump (Loop #3)

CS-8368D 50 Seal Injection to N.A. N.A. 8 RC Pump (Loop #4)

CS-8180 51 Seal Water Return N.A. C 8 and Excess Letdown CT-145 54 Containment Spray N.A. Note 4 8

to Spray Header (Tr. B) 2

.g U

COMANCHE PEAK - UNITS 1 AND 2 2-19 Revision 8 June-.30, 1992

s q

L TECHNICAL'RE0VIREMENT 2.1-(continued)

)

' TABLE--2.1.1 (continued)

O CONTAINMENT-ISOLATION VALVES '

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

[

i

-6.CheckValves_(Continued):

j- CT-142 55~ Containment. Spray- N . A'. . Note 4 8- g i to Spray Header l:'

.(Tr. A) 2 :

CI-030 62 Instrument Air N.A. 'C- .8- *

! to Containment-

- 8841A _RHR to Hot Leg H.A. .N . A. - -8

Loop #2

! 88418--- 63- RHR.tc Hot Leg _ :H.A. N.A._ 8 I

. Loop #3 f SI-8968 104 N2 Supply to- N.A.- C -8 l Accumulators-CA-016 113- Service Air toH N . A'. :C :8 U -

Containment

~

CC-629 117 CC Return From N . A .H -C. '8-

_RCP's Motors l- CC-713- 118 CC Supply to RCP's~

~

i N.A.: C: '8 Motors cy CC-831 :119 CO Return From l N. A.; .C~ .8- .

! RCP's-Thermal:

Barrier

- CH-024 -120 Chilled Water- -

N.A. -C :8 Supply.-to Contain--

F ment : Coolers p

t KOi E

COMANCHE.PEAKt-_ UNITS _1.ANDi2 2-20 '

Revision.8 .

June 30,-1992--

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

TECH'NICAD REOUIREMENT 2.1 (continued)' $

TABLE 2;1.1 (continued) d CONTAINMENT ISOLATION VALVES.

MAXIMUM- .

! ISOLATION ' NOTES AND 7

FSAR TABLE TIME- LEAK TEST-

VALVE NO. REFERENCE NO.* LINE-OR SERVICE--(Seconds) :FJ.001REMENTS

7. Steam Line Isolation Signal. ;

HV-2333A 1 Main Steam From 5 Note 2 & 3 8

~

,' Steam Generator il ,

1 Drain From Main N.A.- 8 HV-2409 3 5 Steam Line il

. HV-2334A' 6 Main-Steam From .

5 Note 2'& 3-- 8 Steam Generator #2-HV-2410 8 Drain From Main ~ -5 N.A.. 8-l ' Steam Line #2

,_ HV-2335A -10 Main. Steam From-._ 5. -Note 2;& 3' _8 -

Steam Generator #3

~

4 HV-2411 12 Drain From. Main- 5. LN. A.E 8' Steam Line-#3, HV-2336A 14- Main Steam From S' Note ~2 & 3 8-I- Steam Generator'#4-l-

L HV-2412- 16. Drain From Main 5- N.A. 18 Steam Line (4-i g

i y

. 4 LO .

b COMANCHE PEAK.--UNITS 1_.AND '

2121~ ' Revision 8-

' June'30,L1992.

TECHNICAL RE0VIREMENT 2.1 (continued)

TABLE 2.1.1 (continued)

/N

( ,)- CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE Hn.* LINE OR SERVICE LSggpodil REOUIREMENTS

8. Feedwater Line Isolation Signal HV-2134 19 Feedwater to 5 Note 3 8 Steam Generator #1 FV-2193 20c Feedwater Preheat 5 Note 3 8 4

Bypass Line S.G. #1 HV-2185 20d Feedwater Bypass 5 Note 3 8 Line S.G. #1 HV-2135 21 Feedwater to 5 Note 3 8

. Steam Generator #2 FV-2194 22c Feedwater Prsheat 5 Note 3 8 Bypass Line S.G. #2 HV-2186 22d Feedwater Bypass 5 Note 3 8

(~.h. Line S.G. #2 wJ HV-2136 23 Feedwater to 5 Note 3 8 Steam Generator #3 FV-2195 24c Feedwater Preheat ~5 Note 3 8 Bypass Line S.G. #3 HV-2187 24d Feedwater Bypass 5 Note 3 8 Line S.G. #3 HV-2137 25 Feedwater to 5- Note 3 8 Steam Generator #4

~

FV-2196 26c Feedwater Preheat 5 Note'3 8 Bypass line S.G. #4 HV-2188 26d feedwater Bypass 5 Note-3 8 Line S.G. #4

. /^\

()

COMANCHE PEAK -UNITS 1 AND 2 2-22 Revision 8 June 30, 1992

Y 3

~

0 ' TECHNICAL-REQUIREMENT 2.1 (continued)-

TABLE 2.111-(continued)- ,

CONTAINMENT ISOLATION VALVES

?~

MAXIMUM i

ISOLATION' NOTES AND .

FSAR--TABLE ~ . --

. TIME- LEAK-TEST-

[ VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REOUIREMENTS -

i 9. Safety Injection Actuation Isolation i

L 8105 46 Charging Line 10 C 8 L to Regenerative- '

Heat Exchanger- -

4

10. Relief Valves- '

8708B 33 RHR From Hot N.A. C 8 Leg _ Loop #4 l

8708A 34 RHR From Hot N.A. C.. 8-

'f l Leg Loop fl.

MS-021 Sb- . _ Main Steam Safety _ N . A.- Note;3 ,8 '

Valve S.G.-#1:

MS-022- Sb Main Steam Safety' N.A. Note:3 8 I l[ Valve S.G. #1

MS-023 Sb Main S6eam Safety: N.A. Note 3 8-1 -Valve S.G. #1-l MS-024 5t; Main Steam-Safety- N.A. : Note:3 : 8 -_

l- Valve S.G.~#1' i

U MS-025 5b Main Steam Safety. :N.A.- ' Note.3- 8 Valve.S.G. #1 MS-058- 9b Main Steam Safety N . A . .. -Note.3_ 8

{ Valve S.G.'#2:

MS-059 9b ' Main. Steam-Safety N.A.- Note 3' .8

' Valve-S G. #2- .;

L-MS-060 9b Main Steam Safety: '

N.A. Note'3 .8-g Va he S.G.-#2' ;

i h .

iA

.\ )./

f xCOMANCHE PEAK - UNITS 1:AND 2: 2 Revision 8-iJune 30,_:1992:

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

s u TECHNICAL RE0dlREMENT 2.1 (continuedi

'53LE'2.1.1 (continued)

CONTAINMENT ISOLATION VALVE 5 MAXIMUM.

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

10._ReliefValves(Continued)

MS-061 9b Main Steam Safety -N.A. Note 3 86 Valve S.G..#2 ' ,

MS-062' 9b . Main Steam Safety- N.A. . Note 3; 8-Valve'S.G. #2' MS-093 13b Main Steam Safety

~

N.A. Note:3' :- 8 ' ~

Valve S.G. f3 Main Steam Safety- i MS-094- 13b N.A. : Note 3 8 Valve S.G. #3 :

MS-095 13b . Main'_ Steam Safety- _ N. A.: _ Note 3 8 Valve S.G. f3-MS-096 13b Main _ Steam: Safety _ N . A. . ' Note 3 8

h- Valve S.G. #3 MS-097 13b Main. Steam Safety N.A. Note.3- 8 Valve S.G. #3-MS-129 18b . Main Steam Safety _N.A'.- ~Noto 3: :- 8 F Valve S.G. f4-

, MS-130 18b Main Steam-Safetyi N. A..- Note 3' 8 Valve:S.G. #4 MS-131 18b Main Steam Safety LN;A.- Note 3- 8

. Valve S.G.-#4 MS-132 18b Main Steam Safety N. A.. .Notef3 8_ ;

[ . Valve S.G. #4:

,. MS-133 18b Main Steam. Safety N.A. Note:3- 8 3: Valve'S.G.-#4' 1

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L COMANCHE PEAK - UFITS 1 AND 2 2-24 Revision 8 June.30,7.1992

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N TECHNICAL RE001REMENT 2.1 (continued)

TABLE 2.1.1 (continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION NOTES AND FSAR TABLE TIME LEAK TEST VALVE NQ2 REFERENCE NO.* LINE OR SERVICE (Secondtd REOUIREMENTS 10.ReliefValves(Continued)

RC-036 41a Penetration Ther- N.A. C 8 rial Relief WP '176 52a Penetration Ther- N.A. C 8-mal Relief 0D-430 60a Penetration Ther- N.A. C 8 mal Relief

'/0-907 61a Penetration Ther- N.A. C 8 '

mal Relief PS-503 74a Penetration Ther- N.A. C 8 mal Relief PS-501 77a Penetration Ther- N.A. 8 :

mal Relief PS-502 78a Penetration-Ther- N.A. C 8 ,

mal Relief PS-500 80a Penetration Ther- N.A. C 8 mal Relief. ;

WP-7177 Bla Penetration Ther- N.A. C 8

, mal Relief ,

[SI-8972 83a Penetration Ther- N.A. C)- 8 mal Relief 4

[CC-1067 114a Penetration Ther- N.A. C) 8 ;

mal. Relief (CH-271 120a Penetration Ther- 'N. A. . C) 8' mal.Rolief-

[CH-272 121a. Penetration Ther N.A. C) -

.8 '!

- mal Relief O

COMANCHE PEAK - UNITS 1 AND 2- .2-25: ' Revision 8-

June,30, 1992 .i

l 1

ILCHNICAL REQUIREMENT 2.1 (continued)

. /T TABLE ?.1.1 (Continued)

'ig

IABLE NOTATIONS

Identification code for containment penetration and associated isolation valves in FSAR Tables 6.2.4-1, 6.2,4-2, and 6.2.4 3.

1

# May be opened on an intermittent basis under administrative control. ;

The table does not list local vent, drain and test connections as they are a special class of containment isolation valves and are locked i closed and capped to aeet containment isolation criteria when located 4 within the penetratic ' boundary, i

'M ce 1: All four MSIV bypass valves are locked closed in Mode 1. ,

During Mode 2, 3, and 4 one M51V bypass valve may be opened

] provided the other ihrra MSIV bypass valves are locked closed and their associated MSIVs are closed.

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

Note 3: These valves are included for table completeness, the requirements of Specification 3.6.a* do not apply. Instead, f-- the requirements of Specification 3.7.1.1, 3.7.1.5, 3.7.1.6 3 t and 3.7.1.7 apply for main steam safety valves, mainsteam 3

.1 isolation valves, feedwater isolatinn valves and steam 3 generator atmospheric relief valves. respectively. 3 Note 4: These valves are leak tested in accordance with Technical

Specification Surveillance Rcquirement 4.6.1.2. 2 Note 5: 10 CFR 50 Appendix J. Type C testing of th.ese valves is 6

, satisfied by the testing of the airlock under Technical 6 Specification Surveillance Requirement 4.6.1.3b.

