Text

Forwards Draft Rev 0 to Comanche Peak Steam Electric Station Tech Spec Improvement Program Tech Spec Requirements, Per NRC Rev 4a of Sts,For Review
	ML20206H605
Person / Time
Site:	Comanche Peak
Issue date:	11/17/1988
From:	Counsil W; TEXAS UTILITIES ELECTRIC CO. (TU ELECTRIC)
To:	; NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
	TXX-88779, NUDOCS 8811230248
	Download: ML20206H605 (68)
	v • d • e

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TXX-88779 L 4 File > 10014

= r 916 clo Ref i 10CFR50.36 TUELECTRiC November 17, 1988

$$NN, U. S. Nuclear Regulatory Commission Attn: Docutaent Control Desk

. Washington, D.C. 20555

SUBJECT:

' COMANCHE PEAK STEAM ELECTRIC STATION (CPSES)

DOCKET NO. 50-445 CPSES TECHNICAL SPECIFICATION IMPROVEMENT PROGR9i Gentlemen:

As you are aware, the NRC and the nuclear industry have recently recognized the benefits of improved Tech'11 cal Specifications and efforts are currently underway to develop and implement new Standard Technical Specifications which are reflective of the philosophy. Due to the unavailability of the new Standard Technical Specifications (STS), TV Electric must proceed with development of the CPSES Uni'. 1 Technical Specifications based on the NRC's Revision 4a of the STS. Our development efforts are being proposed for the CPSES Technical Specifications. These enhancements include the relocation of certain Technical Specifications, including the CPSES Technical Specification Improvement Program (TSIP).

The attachment to this letter provides a copy of the draft CPSES TSIP l Technical Requirements. These are being provided to allow consideration by the NRC technical c.aiewers, as appropriate, during the "Proof and Review" stage of the Technical Specification approval procesc.

Very tru yours, Rh W. G. Counsil RWH/gj Attachment c - Mr. R. D.inspectors, Resident Martin, Reg.*on CPSES (3 IVco(1 copy))

Mr. R. F. Warnick, NRC (1 cop ) pies Mr. J. H. Wilson, NRC (1 copy Mr. Bob Giardina, NRC (1 copy M

0811230240 001117 5 PDR ADCCKOSOOg4 ne sons o u surer ian can. raw n.w Ilq

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DRAr7 CPSES TECHNICAL SPECIFICATION IMPROVEMENT PROGRAM (TSIP)

TECHNICAL REQUIREMENTS Rev. O

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ATTACHMENT 1 DRAFT CPSES TECHNICAL SPECIFICATION IMPROVEMENT PROGRAM INDEX TECHNICAL REQUIREMENT NUMBER SYSTEM / TITLE REVISION (Related Tech Spec if required) 1.1 (3/4.3.1) Reactor Trip Response Time 0 1.2 (3/4.3.2) ESF Actuation Response Time 0 1.3 Moveable Incore Detection System 0 f 1.4 Seismic Instruments 0 '

1.5 Meteorological Instrumentation 0 .

1.6 Loose Parts Detection System 0 2.1 (3/4.4.6.2) RCS Pressure Isolation Valves 0 3.1 (3/4.6.3) Containment Isolation Valves 0 4.1 (3/4.7.9) Snubbers 0 4.2 Sealed Source Contamination 0 5.1 (3/4.8.4) Containment Penetration Conductor 0 Overcurrent Protection Devices i

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.T ATTACHMENT 1 DRAFT l

TECHNICAL REQUIREMENT 1.1 REACTOR TRIP RESPONSE TIME NOTE: This Technical Requirement contains the Reactor Trip Response Time Table. Although the CPSES Technical Specification is repeated here, in part, care must be taken not to overlook Technical Specification requirements.

i 1.1-1 Rev. 0

4 ATTACHMENT 1 DRAFT 3/4.3 INSTRUMENTATION 3/4.3.1 REACTOR TRIP SYSTEM INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.1 As a minimum., the Reactor Trip System instrumentation channels and interlocks of Table 3.3-1 shall be OPERABLE with REACTOR TRIP SYSTEM RESPONSE TIMES within their limits.

APPLICABILITY: As shown in Table 3.3-1.