4 Note 6: These valves are considered an' integral part of the airlock 6 associated with their respective airlock dear. Therefore . 6 they are subject to the controls of Specification 3.6.1.3. 6 Note 7: These valves are securso ^m positior, by hydraulic system 6 locks and/or interlocks and do not require separate locks. 6 LO)

COMANCHE PEAK - UNITS 1 AND 2 2-26 June 30, 1992~

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TECHNICAL REOUIREMENT 2.1 (continued)

BASES ,

2.1 CONTAINHENT ISOLATION VALVES

The OPERABILITY of the containment isolation valves ensures that the containment atmosphere will be isolated from the outsdoe environment in the event of a release of radioactive material to the containment atmosphere or pressurization of the containment and is consistent with the requirements of. General Design Criteria 54 through 57 of 10CFR50, 1

Appendix A. Containment isolatiun within the time limits specified for those isolation valves designed to close automatically ensures that the release of radioactive material tc the environment will be consistent with the assumptions used in tiie analyses _for a LOCA.

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iO COMANCHE PEAK - UNITS l'AND 2 2-27 I

l June 30, 1992

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TECHNICAL REQUIREMENT 3.1 SNUBBER INSERVICE INSPECTION PROGRAM NOTE: This Technical Requirement contains the augmented inservice inspection program for snobbers. -Although the CPSES Technical .

Specification is repeated here, care must be taken not to j overlook Technical Specifl cation requirements.

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O COMANCHE PEAK - UNITS 1 AND.2 I3-1 .

' June 30, 1992

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

APPLICABILITY: MODES 1, 2, 3, and 4. MODES 5 and 6 for snubbers 8 located on systems required OPERABLE in those MODES.*

ACTION With-one or more snubbers inoperable on any system, within 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months s-replace or restore the inoperable snubbers (s) to OPERABLE status and perform an engineering evaluation in accordance with the approved augmented inservice inspection program on the attached _ component or declare the attached system inoperable and follow the appropriate ACTION statement for that system.

E'WEILLANCE RE0VIREMENTS 4.7.9 Each snubber shall be demonstrated OPERABLE by performance of 4

the requirements of the approved augmented inservice inspection program.

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Unid2requirementsareeffectiveuponissuanceoftheUnit2 8

operating license.

O COMANCHE PEAK - UNITS 1 AND 2 3-2 Revision 8-

-June 30, 1992

TECHNICAL RE0VIREMENT 3.1 SNUBBERS TESTS / INSPECTIONS .

TR3.1 Each snubber shall be demonstrated OPERABLE by performance of the following aug:nented inservice inspection program in lieu of the requirements of Technical Specification 4.0.5.

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

b. Visual Inspections Snubbers are categorized as inaccessible or accessible during reactor operation. Each of these groups (inaccessible ard 5 accessible) may be inspected independently according to the schedule determined by the table below. The visual inspection.

interval for each type of snubber shall be determined based upon the criteria provided in the table and the first inspection interval determined using this criteria shall be based upon the previous inspection interval as established by the requirements in effect before this revision.

NUMBER OF UNACCEPTABLE $NUBBERS ~ 5 Population Column A Column B Column C- 5 or Category Extend Interval Repeat Interval Reduce Interval 5 (Notes 1 & 2) (Notes 3 & 6) (Notes 4 & 6) -(Notes'5'& 6) 5 1 0 0 1 5 80 0 0- 2 5 100 0 1 4 5 5

150 0 3 8 5 200 2 5 13 5 300 .5 12 25 5 5-400 8 18 36 5 500' 12 24' 48 5

=750 20 40 78 5 1000 or greater 29 56 109 5:

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

COMAhCHE PEAK - UNITS 1 AND 2 3-3 .

June 30, 1992;

J 1

a TECHNICALREQUIREMENT3.1(continued) 5 TESTS / INSPECTIONS (Continued)

Snubbers may be categorized, based upon their 5 accessibility during power operation, as accessible or inaccessible. These categories may be examined ,

i separately or jointly. However, the licensee must make

and document that decision before any inspection and shall 3 use that decision as the basis upon which to determine the j next inspection interval for that category.

Note 2: Interpolation between population or category sizes and the 5 number of unacceptable snubbers is permist'ble. Use next i

lower integer for the value of the limit for Columns A, B, i

or C if that integer includes a fractional value of j unacceptable snubbers as determined by interpolation.-

Note 3: If the number of unacceptable snubbers is equal to or less 5

than the number in Column A, the next inspection-interval 2

may be twice the previous interval but not greater than 48

months.

Note 4: If the number of_ unacceptable snubbers is equal to or less 5 I than the number in Column B, but greater than the number J in Column A, the next inspection interval shall be the )

same as the previous. interval.

Note 5: If the number of' unacceptable snubbers is equal to or 5

. greater than the number in Column C, the next inspectinn i interval shall be two-thirds of the previous interval.

However, if the number of_ unacceptable snubbers is less

than the number in Column C but greater than the number in Column B, the next_ interval shall be reduced' proportionally be_ interpolation, than is, the previous interval shall be reduced by a factor that is one-third of-the ratio of the difference between the number of unacceptable snubbers found during the previous interval and the number in Column B to the difference in the numbers in Columns B and C.

Note 6: The provisions of Specification'4.0.2 are applicable for 5

, all inspection intervals up to and including 48 months.

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COMANCHE PEAX'- UNITS 1 AND 2 3-4

' June 30 -1992

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TECHNICAL REOUIREMENT 3.1 (continued 1 qs SNUBBERS TESTS / INSPECTIONS (Continued) I i I 4

c. Visual Inspection Acceptance Criteria

~

Visual inspections shall verify that: (1)therearenovisible l l indications of damage or impaired OPERABILITY, (2) attachements to l the foundation or supporting structure are secure, and (3) i' fasteners for attachment of the snubber to the component and to the snubber anchorage are secure. Snubbers which appear inoperable as a result of visual inspections may be determined OPERABLE for the purpose of establishing the next visual inspection interval, provided-that: -(1) the cause of the r rejection is clearly established and remedied for that particular

, snubber and for other snubbers irrespective of type that may be generically susceptible; or (2) the affected snubber is functionally tested in the as-found condition and determined

OPERABLE per Test / Inspection-TR3.lf. All snubbers connected to an inoperable common hydraulic fluid reservoir shall be counted as inoperable snubbers.

d. Transient Event inspection i

- () An inspection shall be performed of all-snubbers attached to sections of systems that have experienced unexpected, potentially i damaging transients as determined from a review of operational-

data. A visual inspection of those systems chall be performed

. within 6 months following such an event. In addition to

, satisfying the visual inspection acceptance criteria, freedom-of-motion of mechanical snubbers shall be verified using-at least one of the following: (1) manually induced-snubber movement; or (2)

! evaluationofin-placesnubberpistonsetting;or(3)-strokingthe' ,

mechanical snubber through its full range of travel.

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a COMANCHE PEAK - UNITS 1 AND 2 3-5

June 30, 1992-

i i

TEC_HNICAL REOUIREMENT 3.1 (continued)

SNUBBERS i TESTS / INSPECTIONS (Continued) l j

e. Functional Tests l j During the first refueling shutdown and at least once per 18 ,

months thereafter during shutdown, a representative sample of I snubbers of each-type shall be tested using b,se of the following i j sample plans. The sample plan for each type shall be selected-

prior to the test-period and cannot be-changed during the test 1

( period. The NRC Regional-Administrator shall be notified in

] writing of the sample plan selected for each snubber type prior to -

! the test period or the sample plan used in.the_ prior test period .;

! shall be implemented:

i

, 1) At least 10% of the total of each type of snubber shall be !

!- functional _1y tested either in-place or in a bench test. For :

! each snubber _ of a type that does not meet the functional. test l acceptance criteria of Test / Inspection TR3.lf, an additional j 10% of that type of. snubber shall be functionally _ tested until :

no more failures are found or until all_ snubbers of that type j have been functionally tssted;.or

2) A representative sample of each type of-snubber.shall be

! functionally tested in accordance with Figure 3.1-1.- '?C"~ is l_ the total number of snubbers of a type found not meeting the-l acceptance requirements of Test / Inspection TR3.lf. The ,

i cumulative number of snubbers of a type tested'is denoted by "H". At the end of.each day's testing, the new values of "Hd and"C"(previousday'stotalplus^currentday'sincrements) j shall be plotted on Figure 3.1-l'. :If.at any_ time the point L plotted falls in the "Acce n" region, testing of snubbers of

that type may be terminated. When the point plotted lies in -5 the " Continue Testing" region,-additional snubbers of that !

j type shall be tested until the region, or all the snubbers of,-point that type falls-in_the."

have been Accept" tested, i

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~ COMANCHE PEAK - UNITS 1 AND 2- 6:

June 30/1992-

TECHNICA'. REOUIREMENT 3.1 (continued 1 i SNUBBERS TESTS / INSPECTIONS (Continued 1

f. Functional Test Acceptance Criteria The snubber functional test shall verify that:

P

, 1) Activation (restrainingaction)isachievedwithinthe specified range in both tension and compression;

2) Snubber bleed, or release rate where required, is present in both tension and compression, within the specified range; !

3) For mechanical snubbers, the force required to initiate or 'l maintain motion of the snubber is within the specified range ,

in both directions of travel. l 5 ,

Testing methods may be used to measure parameters indirectly or parameters other than those specified if those results can be

correlated to the specified parameters through_ established' methods,

g. Functicin t Test Failure Analysis An engineering evaluation shall be inade of each failure to meet the functional test acceptance criteria to determine the cause of the failure. The results of this evaluation shall be used, if

-applicable, in selecting snubbers to be' tested in an effort to.

determine the OPERABILITY of other snubbers irrespective of type which may be subject to the same failure mode.

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COMANCHE PEAK - UNITS 1 AND 2 3-7_

June'30, 1992-

J I

)

! TECHNICAL REOUIREMENT 3.1 (continued)

- O V SNUBBERS l' TESTS / INSPECTIONS (Continued)

g. Functional Test Failure Analysis (Continued)

For the snubbers found inoperable, an engineering evaluation shall i be performed on the components to which the inoperable snubbers

{ are attached. The purpose of this engineering evaluation shall be to determine if the components to which the inoperable snubbers are attached were adversely affected by the inoperability of the

snubbers in order to ensure that the component remains capable of

, meeting the designed service.

If any snubber selected for functional testing either fails to lock up or fails to move, i.e., frozen in-place, the cause will be evaluated and, if caused by manufacturer or design deficiency, all

' snubbers of the same type subject to the same defect shall be functionally tested. This testing requirement shall be independent of the requirements stated in Test / Inspection TR?.le for snubbers not meeting the functional test acceptance criteria.

h. Functional Testina of Repaired and Replaced Snubbers

! Snubbers which fail the visual inspection or the functional test i acceptance criteria shall be repaired or replaced. Replacement snubbers and snubbers which have repairs which might affect the functional test results shall be tested to meet the functional test criteria before installation in the unit. Mechanical snubbers shall have met the acceptance criteria subsequent to their most recent service, and the-freedom-of-motion test must-have been performed within 12 months before being installed in the unit.

1. Snubber Service life Procram i The service life of hydraulic and mechanical snubbers shall be monitored'to ensure that the service life is not exceeded between i curveillance inspections. The_ maximum expected service life for various seals, springs, and other critical parts shall be determined and established based on engineering information and shall be extended or shortened based on monitored test results and failure history. Critical parts shall be replaced so that the maximum service-life will not be exceeded during a period when toe snubber is required to be OPERABLE. The parts replacements shall be documented and the documentation shall be retained in accordance with Technical Specification 6.10.2.

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COMANCHE PEAK.- UNITS 1 AND 2 3-8

. lune 30, 1992

, y

TECHNICALREQUIREMENT3.1(continued)

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=

C 5 0 4 3

CONTHJE TEtiTING r p.

l ACC EPT 4 I

, 1 rv 0 # '

10 20 30 40 50 60 70 80 90 100 i

N-i Figure 3.1-1 m Sample Plan 2) for Snubber Functional Test V

COMANCHE PEAK - UNITS 1 AND 2 3-9 June 30, 1992 ,

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

3

TECHNICAL REOUIREMENT 3 2 STATION SERVICE WATER SYSTEM OPERABILITY CRITERIA 4

3.2 A Unit 2 Service Water Pump shall be available to support Unit 1 operation, t APPLICABILITY: Modes 1, 2, 3 ar.d 4.* 8

COMPENSATORY MEASUPES

a. If neither Unit 2 Service Water Pump is available, either restore a Unit 2 Service Water Pump to available status within 7 days, or, place Unit 1 in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD 4

SHUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months , s

b. If only one-Unit 1 Service Water Pump is OPERABLE and neither Unit i E Service Water Pump 4 available, immediately initiate action to restore either a Unit 2 Service Water Pump to available status or f the inoperable Unit 1 Service Water Pump to an OPERABLE status.

TEST / INSPECTIONS O

d The Unit 2 Service Water Pump (s) shall be considered available if it is capable of being manually started and cross-connected to the Unit 1 Service Water System. This availabi14 9 shall be demonstrated by:

TR3.2.1 At least once per day, verifying that Bus 2EA1 is energized if the 2A Service Water Pump is.the available pump, or Bus 2EA2 is energized if the 28 Service Water _ Pump is the available pump; and TR3.2.2 At least once per day, verifying that the cross connect valve (s) between the Unit 1 Service Water System and the available Unit 2 Service Water Pump are open or capable of j being opened.

TR3.2.3 At least once quarterly stroking cross-connect valves XSW-0006, XSW-0007, XSW-0008, XSW-0028, XSW-0029 through their

. full range of motion.

TR3.2.4 At least once per 31 days, the available pump _will be operated-for at-least 15 minutes.

1

Unit 2 requirements are effective upon issuance of the Unit 2 8 operating license.

COMANCHE-PEAK - UNITS'1 AND 2.' 3-10 Revision 8 June 30,1992

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TECHNICAL RE0VIREMENT 3.2 (continuqdl BASES 3.2 STATION SERVICE WATER SYSTEM i i

The inclusion of this requirement for Unit 2 Station Service Water 1 Pump availability while Unit 1 is operating in MODES 1 through 4, the j attendant Test / Inspections to demonstrate availability, and the compensatory measures to be taken in the event a Unit 2 Service Water !

Pump is not available, provide the necessary level of administrative controls to assure acceptable results from the Probabilistic Risk Assessment (PRA) for loss of Unit 1 Station Service Water. These requirements are in addition to the requirements for Unit 1 Station

( Service Water contained in the Technical Specifications. ;

j The Test / Inspection requirements for the Unit 2 Station Service Water pump availability are adequate to ensure that power is available to the pump and the pump is capable of pumping upon demand. The cross-connect discharge path valves-are tested at least once-per' quarter by stroking these valves through their full range of motion. These cross-connect valves are also verified to'be capable of being opened-or already open by an administrative check by examining logs or otner information to determine if these valves are out-of-service for maintenance or other reasons.

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COMANCHE PEAK - UNITS 1 AND 2- 3-11 JuneL30, 1992-

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i JECHNICAL REOUIREMENT L2 FEEDWATER ISOLATION eL\' TEMPERATURE OPERABILITY CRITERIA 3.3 Each main feedwater isolation valve shall be greater than or 3 equal to 900F, when feedwater line pressure is greater than -l 1 675 psig. 3 l1 MPLICABILITY: MODES 1*, 2, 3 and during pressure testing of the l l

steam generator or main feedwater line. ** 8 L ' 2NSATORY MEASURES:

With one or more main feedwcter isolation valves outside of the above 3

limits:

I

a. Restore main feedwater isolation valve pressure and/or 3 temperature to within the limits within 30 mirutes, and

b. Perform an engineering evalua,lon to determine the effect of 3 the overpressure on the structural integrity of the main feedwaterisolationvalve(s)anddeterminethatthemain

feedwater isolation valve (s) remains ccceptable for continued

, operations within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months . Complete this determination each.

4 O

y time this compensatory measure is entered.

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 SHJT00WN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

TESTS / INSPECTIONS 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 Readings shall be taken using the following instruments: TI-2152-1, 8 TI-2152-2, TI-2152-3 and TI-2152-4. If.any of these instruments are inoperable, a surface pyrometer may be used to determine valve

, temperature.

Except in MODE 1 with the feedwater isolation valve open, 3 temperature readings are not required. 3

- Unit 2 requirements are effective upon issuance of.the Unit 2 8 operating license.

O l COMANCHE PEAK -' UNITS 1 AND 2 3-12 Revision 8

[ June 30, 1992

TECHNICAL REOUIREMENT 3.3 (Continued)

BASES i

3.3 FEEDWATER ISOLATION VALVE TEMPERATURE Supplemental inipact testing performed on portions of representative samples of the valve body, neck and bonnet of the feedwater isolation valves (FIV's) yielded results which were not in accordance with the ASMEcoderequirementsforfracturetoughnessformaterial(kC-2300) based on a minimum service temperature of 400F. The results of the supplemental tetting are discussed in Engineering Report ER-DBE-ME-

] 045. In addition a fracture mechanics analysis is detailed in '

Calculation 16345-ME(B)-274R/1"ResistanceofFeedwaterValvesto Brittle Fracture". ,

i- As indicated in the engineering report. the fracture toughness 4

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

The valve bonnet fracture toughness has been demonstrated by the fracture analysis calculation in conjunction with a Volunetric Hon-Destructive Exam which determined that there are no significant material flaws which could . lead to fracture propagation.

As a result of the conclusions drawn in Engineering Report ER-DBE-ME- 8 O 045, it is necessary that minimum temperat're limitations be imposed O u 4

upon Feedwater Isolation Valves HV-2134, -2135. -213J and -2137. As stated in DBE-ME-203 Section 4.3.7 " Operator interfaca requirements",

the feedwater isolation valves must be verified to be above 900F prior to entering MODE 3, RCS T avg t 3500F. This' corresponds to a pressurization at the valve of approximately 140-150 psig. The ;

maximumpressurizationduringcoldconditions(valvetemperature

< 900F) should be limited to no nore than 20% of' the valve hydrostatictestpressure(3375psigx20%=675psig)whichexceeds thecondensatepumpocadheaddischargepressure(Ref.ER-0BE-ME-045).

,, 'ri...

. lant start-up, it is possible to cold pressurize the valves

, m ta r condensate pumps / feed pumps or from back pressurization from

, .- ' uam Generators. Imposing the MODE 3 limitation will prevent the id :cessurization from the generators.

1 Cold pressurization.from the condensate pumps is normally prevent 0d due to the mar. val isolation valves upstream of each FIV being closed' anytime the feedwater headers are pressurized during long cycle condensate full flow flushing operation or condensate pump minimum flow operation.

Steam turbine driven feed pumps are started during MOCE 2 when sufficient steam is available for pump operation. Pressurization of the FIV from the Main Feed Pumps will therefore occur _ cnly atter

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

COMANCHE PEAK - UNITS 1 AND 2- 3-13 Revision 8 June.30, 1902_-

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l TECHNICAL RE0VIREMENT 4.1 CONTAINMENT PENETRATION CONDUCTOR f OVERCURRENT PROTECTION DEVICES 4

! NOTE: This Technical Requirement contains the listing of overcurrent ~!

protection devices subject to the requirements of Technical ;

Specification 3.8.4. Although the Specification it rar?ated l

here, care must be taken not to overlook Technical ;

Specification Requirements.

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, COMANCHE PEAK - UNITS-1 AND 2~ 4 1?

June 30, 1992 I - -

3/LLLELECTRICAL EQUIPMENT PROTECTIVE DEVICES CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEV1f15 LUilTING CONDITION FOR OPERATION 3.8.4 All containment penetration conductor overcurrent protcetive devices shall be OPERABLE.

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

B ACTION:

With one or more of the containment penetration conductor overcurrent protective device (s) inoperabb:

a. Restore the protective device to OPERABLE status or:

1. Deenergize the circuit (s) by racking out, locking open, or removing the inoperable-protective device And tripping / removing the associated protective device within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the affected :ystem or component inoserable, and verify the inoperable protective device rac(ed out, locked open, or removed at least once per 31 days thereafter; the provisions of Specification 3.0.4 are not applicable to overcurrent protective devices in f

circuits which have their associated protective device tripped / removed and their inoperable protective device racked out, locked open, or removed; or

2. Deenergire the circuit (s) by tripping / removing the associated protective device or racking out, locking open, or removing the inoperable protective device within 72-hours, declare the affected system or component inoperable, ;nd verify the associated protective device to be tripped / removed or the inoperable protective device racked out, locked open, or removed at least once per 7 days thereafter; the provisions of Specification 3.0.4 are not applicable to overcurrent jevices in circuits whicn have their associb ed protective device tripped / removed or their inoperable protective device racked out, locked open, or removed; or

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

Unit 2 requirements are effective upon issuance of the Unit 2-operating license.