ACTION: V)

As shown in Table 3.3-1. y SURVEILLANCE REQUIREMENTS N <

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O 4.3.1.1 Each Reactor Trip System instrumentation channel and interlock b and the automatic trip logic shall be demonstrated OPERABLE by the performance of the Reactor Trip System Instrumentatior. Surveillance 7

Requirements specified in Table 4.3-1. g 4.3.1.2 The REACTOR TRIP SYSTEM RESPONSE TIME of each Reactor trip function shall be demonstrated to be within its li:mit at least once per 18 months. Each test shall include at least one train such that both N

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

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1.1-2 Rev. O l

ATTACHMENT 1 DR L"I Technical Requirement 1.1 Table 1.1.1 REACTOR TRIP SYSTEM INSTRUMENTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE TIME

1. Manual Reactor Trip N.A.

2. Power Range, Neutron Flux

f 0.5 second*

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

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

5. Intermediate Range, Neutron Flux N.A.

6. Source Range, Neutron Flux f 0.5 second*

7. Overtemperature N-16 f 7 seconds *f

8. Overpower N-16 f 7 seconds *#

9. Pressurizer Pressure-Low f 2 seconds

10. Pressurizer Pressure-High 1 2 secends

11. Prescurizer Water Level-High N.A.

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Neutron / gamma detectors are exempt from responsa time testing. Response time of the neutron / gamma flux signal portion of the channel shall be measured from detector oucput or input of first electronic component in a channel.

/ Response time includes the thermal well response time.

1.1-3 Rev. 0

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s ATTACHMENT 1 DRAFT Technicel Requirement 1.1 (continued)

Table 1.1.1 REACTOR TRIP SYSTEM INSTRUMFNTATION RESPONSE TIMES FUNCTIONAL UNIT RESPONSE TIME

12. Reactor Coolant Flow-Low

a. Single Loop (Above P-8) < [1] second

b. Two Loopo (Above P-7 and below P-8) ][ [1] second

13. Steam Generator Water tevel--Low-Low < [2] seconds

14. Undervoltage - Reactor Coolant Pumps j[ [1.5] seconds l

15. Underfrequency - Reactor Coolant Pumps j; [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 N.A.

BASES 1.1 REACTOR TRIP SYSTEM RESPON5T YlMES T*_s bases for the Reactor Trip System are contained in the CPSES Technical Specifications. The measurement of response time at the specified 4

frequencies provides assurance that the Reactor trip actuation associated I

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

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4 ATTACHMENT 1 DRAFT- i TEChdICAL REQUIREMENT 1.2 ESF /MTUATION SYSTEM RESPONSE TIME NOTE: This Technical Requirement contains the ESF Actuation System Response Time Table. Although the CPSES Technical Specification is repeated here, in part, care must be taken not to overlook ,

Technical Specification requirczents. ,

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1.2-1 Rev. 0

s ATTACHMENT 1 DRAFT INSTRUMENTATION 3/4.3.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTDi INSTRUMENTATION LIMITING CONDITION FOR OPERATION 3.3.2 The Engineered Safety Features Actuation System (ESFAS) instrumentation channels and interlocks shown in Table 3.3-2 shall be OYERABLE with their Trip Setpoints set consistent with the values shown in the Trip Setpoint column of Table 3.3-3 and with ESF RESPONSE TIMES within their limit value.

APPLICABILITY: As shown in Table 3.1-2.

ACTION:

a. With an ESPAS Instrumentation or Interlock Trip Setpoint trip less conservative than the value shown in the Trip Satpoint column but more consersative than the value shown in the Allowable Value column of Table 3.3-3, adjust the Setpoint y a consistent with the Trip Setpoint value. O

b. With an ESFAS Instrumentation or Interlock Trip Setpoint less amp conservative than the value shown in the Allowable Value columns

of Table 3.3-3, either:

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1. Adjust- the Setpoint consistent with the Trip Setpoint O 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 g Equation 2.2-1 was satisfied for the affected channel, or m

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 g adjusted consistent with the Trip Setpoint value.

g Equation 2.2-1 Z+R+S < TA

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Z = The value from Column Z of Table 3.3-3 for the affected b channel, @

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R = 'Be "as found" value (in percent span) of rack error for the ***

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

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

1.2-2 Rev. O

ATTACHMENT 1 DRAFT INSTRUMENTATION SURVEILLANCE REOUIREMENTS 4.3.2.1 Each ESFAi instrumentation channel and interlock and the automatic actuation logic and relays shali Le demonstrated OPERABLE by performance of the E.1FAS Instrumentation Surveillance Requirements specified in Table 4.3-2.

4.3.2.2 The ENGINEERED SAFETY FEATURES RESFONSE TIME of each ESFAS function shall be demonstrated to be within the limit at least once per 18 monthu. 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 chanr.els are tested at least once per N times 18 months where N is the total number of redundant n annels in a specific ESFAS function as shown in the "Total No. of Channels" column of Table 3.3-2. y G

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4 ATTACHMENT 1 DRAFT Technical Requirement 1.2 TABLE 1,2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS ,

1. Manual Initiation

a. Safety Injection (ECCS) , . N.A.

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b. Containment Spray (Phase "L" [

Isolation and Containment Vent Isolation) N.A. i

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

d. Steam Line Isolation N.A. ,

e. Feedvater Isolation (SI) N.A. L i

f. Auxiliary Feedvater (SI) N.A. !

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

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

i. Control Room Emergency I

Recir- 21stion (SI) N.A.

j. Reactor Trip N.A.

, k. Emergency Diesel Generator

, Operation N.A.

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

m. Turbine Trip N.A. ,

1 2. Containment Pressure--High-1 l

a. Safety Injection (ECCS) I27(1.5a)/12(4,5b) ,

b. Reactor Trip f2

c. Feedvater Isolation f 6.5 l J. Phase "A" Isalation i 17( }/27( ;

! e. Containment Ventilation Isolation N.A. [

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ATTACHMENT 1 LRAFT Technical Requirement 1.2 (continued)

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

f. Auxiliary Teodwater f 60

g. Station Service Water N.A.

h. Component Cooling Water N.A.

1. Essential Ventilation Systems N.A.

, J. Emergency Diesel Generator i

Operation f 12

k. Turbine Trip N.A.

1. Control Room Emergency Recirculat'.on N.A.

m. Containment Spray Pump (7) f 17/27

3. Pressurizer Pressure--Lov

a. Safety Injection (ECCS) f27(1,5a)/12(4.5b)

b. Reactor Trip f2 l c. Feediater Isolation f7

d. Phase "A" Isolation I 17( )/27( }

e. Containment Ventilation Isolation f5(0)

f. Auxiliary Feedwater ( 60

g. Station Service Water N.A.

h. Component Cooling Water N.A. ;

i. Essential Ventilation Systems N.A.

J. Emergency Diesel Cenorator Operation 1 12

k. Turbine Trip M.A.

1. Control Room Emergeucy Recirculation N.A.

m. Containment Spray Pump (7) f17/27 1.2-5 Rev. 0

ATTACHMENT A DRAFT Technical Reauire . , ._ ,'; (continued)

TABL.

ENGINEERED SAFETY FEATsRES RESPONSE TIMES INITIATION SIGNAL AND FUNCTION RESPONSE TIME IN SECONDS 4 Steam Line Pressure--Lov

a. Safety Injection (ETCS) ' }

1 22( .5b)/12

k. Reactor Trip i3

c. Feedwater Isolation 16.5

d. Phase "A" Isolation i 17I }/27(I)

e. Containment Ventilation Isolation N.A.

f. Auxiliary Feedwater 1 60 t

g. Station Service Water N.A.

h. Component Cooling Water N.A.

i. Essential Ventilation Systems N.A.

J. Emergency Diesel Generator Operation i12

k. Turbine Trip N.A.

1. Control Room Emergency Recirculation N.A.

a. Containment Spray Pu p (7) i17/27 s

n. Steam Line Isolation 6.5 -

5. Containment Pressure--High-3

a. Containment Spray Puup- 17(

b. Phase "B" Isolatlon N.A.

6. Containment Pressur6 -High-2 Steam Line Isolation 16.5

7. Steam L!ne Pressure - Negative Rate-High Steam Line Isolation 17 1.2-6 Rev. O

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ATTACHMEET 1 DRAFT Technical Requirement 1.2 (continued)

TABLE 1.2.1 ENGINEERED SAFETY FEATURES RESPONSE TIMES !

INITIATION SIGNAL AND FUNCTION RESFDNSE TIME IN SECONDS

3. Steam Generator Water Level - High-High

c. Turbine Trip N.A.

b. Feedwater Isolation f 11

9. Steam Generator Water Lavel - Low-Low L Motor-Driven Auxiliary ~

Taedwater Pumps 1 60

b. Turbint-Driven Auxiliary f Feedwater Pump f 60

10. Loss,-of-Offsite Power Auxilia y Feedvater N.A.

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

1 RWST Level - Low-Low Coincident with Safety Icjection AutosAtic Initiation of ECCS ~

< 30 Switchover to Containment Sump

$ . 3. Loss of Power (6.9 KV Safeguards System Undervoltage)

a. Of fsite Source Undervoltage f[later)

b. Bus Undervoltage f[later]

1,2-7 hev. 0 b s' .a A -

s ATTACINENT 1 DRAFT Technical Requirement 1.2 (cortinued)

TABLE 1.2.1 TABLE NOTATIONS (1) Diesel generator starting snd sequence loading delays included.