8-y COMANCHE PEAK - UNITS 1 AND 2 4-2 Revision 8 j June:30, 1992 1

1

- ELECTRICAL EOUIPMENT PROTECTIVE DEVICES

SURVEILLANCE REOUIREMENTS 4.8.4 The containment penetration conductor overcurrent protective devices shall be demonstrated OPERABLE

a. At least once per 18 months:

1) By verifying that the medium voltage 6.9 kV and low voltage 480V switchgear circuit breakers are OPERABLE by selecting, on a rotating basis, at least 10% of the circuit breakers of each current rating and performing the following:

! a) A CHANNEL CAllBRATION of the associated protective j relays, b) An integrated system functional test which includes simulated automatic-actuation of the system and verifying that each relay and associated circuit breakers and control circuits function as designed, and f c) For each circuit breaker found inoperable during these ,

functional tests, one or an additiondi-representative

sample of at least 10% of all the circuit breakers of 1 the incperable type shall also be functionally tested until no more failures are found or all circuit-breakers of that type have been functionally tested;

2) By selecting and functionally testing a representative sample of at least 10% of each type 480V molded case circuit breakers and lower voltage circuit breakers.

Circuit breakers selected for functional testing shall be-selected on a rotating basis. Testing of these circuit breakers shall consist of injecting a current with a-value equal to.300% of the pickup of the long-time delay-trip element and 150% of the pickup of the short-time delay 4

trip alement, and verifying that the-circuit breaker operates within the time' delay band width for that current specified by the manufacturer. The instantaneous element-shall be tested by injecting a current equal to !20% of

, the pickup value of the element and verifying that the ,

1' circuit breaker trips instantaneously with no-intentional time delay. Molded case-circuit-breaker testing shc11-also follow this procedure except that generally no more i than two trip elements, time _ delay and insth raneous, will be involved. The instantaneous element for molded case circuit breakers shall-be tested by injecting a current-

for a' frame size of 250 amps or less with tolerance: of n

COMANCHE PEAK.- UNITS 1 AND 2 4-3 June 30,<1992-

i !

ELECTRICAL EOUIPMENT PROTECTIVE DEVICES

() SURVEILLANCE REOUIREMENTS

! 40%, -25% and a frame size of 400 amps or greater of 125%

and verifying that the circuit breaker trips '

instantaneously with no apparent time delay. Circuit breakers found inoperable during functional testing shall be restored to OPERABLE status prior to resuming i operation. For each circuit breaker found inoperable

during these functional tests, an additional.

representative sample of a least 10% of all the circJit

. breakers of the inoperable type shall also be functionally l tcsted until no more failures are found or all circuit

? breakers of that type have been functionally tested; and

! b. At least once per 60 months by subjecting each circuit breaker ~

to an inspection and preventive maintenance in accordance with

procedures prepared in conjunction with its manufacturer's recommendations.

i

!O i

I i

i -l l

4 l

i-F COMANCHE PEAK - UNITS 1 AND 2 4-4 4

. June 30, 1992

. - . - . . . . . . -- . - . . .- - = - _ _

TECHNICAL REOUIREMENT 4.1 TABLE 4.1.la 8 EET_.1 8 CONTAINMENT PENETRATION C0i4QL!CTQR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM !

AED LOCATIOS POWERED

1. 6.9 KVAC from Switchgears

a. Switchgear Bus 1A1 RCP #11

1) Primary Breake '.PCPX1 '

a Relay 50M1-51 b Relay 26 c Relay 86M d Relay 51M2 e Relay SON

2) Backup Breakers 1Al-1 or 1Al-2 a Relay 51M3 b Relay 51 for 1Al-1 c Relay 51 for 1Al-2 d Relay 86/1A1

b. Switchgear Bus 1A2 RCP #12

1) Primary Breaker 1PCPY.

a Relay 50H1-51 b Relay 26 c Relay 86M d Relay 51H2 e Relay SON

2) Backup Breakers 1A2-1 or 1A2-2 a Relay 51M3 b Relay 51 for_1A2-1 c Relay 51 for 1A2-2 d Relay 86/1A2 i

l

. COMANCHE PEAK - UNITS 1 AND 2 4-5 Revision 8 l June.30,.1992 I 1

TECHNICAL REOUlREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8 O

V UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION POWERED

1. 6.9KVACfromSwitchgears(Continued)

, c. Switchgear Bus 1A3 RCP #13

1) Primary Breaker 1PCPX3 a Relay 50M1-51 b Relay 26 c Relay 86M d Relay 51M2 e Relay SON

2) Backup Breakers 1A3-1 or 1A3-2 a Relay 51M3 b Relay 51 for 1A3-1 c Rehy 51 for 1A3-2 O, d Relay 86/1A3

d. Switchgear Bus 1A4 RCP #14

1) Primary Breaker 1PCPX4 a Relay 50M1-51 b Relay 26 c Relay 86M d Relay 51M2 e Relay SON

2) Backup Breaker 1A4-1 or 1A4-2 a Relay 51H3 b Relay 51 for 1A4-1 c Relay 51 for 1A4-2 d) Relay 86/1A4-

2. 4B0 VAC from Switchgears 2.1 Device Location - Containment 480V Switchgears 1EB1, 1EB2, Recire. Fans 1EB3 and 1EB4 and CROM

. Vent fans

'd a. Primary Breakers - 1FNAV1, ifNAV2, 1FNAV3. 1FNAV4, 1FNCB1 and 1FNCB2 COMANCHE PEAK . UNITS 1 AND 2 4-6 Revision 8 June 30, 1992

11CHNICAL REOUIREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8 UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR i OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER SYSTEM AND LOCATION P9WERED

2. 480 VAC from Switchgears (Continued)

b. Backup Breakers - IEB1-1, 1EB2-1, 1EB3-1 and 1EB4-1, BT-1EB13 and BT-1EB24

1) Long Time & Instantaneous Relays

10Z51 (1EB1-1) 5Dl51 (1EB2-1) 1FNAV1- 1FNAV2 10251 (1EB3-1) 10251 (1EB4-1) 1FNAV3 1FNAV4 10/51 (1EB3-1) 10251 (1EB4-1) 1FNCB1 1FNCB2

2) Time Delay Relays

61-1 (1EB1-1 62-1X (1FNAV1) 1FNAV1 and IFNAV1 BT-1EB13) 62-1 (1EBZ1- 62-JX (1FNAV2) 1FNAV2 and 1FNAV2 BT-1EB24) 62-1 (1EB3-1 6hlX (1FNAV3) 1FNAV3 and 1FNAV3 BT-1EB13) 62-1 (1EB4 ShlX (1FNAV4) 1FNAV4 and 1FNAV4 BT-1EB24) 62-1 (1EB3-1 . ShlX. (1FNCB1)

IFNCB1 and IFNCB1:

BT-1EB13) 62-1 (1EB4-1 6hlX (1FNCB2) 1FNCB2 and 1FNCB2-BT-1EB24)

(n); .

Associated circuit breaker shown in parentheses', e.g., ICB1-1, is backup breaker-for 1FNAV1.

COMANCHE PEAK.- UNITS 1 AND 2 4-7 Revision 8 o June 30, 1992

TECHNICAL RE0VIREMENT 4.1 (continued) !

I TABLE 4.1.la_fcontinued) 8 j UNIT 1 8 CONTAINMENT PENE1 RATION CONDUCTOR i

OVERCURRENT PROTECTIVE DEVICU DEVICE NUMBER SYSTEM AND LOCATION POWERED 2.2 Device Location - 480V Containment Switchgear IEB4 Polar Crane d

a. Primary Breaker - ISCCP1

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

1) Long Ti.ne Delay Relay 1 51 1 ISCCP1 1 2)TimeDelayandInstantaneousRelays* 1 62 (1EB4-1 and _12X.. (ISCCP1) 1 ISCCP1 BT-1EB24) ISCCP1 1

3. 480VAC from Motor Control Centers d 3.1 Device Location - MCC 1EB1 2 Containment Numbers listed below, i

Primary and Backup - Both primary and backup breakers l 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.

Associated circuit breaker (s) shown in parantheses; e.g. 1EB4-1 and BT-1EB24 are backup breakers for 1SCCPl.

i l

t l

l COMANCHE PEAK - UNITS 1 AND 2 4-8 Revision 8 June 30, 1992

. . . . ~ _~

s ..

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

TECHNICAL REOUIREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8

( UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION j l

3. 480 from Motor Control Centers (Continued)

MCC 1EB1-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED Motor Operated Valve 1-TV-4691 j 4M THED Motor Operated Valve 1-TV-4693 :

3F THED Containment Drain Tank Pump-03 9H THED Reactor Cavity Sump Pump-01 l 9M THED Reactor Cavity Sump Pump-02 7H THED Containment Sump #1 Pump-01 4 7M THED Containment Sump #1 Pump-02 '

i 6H THED RCP fil Motor Space Heater-01 6M THED RCP #13 Motor Space Heater-03 8B 1U0 Incore Detector Drive "A" l 80 THEt, Incore Detector Drive "B" J 78 THED Incore Detector Drive "F" 3B THED Stud Tensioner Hoist Ot11et-01

' O, , 70 THED Hydraulic Peck Lift-01 4B THE0 Retctor C901 ant Pump Mo'or Hoist Receptacle-42 8H THED RC Pipe Penetration Conting Unit-01 8M THED RC Pipe Penetration Cooling Unit-02 DH THEL RCP #11 011 Lift Pump-01 SM THED RCP #13 011 Lift Pump-03 10B THED Preaccess Filter Train Pa:kage Receptacle-17 5B THED Containment Ltg. XFMR-14 (PNL C3) 10F THED S.G. Wet Layup Circ. Pump 01 (CP1-CFAPRP-01) 12M THED S.G. Wet Layup Circ. Pump 03

(CP1-CFAPRP_-03) 12H THED Containment Ltg. XFMR-28 2 (iNL C11 & C12) d O

' COMANCHE PEAK - UNITS _1.AND 2 _4-9 Revision 8 June 30, 1992.

2 TECHNICAL RE001REMENT 4.1 (continued) 3 TABLE 4.1.11 (Contigedl 8-UNIT 1 l8 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER 4

AND LOCATION

, 3. 480VACfromMotorControlsenters(Continued)

I MCC 1EB1-2 G.E.

COMPT. NO. BKR. TYPE .LYSTEM POWERED l

~

, 6D THED Refueling Machine (llanipulator '

Crane-01) l 2M THED RC Drain Tank Pump No. 1 4 2F 1HED Containment Ltg. XFMR-16

, (PNL C7 & C9) l l

IM THED Containment Ltg. XFMR-12 !

(PNL C1 & CS) 3M THED Preaccess Fan No. 11

SD THED Fuci Transfer System Reactor Side Cont, Pn1. for-TBX-FHSTTS 3.2 Device Location - MCC 1EB2-2 Containment Numbers listed t 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 therral-magnetic trip elements.

MCC 1EB2-2 G.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 4G THED Motor Operated-Valve 1-TV-4692-4M THED Motor Operated Valve 1-TV-4694 3F- -THED Containment Drain Tank Pump-04 7H THED Containment Sump No. 2 Pump-03 7M THED Containment Sump No.-2. Pump-04 6H THED RCP #12 Motor Space Heater-02

, 6M THED -RCP #14 Motnr Space Heater-04 5B -THED Incore Dei ir Drive "C" 2B THED Incore Detenor Drive 'D" 7B THED Incore Detector-Drive "E" 5D THED Containment Fuel Storage Crane-01 3B THED Stud-Tensioner Hoist Outlet-02 48' THED Containment Solid Rad Waste e Compactor '

COMANCHE PEAK - UNITS 1 AND 2 4-10 Revision 8

' June-30, 1992

TECHNICAL REOUIREMENT 4.1 (continued) ,

TABLE 4.1.la (Continued) 8 '

O CONTAINKENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOC.A_1108

3. 480VACfromMotorControlCenters(Continued)

MCC 1EB2-2 G.E. l COMPT. NO. BKR. TYPE SYSTEM PCHERED 108 THED RCC Change Fixture Hoist Drive-01 10F THED Refueling Cavity Skimmer Pump-01 128 THED Power Receptacles (Cont. E1. Pal')

1H THED S.G. Wet Layup Circ. Pump 02 (CP1-CFAPRP-02) 12M THED S.G. Wet Layup Cire. Pump 04

.(CP1-CFAPRP-04) 8H THED RC Pipe Penetration Fan-03 8M THED RC Pipe Penetration Fan-04 SH THED RCP #12 011 Lift Pump-02 SM THED RCP #14 011 Lift Pump-04 __

i 12H THED Preaccess filter Train Package Receptacles - 18 b+ 60 1HED Containment Auxiliary Upper Crane-01

. 2F THED Containment Ltg. XFMR-13 (PNL C2) 70 THED Containment Elevator-01 2D THED Containment Access Rotating Platform-01 2M THED Reactor Coolant Drain Tank Pump-02 9F THED Containment Ltg. XFMR-17 (PNL C8-& C10) 9M THED Containment Ltg. XFMR-15 (PNL C4 & C6) 3M THED Preaccess Fan 1G THFK Distribution Panel 1EB2-2-1 7 CP1-EPDPNB-24 7 3.3 Device Location - MCC 1EB3-2 Containment numbers listed below.-

Primary and Backup - Unless noted otherwise,-both primary and backup breakers have identical trip ratings and are i

located in the same MCC compt.

These breakers are General Electric-(] type THED or THFK with thermal-N._/ magnetic trip elements.

l COMANCHE PEAK - UNITS 1 AND 2 4-11 Revision 8 June 30, 1992-

_. _ _ . _ _ . _ _ _ . ~ _ _ _ ..__._._._._ _._ _ _ ___..___ ,

j TECHNICAL RE0VIREMENT_4.1-(continued) ;

TABLE 4.1.la (Continued) 8-UNIT 1 8-l CONTAINMENT PENETRATION CONDUCIOR

, QYERfURRENT PROTECTIVE DEVILLS

! DEVICE NUMBER

! AND LOCATION i

3. 480VACfromMotorControlCenters_(Continued) l MCC 1EB3-2 G.E.

l COMPT. NO. BKR. TYPE SYSTEM POWERED- o L - .

i

! BRF THED JB-IS-10050, Altern. Feed to-Motor = -i i _ Operated Valve 1-8702A l_ 1G -THED -Motor Operated-Valve 1-8112' ,

t 9G THED -Motor Operated Valve 1-8701A' '

9M THED Motor Operated Valve 1-8701B

- 5H THED . Motor Operated Valve 1-8000A i- SG THED Motor-Operated Valve-1-HV-6074 '

4G THED Motor Operated Valve 1-HV-6076.

1, 4M THED* Motor Operated Valve 1-HV-6078--

! 2G THED Motor Operated Valve 1-HV-4696 l- - 2M THED Motor _0perated Valve'l-HV-4701

! 3G THED*- Motor Opert ted-Valve 1-HV-5541 ,

!g - 3M THED* Motor Operated Valve 1-HV-5543-1H THED Motor Operated Valve.1-HV-6083:

l~

9 6F THED _ Motor Operated Valve 1-HV-8808A l 6M THED -Motor Operated Valve 1-HV-8808C 7H THED Containment Ltg. XFMR-18~

.(FNL SC1~& SC3)_ ,

i BM THED Neutron Detector'Well Fan-09. :

7F THFK -Electric H .Recombiner 2 Power: '

! Supply PNL-01< .

BRM THED' ~ Motor Operated Valve 1-HV-4075C-- :

- 9RF THED. Motor Operated Valve 1-HV-4782

, 9RM THED Motor Operated Valve-l-8811A_ ,

i

*- Primary protection is provided by Gould Tronic TR5 fusible switch..

with-3.2A fuse.

~

g-

U c

+

COMANCHE-PEAK:--UNITS 1!AND 2 4 - Revision 8~

~

Junel30,-1992: .

w m > ve=%r,-er- e--t + St w ' bv~+- vr ~ee'" -w v-yw -r - 1.tr ue- t "m' w v t# r ev+-'y <-ev-*<"+- M * ' * - " v r' ***t*= = , ua e s -e% e v *- 4 ee d + -~w- - w o-- J

TECHNICAL REQUIREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8 ,

UNIT 1 8 CONTAINMENT PENETRATION COM0UCTOR OVERCURRENT PROTECTIVE DEVICES ,,

DEVIO (?"9aER AND low ,

3. 480VACfromMotorControlCenters(Continued)

~i Nvice Location - MCC 1EB4-2 Containment numbers listed below.

i and Backup - Unless acted otherwise, both primary cnd backup breakers have identic.C trip ratings and are ,

located in the same MCC compt. '

These breakers are General Electric ,

type THED or THFK with thermal-

. magnetic trip elements.

MCC 1EB4-1 G.C.

[f/_i2T;L SKR. TYPE SYSTEM POWERED

. IM THED JB-1S-1230G, Altern. Feed a to Motor Operated Valve 1-8701B F 8G THED Motor Operated Valve 1-8702A Cii THED Motor Operated Velve 1-87028 4M THEG Motor Operated Valve 1-80008 a 4G 'HED Motor Operated Valve 1-HV-6075 $

3G 1HED Motor Operated Valve 1-HV-6077 3M THEE' Motor Operatei Valve 1-HV-6079 2G THED Motor Operatei Valve 1-HV-5562 2M THE0* Matcr Operated Valve 1-HV-5563 SF THED Motor Operated Valve 1-8808B 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 Po"er Supply PNL-02 8RF THED Motor Operated Valve 1-HV-4783 6RM THED Motor Operated Valve 1-88118

Primary protection-is provided by Gould Tronic TR5 fusible switch with 3.EA fuse.

COMANCHE PEAK - UNITS 1 AND 2 4-13 Revision 8 June 30,=1992

TECHNICAL REOUIREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8-in Cl UNIT 1 B CONTAINMENT PEIETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES F DEVICE NUMBER SYSTEM AND LOCATION P_DK!lEQ

4. 480VAC From Pane 1 boards For Pressur er

Pressurizer Heaters Heaters (1) grw ps A, B, & D

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

Breaker No.-& Location-- Ckt. Nos. 2 thru 4 of Panelboards-l 1EB2-1-2, 1EB3-1-2,'1EB4-1-1, -3 1EB4-1-2 and Ckt. Nos. 2 thru 5 3 of-Panelboards'1EB2-1-1 and- 3 1.EB3-1-1. -3

b. Backup Breakers --General Electric Type THJS with longtime -

and insts, solid state trip devices with 400 Amp. sensor.

, q#

Breaker No. & Location - Ckt. No. 1 of Pane 1 boards 1EB2-1-1, 1EB2-1-2, iEB3-1-1, 3-1EB3-1-2, 1EB4-1-1 and 1EB4-1-2. 3 (2) group C

a. Primary Breakers - General Electric Type THED breakers.

Breaker No. and Location - For both'1EB1-1-1 & 1EB1-1-2 '

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 1E31-1-1 & 1EB1-1-2.- 3

5. 120V Space Heater Circuits Contahment from 480V Switchgears Recirc. Fan-and CRDH Vent.

Fan Motor Space Heaters

-i. ,) ,

'w]

-COMANCHE PEAX : UNITS'1 AND 2 4-14.- Revision 8 June 30.-1992

4 TECHNICAL REOUIREMENT 4.1 (continued) 16BLE 4.1.la (Continued) 8

-s

.Uhll_1 8 CONTAINMENT-PENETRATION CONDUCTOR OVERCURRENT PR01ECTIVE DEVICES

5. 120VSpaceHeaterCircuitsfrom480VSwitengears(Continued)

a. Primary Devices - N/A (Fuse) 2

b. Backup Breakers 2 BKR. LOCATION WESTINGHOUSE

& NUMBER BKR'. TYPE i

Swgr. 1EB1, EB1010 7

Cubicle 3A,

. CP1-VAFNAV-01 Space-Heater 6kr.

Swgr. 1EB2, EB1010 Cubicle 3A, CPI-VAFNAV-02 Space Heater Bkr.

, ,i L Swgr. 1EB3, ED1010 Ct.bicle 9A, CPI-VAFNAV-03 Space Heater Bkr.

1 Swgr. IEB4, EB1010 Cubicle 9A, 2

Cl1-VAFNAV-04 Space Heater Bkr.

-Swgr. 1EB3,- EB1010 Cubicle 8A, CP1-VAFNCB-01

Space Heater Bkr.

Swgr. 1EB4, EB1010 Cubicle 8A, CP1-VAFNCB-02 Space Heater Bkr.

A.

!\_) . -

COMANCHE PEAK - UNITS.1 AND 2 4-15_. Revision'8 JL:^ 30, 1992

q TECHNICAL REOUIREMENT 4.1 (continued)

TABLE 4.1.la (Continued) 8 i (G_) UNIT 1 8 CONTAINMENT PENETRATION CONDUCTOR l OVERCURRENT PROTECTIVE DEVICES-DEVICE NUMBER , SYSTEM

' 1 AND LOCATION POWERED

6. 125V DC Control Power- Various-a.PrimaryDevices-N/A-(Fuse) ;

b. Backup Breakers GENERAL ELECTRIC-l PANELBOARD N L CKT. NO. BREAKER-TYPE l XED1-1 1,6 TED 1,3,6 XED2 TED XD2-3 8 TE9 1 1ED2-1 14,17 TED '

1E01-1 14 TED 2 102-3 7,10 _TED-102-2 9- TED-1ED2-2 12 TED-h) 1ED3-1 1ED1-2 7,8 5 TED TED-TBX-WPXILP FB(Westinghouse)

Main (LBK3) l1 .

7. 120 V AC Control Power from_ Isolation XFMR 1XEC3 & TXEC4 [1 a.PrimaryDevices-N/A(Fuse) 1

b. Backup Breaker - Square D Type Q1l located in I1 Miscellaneous Signal Control. Cabinet. 1

8. 120V AC Power for Personnel _and Emergency Airlocks a.-Primary Devices - N/A-(Fuse)

b. Backup Bret.kers

" GENERAL ELECTRIC-EsNELBOARD NO.- (KTJ_L BREAKER TYPE XEC2 34 TED XECl-2 2 TED w:

1.

' COMANCHE PEAK. UNITS 1 AND 2 4-16 ._ Revision 8-June-30 1992-

A

TECHNICAL-REOUIREMENT 4.1 (continued)

, = TABLE 4.1.la (ContinuedF 8-O UNIT 1 ja CONTAINMENT PENETRATION CONDUCTOR

- QVERCURRENT PROTECTIVE DEVICES - .

E DEVICE NUMBER AND LOCATION 9, 118V AC Control Power l

! a.PrimaryDevices--N/A(Fuse) '

j. b. Backup Breakers GENERAL ELECTRIC.

PANELBOARD NO. CKT.-NO.' BREAKER TYPE 1C2 22 TED' 1PCI 10,13 TED 1PC4 6,10 -

TED-1EC1 7- -TED~ 2

, 1EC2 7 TED .2 1EC5 8 TED

~

1EC6 3,8 - TED 1:

l'0. Emergency Evacuation System Warning. Lights: Power

a.--Primary Devices 'N/A (Fuse)._

-b. Backup Breakers

. :SQUARELDL .

PANELBOARD NO. CKT;'NO. ' BREAKER TYPE: ,

L XEC3-3 = 9, - 10 FAL-12020 ' 1 e

11. DRPI Data Cabinet-Power' Supplies a.-Primary Brer.kers 12 2

SQUARE 0- -2; PANELBOARD NO. CKT. NO. LBREAKER TYPE !2 ,

IC14 1,2 FA-14050A. t2-

b. Backup, Breakers-J

. .. SQUARE D-PANELBOARD NO. CKT.-NO.

BREAKER TYPE-IC14 Main Pnl. Bkrs.: LFS-14070A- 2.

c

.. COMANCHE PEAK . UNITS 1/AND 2- .4-17 -Revision 8

! June 30,f1992=

)

TECHNICAL RE0VIREMENT 4.1 8 TAbiE 4.1.lb 8.

k, UNIT 2 -8 CONTAIL ENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 AND LOCATION POWERED 8

1. 6.9 KVAC from Switchgears 8

a. Switchgear Bus 2A1 RCP #21 8

1) Primary Breaker 2PCPX1 8 a Relay 50M1-51 8 b Relay 26 8 c Relay 86M 8 d ' Relay 51M2 8

2) Backup Breakers 2Al-1 or 2Al-2 8 a) Relay 51M3 8 b) Relay 86/2A1 8

b. Switchgear Bus 2A2 RCP #22 8

1) Primary Breaker 2PCPX2 8 a Relay 50ML-51 8 b Relay 26 8 c Relay 86M 8 d Relay 51M2 8

2) Backup Breakers 2A2-1 or 2A2-2 8 a) Relay 51M3 8 b) Relay 86/2A2 -8 f')

s_/-

COMANCHE PEAK = UNITS 1 AND 2 4-18 Revision 8 !

June 30, 1992

TECHNICAL REQUIREMENT 4.1 (continued) 8 TABLE 4.1.lb (Continued) 8 O)

( UNIT 2 S CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 4 AND LOCATION POWERED 8

1. 5.9KVACfromSwitchgears-(Continued) 8 8

c. Switchgear Bus 2A3 RCP #23 8

1) Primary Breaker 2PCPX3 8 a Relay 50M1-51 8 b Relay 26 8 c Relay 86M 8 d Relay 51M2 8

2) Backup Breakers 2A3-1 or 2A3-2 8

a) Relay 51M3 8 b) Relay 86/2A3 8

d. Switchgear Bai %4 RCP #24 8 U 1) Primary Breaker 2PCPX4 8 a Relay 50M1-51 8 b Relay 26 8 c Relay 86M 8 d) Relay 51M2 8

2) Backup Breaker 2A4-1 or 2A4-2 8 a) Relay 51M3 8

b) Relay 86/2A4 8

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

a. Primary Breakers - 2FNAV1, 8 2FNAV2, 2FNAV3, 2FNAV4, 8

'2FNCB1 and 2FNCB2 8 LJ -

COMANCHE PEAK - UNITS 1 AND 2 4-19 Revision 8 June 30. 1992'

TECHNICAL REOUIREMENT 4.1 (continued'i' 8

,.3 _

TABLE 4.1.lb (Continueo) 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8 D"VICE NUMBER SYSTEM 8-MD LOCATION POWERED 8

2. 480VACfromSwitchgears-(Continued). 8

b. Backup Breakers - 2EB1-1, 8 2EB2-1, 2EB3-1 and 2EB4-1, 8 --

.BT-2EB13 and BT-2EB24- 8

1) Long Time & Instantaneous Relays

P 52/51 (2EB1-1) EQL51 (2EB2-1) 8 2FNAVl_ 2FNAV2 8 10251 (2EB3-1) 5HZ51 (2EB4-1) 8 8

2FNAV3 2FNAV4 5D151 (2EB3-1) 1Q/51 (2EB4-1) 8

, 2FNCBI 2FNCB2 8

. 8 s .'

(j 2) Time Delay Relays

8 52-1 (2EB1 $1-1X (2FNAV1) 8 2FNAV1- and 2FNAV1 8 BT-2EB13) 8 52-1 (2EB2-1 61-1X (2FNAV2) 8 2FNAV2 and 2FNAV2 8 BT-2EB24) _8 61 -1 (2EB3-1' 52-1X (2FNAV3) 8 2FNAV3 and 2FNAV3 8 BT-2EB13) -8 62-1 (2EB4-1 62-11 -(2FNAV4) 8 2FNAV4 and 2FNAV4 8-

BT-2EB24) _8 62-1 (2EB3-1 62-1X (2FNCB1)- 8 2FNCB1 and 2FNCB1 8 BT-2EB13) 8 62-1 (2EB4-1 62-lX (2FNCB2) 8.

2FNCB2 and 2FNCB2 8 BT-2EB24) 8-L '- - 8

Associated circuit breaker shown in pa',entheses; e.g., 2EB1-1, is 8 backup breaker for 2FNAV1.

COMANCHE PEAK - UNITS 1 AND 2 4-20 Revision-8 June 30, 1992

TECHNICAL REOUIREMENT 4.1 (continued) 8 TABLE 4J.lb(Continued) 8 UNIT 2 8 CONTAINMENT PEETRATION CONMC10R 8 OVERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8

&ND LOCATION POWERED 8 2.2 Device Location - 480V Containment 8 Switchgear 2EB4 Polar Crane 8

a. Primary Breaker - 2SCCP1 8

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

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

2) Time Delay and Instantaneous Relays

8 62 (2EB4-1 and 62X (2SCCP1) 8 2SCCP1 BT-2EB24) 2SCCP1 8 8

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

Associated circuit breaker (s) shown in parantheses; e.g. 2EB4-1 8 and BT-2EB24 are backop breai<ers for 2SCCPl.

i

_J COMANCHE PEAK - UNITS 1 AND 2 4-21 Revision 8 June 30,.1992

I TECHNICAL REOUIREMENT 4.1 (continued) 8 m TABLE 4.1.lb (Continued) 8-UNIT 2 8 ,

CONTAINMENT PENETRATION CONDUCTOR 8 QyERCURRENT PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 480fromMotorControlCenters(Continued) 8 MCC 2EB1-2 G.E. '8

@MPT. NO. BKR. TYPE SYSTEM POWERED 8 4G THED Motor Operated Valve 2-TV-4691 8 4M THED Motor 0perated Valve 2-TV-4693 8

- 3F THED Containment Drain Tank Pump-03 8 9H THED Reactor Cavity Sump Pump-01 8 9M THED Reactor Cavity _ Sump Pump-02 8 7H THED' Containment Sump fl Pump-01 8 7M THED Containment Sump #1 Pump-02 8 --

6H THED RCf #21 Motor Space Heater 8 6M THED RCP #23 Motor-Space Heater-03 8 8B THED Incore Detector. Drive "A" 8 80 THED Incore Detector Drive "B" 8 p 7B THED Incore Detector Drive "F" 8

'V 3B THED Stud Tensioner Hoist Outlet-01 8

, 70 THED Hydraulic Deck Lift-01 8 4B THED Reactor Coolant Pump Motor 8 Hoist Receptacle-42 8 8H THED RC Pipe Penetration Cooling 8 Unit-01 8 8M THED RC Pipe Penetration Cooling 8 Unit-02 8 5H THED RCP #21 011 Lift Pump-01 8 SM THED RCP #23 011 Lift Pump-03 _

8 108 THED Preaccess Filter Train Package 8 Receptacle-17 _

8-5B THED Containment-Ltg. XFMR-14 8 (PNL2LPC3) 8

. 10F THED S.G. Wet Lcyup Circ. Pump 01 8 (CP2-CFAPRP-01) 8 12M THED S.G. Wet'Layup Circ. Pump 03 8 (CP2-CFAPRP_-03) 8 12H THED Containment Ltg. XFMR-28. -8 (PNL 2C11 & PC12) 8'

(

(~

LJ i

COMANCilE PEAK - UNITS 1 AND 2 4-22 Revision 8 June 30, 1992

TECHNICAL RE001REMENT 4.1'(continued) 8 TABLE 4.1.lb (Continued) 8

.r\

C/ UNIT 2 8 CONTAINMENT > PENETRATION CONDUCTOR 8 OVERCURRENT PRO 1ECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

3. 480VACfromMotorControlCenters(Continued)- 8 1

MCC 2EB1-2 G.E. 8 l COMPT. NO BKR. TYPE S.YSTEM POWERED 8 6D THED RefuelingMachine(Manipulator _ 8 Crane-01) 8-2M THED RC Drain Tank Pump No. 1 8 2F THED Containment Ltg. XFMR-16 8 (PNL 2C7 & 2C9) _8 1M THED Containment Ltg. XFMR-12 8.

(PNL 2LPC1 & 2LPC5) 8 3M THED Preaccess Fan No. 11 - 8 50 THED Fuel Transfer System Reactor -8 Side Cont. Pnl. for TCX-FHSTTS-01 8 3.2 Device Location - MCC 2EB2-2 Containment Numbers 8 listed below. 8 PrimaryandBickup-Bothprimaryandbacdupbreakers 8 Breakers .have identical trip ratings and are 8 loceted in the same MCC compt. 8 These breakers ire General Electric 8 type THED and THFK _with thermal- 8 magnetic trip elements. 8

'MCC 2EB2-2 G.E. 8 COMPT. NO. BKR. TYPE 3.Y._ STEM POWERED _ 8 4G THED Motor Operated. Valve 2-TV-4692 8 4M THED Metac Cperated Valve 2-TV-4694 8 3F THED Coni.sinment Drain Tank Pump-04 -8 .l 7H TPED Containment _ Sump No. 2 Pump-03 8

, 7M THED Containmerc $ ump No.--2 Pump-04 8 )

6H THED RCP No. ?.2 riotor Space _ Heater 8 6M THED "CP No. 24 Motor Space Heater-04 8 I Incore Detector Drive "C" 5B THED 8 2B THED Incore Detector Drive "D" 8 7B THED Incore Detector Drive "E" 8 50 THED Containment Fuel Storage Crane-01 8 38 THED Stud-Tensioner Hoist Outlet-02: 8 4B THED Containment Solid Rad Waste 8 r~N_ Compactor-01 '8 b

COMANCHE PEAK - UNITS 1 AND 2 4-23 Revision 8' June 30, 1992

4

^

TECHNICALDREOUIREMENT 4.1 (continued) j [8 -

i-

- .. TABLE-4.1.lb4(Continued) 8:

-%f --

i UNIT 2-

, -l: 8 CONTAINMENT PENETRATION CONCUCTOR 8

OVERCURRENT~ PROTECTIVE CEVICE$ 8-l DEVICE NUM8ER 8

-AND LOCATION . 8- ,

3. 480VAC'fromMotorControl' Centers _(Continued)- 8 l

l MCC 2EB2-2 G.E. -8 COMPT. NO. BKR. TYPE SYSTEM POWERED 8' i 10B THED RCC_ Change Fixture Hoist Drive-01 8:

c 10F THED Refueling CavitysSkimmer Pump 8 a 128 IHED Power, Receptacles:(Cont. El. 8;

[ 841'). . .

8 ;

?S.G.' Wet Layup C.re.; Pump 02: '8i

~

l 1H . THED _

(CP2-CFAPU-02) 8-

12M THED S.G. Wet-Layup Circ. Pump:04

'8 (CP2-CFAPRP-04). ~8'

, 8H; THED RC P Ve Penetration Fan-03 '8

BM THED .RC: Pipe Penetration Fan-04 8

! 5H THED RCP #22!011-Lift Pump B ;-

} SM -THED RCP #24~011; Lift Pump-04: .; 8

! 12H THED ._Preaccess Filter Train' Package 1 -8:

! b Receptacles - 18' . __

' ~

8 60 THED Containment: Auxiliary ' Upper ~

r l Crane-01 L3:

, 2F THED Containment Ltg.'XFMR-13-(PHL/ _8 L

'- '2LPC2) . . .

8 7D THED Containment Elevator-01.. '8 i: 2D THED Containment; Access-Rotating; :81 Platform . - . _.. .__ _ . 8-p 2M THED . Reactor Coolant: Drain Tank Pump-02

8-

EF THED. Containment Ltg. XFhF.-17 8

r

-(PNLJ2C8 & 2C10)E_ _8 y Containment:Ltg. XFMR-15 ' ~

9M .THED ' 8 L;

-(PNL 2LPC4t& 2LPC6)- '84 3M 'HED. - Preaccetrc- Fan-12.- -

'8 id THFK- Distribution-Panel:1E82-2 8 i: cpi-EPDPNB-24' .

~8) l_ IC THFK Containment Welding, Receptacles _ -

8' H P

~

3.3 ' Device Location -MCC.2EB3-2LContainment numbers 18 listed below.. :8 Primary and. Backup: -Unless noted ot)erwise, both 8'

. -primary and backup breakers have- 8:

identical: trip ratings and are. 8-located,in the same MCC' compt.

.A

'~e' i These breakers are General:Electrici 8

~

type: THED.or--THFK with thermal- 8-

. : magnetic trip elements. 8 t

-COMANCElE PEAK , UNITS 1-AND'2- 4-24. Revision"8-

~ '

, s-- June 30,w1992 1.a um . . -- , . _ - . ....~.;., . _ , _ , . --._.. _ .-_ - ,_., _, . . _ _ . . .

TECHNICAL REOUIREMENT 4.1 (continuedi 8 TABLE 4.1.lb (Continued) 8 b

\,./

UNIT 2 8

[SMIAINMENT PENETRATION CONOUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8'

DEVICE NUMBER 4

AND LOCATION

3. 480VAC from Motor Control Centers (Continued) 8 MCC 2EB3-2 G.E. 8 COMPT. NO. 8KR. TYPE SYSTEM PO',-lERED 8 8RF THED Alte n. Feed.to Motor. 8-Operated Valve 2-8702A~ 8-1G T::ED Motor Operated Valve 2-8112- 8

9G- THED Motor Operated' Valve 2-8701A 8-9M THE0 Motor Operated Valve 2-8701B 8-SM THED Motor Operated Valve 2-8000A _8 SG THED lotor Operated Valve 2-HV-6074 8 l 4G THED Motor Operated Valve 2-HV-6076 8 4M THED* Motor Operated Valve.2-HV-6078- 8

. 2G THED Motor Operated Valve 2-HV-4696 8 2M THED Motor Operated Valve,2-HV-4701 ~8 3G THED Motor Operated Valve 2-HV-5541 8 3 3:4 THED Motor: Operated Valve 2-HV-5543 -8

.- u. 1M THED Motor Operated Valve 2-HV-6083 8 l 6F THED Motor Operated Valve 2-HV-8808A 8 6M THED Motor Operated Valve 2-HV-0808C- 8-7M THED Containment Ltg. XFMR-18 8 (PNL 23C1:& 2SC3) _. 8 8M THED Neutron Detecter:Well Fan-09 8 7F THFK Electric H .Recombiner 2 Power 8-

!- Supply PHL-01 .-- ~

8 8RM THED Motor Opera.ted Valve 2-HV-4075C -8 9RF- -THED Motor Operated Valve 2-HV-4732- 8 9RM THED Motor Operated talve 2-8811A 8-(

_ Primary protection is provided by_Gould Tronic.TRS fusible switch

_8-with 3,2A fuse,

)

f J.

~

1 COMANCHE PEAK - UNITS 1 AND'.2 4 Revision 8-

. June 30.-1992

~ - - , .n,-- ,~, - , - . . . , , , , , -. , ,e - ,, , , ,

JECHNICAL REOUIREMENT 4.1 (continued). 8 TABLE 4.1.lb (ContinuedP 8 --

UNIT 2 8 CONTAINMENT-PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES 8-DEVICE HUMBER 8' AND LOCATION 8.

3 .,

480VACFromMotorControlCenters(Continued) 8 W

3.4 Device Location - MCC 2EB4-2 Containment numbers 8 listed below.' 8 .

Primary and Backup --Unless noted otherwise., both 8 primary and backup breakers have' 8

identical trip ratings and are: .8 .

located in the same MCC, compt. 8 These breakers are General 8-Electric type THED or THFK with 8 thermal-magnetic trip elements. 8 MCC 2EB4-2 G.E. 8

[DMPT. NO. BKR. TYPE SYSTEM POWERED 8.

1M THED Altern. Feed to Hotor 8 Operated Valve 2-87018- 8-8G THED Motor Operated Valve 2-8702A 8 4

SM THED Motor Operated Valve 2-87028 8-4M THED Motor Operated Valve'2-8000B 8 4G THED Motor. Operated Valve.2-HV-6075' 8 3G THED Motor Operated Valve 2-HV-6077 8 .

-Motor Operated Valve 2-HV-6079 3M THED* 8 2G THED* Motor Operated Valve 2-HV-5562 8-2M .THED* Motor-Operated Valv_e 2-HV-5563- 8 SF THED Motor. Operated Valve 2-88088 8 5M THED Motor-Operated Valve 2-88080 8 6M THED Containment Ltg. XFMR 8 (PNL 2SC2 & 2SC4) 8-7M THED Neutron Detector Well Fan-10 8L 6F THFK E %ct. H2 Recombiner Power 8-Supply PNL-02 8 BRF THED . Motor Operated Valve-2-HV-4783 8 Motor Operated Valve 2-8811B

~

8RM THED 8' 8

Primary protectica is provided by Gould Tronic TR5 fusible switch 8

.O with 3.2A fuse.

d

~

COMANCHE PEAK - UNITS 1 AND 2 4-26 Revision 8-June'30, 1992

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

' TECHNICAL RE0VIREMENT 4.1 (continuedF 8

. TABLE-4.1.lb (Continuedi 8 UNIT 2 8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT-PROTECTIVE DEVICES 8 DEVICE NUMBER SYSTEM 8 AND LOCATION f1E8fD - 8

4. 480VAC From Panelboards For Pressurizer 8 Pressurizer Heaters Heaters 8 (1) group: A, B, & D 8

a. Primary Breakers - General Electric Type TJJ Thernal 8 Magnetic breekers. 8

Breaker No. & Location - Ckt. Nos. 2 thru 4 of Panel 8 boards 2EB2-1-2, 2EB3-1-2, 8 2EB4-1-1, 2EBo-1-2 and Ckt. -8 Nos. 2 thru 5 of Pane 1 boards 8

2EB2-1-1 and 2EB3-1-1. 8

^

b. Backup Breakers - General Electric Type THJS with 8

longtime and insts solid state 8 trip devices with 400 Amp. sensor. 8

(r)

Breaker No. & Location - Ckt. No. 1 of Panelboards 2EB2-1-1, 2EB2-1-2, 2E03-1-1, -8 8

2EB3-1-2, 2EB4-1-1 and 2EB4-1-2. 8 8

(2) group C 8

a. Primary Breakers - General Electric Type THED 8 breakers. 8 t

Breaker No. and Location - For both 2EB1-1-1 & 2r.P.i-1-2

'8 are located -at Ckt. Nos. i' 8 thru-4. -8

b. Backup Breakers - Genera' Electric Type TJJ-Thermal 8 Magnetic breakers. 8-Breaker No and Location .Ckt Nos. 2-thru'4 of Sw~tch- 8 boards 2EB1-1-1 & 2EB1-1-2. 8

5. 120V Space Heater Circuits- Containment. '8 from 480V Switchgears Recirc. Fan- 8 and-CRDM- 8 Vent Fan Motor 8 Space Heaters 8 f~'.

COMANCHE PEAK - UNITS 1 AND 2- 4-27 Revision 8-

' June 30, 1992

6 TECHNICAL RE0VIREMENT.4.1 (continued) 8 ,

TABLE 4.1.lb(Continued) 8-(-)\

s UNIT 2-8 CONTAINMENT PENETRATION CONDUCTOR 8 OVERCURRENT PROTECTIVE DEVICES '8

5. 120VSpaceHeaterCircuitsfrom480VSwitchgears(Continued) 8-

a. PrimaryDevices-N/A(Fuse) 8

b. Backup-Breakers '8 BKR. LOCATION- WD TINGHOUSE 8

, & NUMBER BKR. TYPE I 8

Swgr. 2EB1, EB1010 8 Cubicle 3B, CP2-VAFNAV-01 8 Space Heater Bkr. ,

-8 Swgr. 2EB2. EB1010 8 Cubicle 3B, 8 CP2-VAFNAV-02 8 Space Heater Bkr. 8

'G Swgr. 2EB3, EB1010 8 V Cubicle 9B, CP2-VAFNAV-03 8

8 4

Space Heater Bkr. 8 Swgr. 2EB4, EB1010 8 Cubicle 93, 8 CP2-VAFNAV-04 8-Space Heater Bkr. 8 Swgr. 2EB3, EB1010; -8 Cubicle 88, 8 CP2-VAFNCB-01 -8 Space Heater Bkr. -8 Swgr. 2EB4, EB1010 8 'I Cubicle 88, 8-CP2-VAFHCB-02 8 Space Heater Bkr. 8 Ci Qf COMANCHE PEAK - UNITS'l AND 2 4-28 -Revision 8-June 30, 1992

TECHNICAL RE0VIREMENT'4.11 continued) 8; j TABLE 4.1.lb'(Continued). 8 -

c- , UNIT 2 :8 ;;

1 CONTAINMENT PENETRATION CONDUClQB '

OVERCURRENT PROTECTI'" '2Q]C[1 DEVICE-NUMBER SYSTEM- 8 AND LOCATION POWERED 8

6. 125V DC Control. Power Various 8-a.PrimaryDevices-N/A-(Fuse)_ 8 i

b. Backup Breakers 8 GENERAL ELECTRIC- 8-PANELBOARD NO. sKT. NQ,, BREAKER' TYPE 8 ,

, XED1 .6 TED 18' XED2-1 -6 TED -8 -

2ED2 11,17,16' TED h

- 11;14 '

2E01-1 .:TED 8 202-3 G,10,11 TED- 8 -;

202-2 9 ;TED? 8 2E02-2~ 12 TED: 8 2E03-1 5: .TED_ :8 2E01-2 -7,8 -

-TED . 8 T8T WPXILP-01 Main (LBK3) FB(Westinghouse) 18 :

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

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

b. Backup Breaker - Square D Type Q1L.; located in; 8 Hisct=11aneous1 Signal Control-Cabinet.- -8 8.. 120V AC Power for-Personnel and Emergency Airlocks- 8~

a. Primary Devices:- N/A'(Fuse) 8 g b.~ Backup Breakers- 8- q

~ GENERAL ELECTRIC; 8^

PANELBOARD NO. CKT. N0; BREAKER-TYPE- :- 8 XEC1 12< x :TED=

=8:

XEC2-2 3- 'TED-8L *

= .

r o '-

1

" ~

COMANCHE PEAX - UNITS'1 AND 2: '

L4-29. . Revision.8: --

cJuneL300 1992L

--.......-,..-.,w..-, . . . . . - . - . . , - - . , . - , . , . . . .

. ,J. . .. . a. . . ,

TECHNICAL REOUIREMENT 4.1 (continued) -8 4 -

_ -TABLE 4.1.lb (Ccntinued) 8 UNIT 2-

]8 CONTAINMENT PENETRATION CONDUCTOR 8 DyfRCURRENT -PROTECTIVE DEVICES 8 DEVICE NUMBER 8 AND LOCATION 8

9. 118V AC Control Power- B'

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

b. Backup Breakers 8-GENERAL ELECTRIC 8-1 PANELBOARD NO. CKT. NO. BREAKER TYPE __. 8.

2LPC2 22 TED 8

, 2PC1 10,13 TED 8 2PC4 6,10 TED- 9 2EC1 7 TED 8-

,' 2EC2 4,7 TED 8 --

2EC5 8 TED 8 2EC6 3,8 TED '8

10. Emergency Evacuation System Warning Lights Power '8

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

b. Backup Breakers 8

~ SQUARE D 8 PANELBOARD NO. CKT. NC . ~ BREAKER TYPE 8

^

XEC4-3 9, 10 FAL-12020 8-8-

11. DRPI Data Cabinet Power Supplies- 8

a. Primary Breakers '8 8

SQUARE D -8 PANELB0f.RD NO. CKT. NO. BREAKER' TYPE- 8 6.

2C14 1,2_ FA-14050A b.' Backup Breakers 8 SQUARE D' -8 PANELBOARD NO. CKT. NO. R BRLAKER TYPE 8 2C14 . Main Pnl. Bkrs. F5-14070A 8 CORANCHE PEAK - UNITS 1-AND 2 A-30 Revision 8-'

, ' June 30, 1992 .

~ . . . . - - . . -

+

i

~ BASES l

4.1 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT-PROTECTION DEVICES O'

The bases'for OPERABILITY and surveillance of these devices are '

contained in the'CPSES Technical Specifications.z All Class 1E motor-operated valves' motor' starters are.provided with thermal overload protection which is: permanently: bypassed and provides.

an alarm function only at . Comanche Peak Steam Electric Station.-

Therefore, there are no-0PERABILITY:or-Surveilla'ce. Requirements for.- -

these devices, since they will not' prevent? safety-related: valves from performing their function (refer to Regulatory Guide 1.106,i"Thernal Overload Protection for Electric Hotors on' Motor Operated Valves,"

Revision 1, March;1977).

i LO i

i 4

i i

l L

V..

L

1. -

L.

t, b

(-

l COMANCHE' PEAK -: UNITS 1-AND.2- =4-311 June!30,11992

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

TECHNICAL REQUIREMENTS MANUAL:

EFFECTIVE-PAGE LISTING-

BELOW IS A LEGEND FOR THE EFFECTIVE PAGE LISTING

Original Submitted July 21, 1989 Revision 1 September 15,-1989 Revision 2 January 15, 1990 Revision 3 July 20,L1990 Revision 4 April 24,-1991

,, Revision 5 September 6, 1991 Revision 6 November 22, 1991

- Revision-7 March 18, 1992 Revision 8 June 30,-.1992--

-p);

q . .

EPL-i- June 30.-1992-

i. 2 2.. - __ . . _

TECHNICAL REQUIREMENTS MANUAL EFFECTIVE PAGE LISTING.

i TRM-Tab Original TRM-Title Pr.ge June-30,11992-

. Table of Contents-Tab Original 4

i June 30, 1992:

! Administrative Controis-Tab _

Original

Administrative Controis-Title Page June 30, 1992

0-1 June 30, 1992 i 0-2 Revision 8 i 0-3 June ~30, 1992-0-4 June 30, 1992 3

0-5 June 30, 1992'

0-6 June 30, 1992 0-7 June 30,-1992-0-8 June 30, 1992-0-9 June 30, 1992 0-10 -June 30, 1992-'

0-11 -

-Revision 8-l 0-12 June 30,.1992.

0-13 June-30,-1992

) 0-14 June-30,.1992 0-15 June 30, 1992 0-16 Revision 8 0-17 June 30, 1992 0-18 June 30,.1992 0-19 Revision l8 0-20 Revision 8 0-21 Revision 8 0-22 Revision 8' 0-23 Revision:8 0-24 -Revision 8 0-25 Revision 8

'- 0-26 Revision 8'-

Technical Requirements-Tab Original-

-Sec.-1-Tab Original 4

1-1 June 30,-1992 1-2. Revision 8 -

4 1-3 -June 30', 1992.

1-4 June 30,-1992 4

1-5 -. June ;30, 1992

.1-6 Revision 8 1-7 June 30, 1992

'l-8 June 30,c1992 1-9 ' Revision 8 1-10 -Revision'8 1-11 Revision 8 ;

1-12 Revision 8 1 1-13 Revision 8 l TN 'l-14 - June 30,1992 V 1-15 Revision 8-

\

EPL-1 June 30, 1992.

? '

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

f TECHNICAL REQUIREMENTS MANUAL EFFECTIVE PAGE LISTING 1-16 June 30, 1992 1-17 Revision 8

1-18 Revision 8-1-19 Revision 8 1-20 Revision 8 1-21 June 30, 1992 1-22 Revision 8 Sec. 2-Tab Original 2-1 June 30 -1992 2-2 Revision 8 2-3 June 30, 1992 2-4 Revision 8 2-5 Revision 8 2-6 Revision 8 2-7 Revision 8 2-8 Revision 8 2-9 ,

Revision 8 2-10 Revision 8 2-11 Revision 8-2-12 Revision'8 2-13 Revision 8 2-14 Revision 8 CT 2-15 Revision 8 U- 2-16 Revision 8 2-17 Revision d 2-18 Revision 8 2-19 Revision 8 2-20 Revision 8 2-21 Revision 8 2-22 Revision-8' 2-23 Revis1un 8 2-24 Revision 8 2-25 Revision 2-26 June'30, 1992 2-27 June 30,1992-Sec. 3-Tab Original-31 -Jun. 30, 1992 3-2 Revision 8 3-3 June 30, 1992 ;

3-4 June 30, 1992 3-5 June 30,-1992J 3-6 June 30,=1992 3-7 June _30, 1992 8 --June 30, 1992 3-9 June 30, 1992 3-10 Revision 8 3-11 June 30, 1992-- i

3-12 Revision 8-3.I 3-13 Revision 8 i

EPL-2 -June 30,-1992

. :n . . . - -.-- - . . - .

s i

-TECHNICAL REQUIREMENTS MANUAL EFFECTIVE PAGE LISTING-

. Sec. 4-Tab Original 4-1 June 30, 1992

- 4-2 Revision 8 4-3 June 30, 1992 J

4-4 June 30, 1992-4-5 Revision 8 4-6 Revision 8 4-7 _ Revision 8 4-8 Revision 8 ,

4-9 Revision 8

! 4-10 Revision 8 4-11 Revision 8 i 4-12 Revision 8

, 4-13 Revision 8:

, 4-14 Revision E-4-15 Revision 8.

4-16 Revision 8

, 4-17 Revision 8 4-18 Revision 8

. 4-19 Revision 8

' 4-20 Revision 8

~ 4-21 Revision 8 4-22 Revision 8 4-23 Revision 8 4-24 Revision 8

4-25 Revision 4-26 Revision 8-4-27 Revision'8 4-28 Revision 8

. 4-29 Revision 8 4-30 Revision 8-4-31 June 30,;1992-EPL-Tab Original EPL June 30, 1992 EPL June.30, 1992 EPL-2 June 30, 1992:

i- EPL'-3 June 30, 1992 L

O -EPL-3 June 30,11992

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

ML20101N941

Text

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