(2) Diesel generator starting delay noj:, included. Offsite power available.

(3) Diesel generator sesrting delay included. RHR pumps not included.

(4) Diesel generator starting and sequence loading delays not included. RHR pumps not included.

(5) Response Time Limit includes opening of injection path valves. Following additional time is allowed for completion of the transfer of the pump suction from the VCT to the RWST a) 10 secs b) 15 secs (6) Includes containment pressure relief line isolation only.

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

BASES 1.2 ENGINEERED SAFETY FEATURES ACTUATION SYSTEM RESPONSE TIMES The bases for ths Engineered Safety Features Actuation System are contained in the CPSES Tecnnical Specifications. The measurement of response time at the specified frequencies provides assurance that the Engineered Safety Features actuation associated with each channel is completed within the time limit assumed in the safety analyses. No credit was taken in the analyses for those channels with response t ^ ts indicated as not applicable. Response time may be demonstrated by any serios of sequential, overlapping, or total channel test measurements provided that such tests demonstrate the total a.hannel response time as defined. Sensor response time varification may be demonstrated by either (1) in place, onsite, or offsite test meacurements, or (2) utilizing replacement sensors with certified response time.

1.2-8 Rev. 0

ATTACHMENT I DRAFT TECHNICAL REQUIRENENT 1.3 MOVABLE IyCORE DETECTORS OPERABILITY CRITERIA 1.3 The Movable Incore Detection System shall be OPERABLE with:

4. 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.

APPLICABILITY: When the Movable Incore Detection System is used fort

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

b. Monitoring the QUADRANT POWER TILT RATIO, or

c. Measurement of H F q(Z) and F,y, COMPENSATORY MEASURES:

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

TEST / INSPECTIONS rego:r ed, 1.3 TheMovableIncoreDetectionSystemshallbe[demonstratedOPERABLE within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months prior to use by irradiating each detector and determining the acceptability of its voltage curve when4rsquired fort we s yte.n is

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

b. Monitoring the QUADRANT POWER TILT RATIO, or

c. Keasurement of F H. Fq(Z) and F BASES __

l.3 MOVABLE INCORE IsETECTO'RI~

The OPERABILITY of the movable incore detectors with the specified minimum complement of equipment ensure's that the measurement.s obtained f rom use of this aystem accurately represent the spatial neutron flux distribution of the core. The OPERABI'ITY of this system is demonstrated by irradiating each detector used and deteraining the acceptability of its voltage curve.

For the purpose of measuring F Quarter-core flux taaps, asedinWCb-8648, def9n(Z) or JuneFf a1976, full incore may be flux used map in is use recalibration of the Excore Neutron Flux Detection System, and full incore flux maps or sywmetric incore thimbles may be used for monitoring the QUADRANT POWER TILT RATIO when c..e Power Range channel is inoperable.

1.3-1 Rev. O t ~

M ACHMENT 1 DRAFT TECHNICAL REQUIREMENT 1.4 SEISMIC INSTRUMENTATION i

OPERA 3ILITY CRITZRIA i

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

APPLICABILITY: At ell times.

n.

COMPENSATORY MEASbRES:

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

tests / INSPECTIONS 1.4.1 Each of the above eequired seismic monitoring instruments shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK.

CHANNEL CALIBRATION, and ANALOG CHANNEL OPERATIONAL TEST at the frequencies sl.own in Table 1.4.2.

1.4.2 Each of the above required seismic monitoring inr,trvaents which is accessible during power operations and which is actuated during a seismic event greater than or equal to 0.013 shall be rest; red to OPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months and a CHANNEL CALIBRATION performed within 15 days following the seismic event.

Data shall be retrieved from actuated instruments and analyzed to determine the magnitude of the vibratory ground motion. A Special Report shell be prepared end submitted to the Commission pursuant to CPSES Technical Specification 6.9.2 within 14 days describing tha magnitade, frequency spectrum, and resultant effait upon facility features important to safety.

1.4.3 Each of the above seismic monitoring instruments which is actuated during a seismic event greater than or equal to 0.0lg but is not accessible during power operation shall be restored to OPERA?'.E status and a CRANNEL CALIBRATION performed the next time the plant enters MODE 5 or below. A supplemental report shall then be prepared and submitted to the Commission within 14 days pursuant to CPSES Technical Specification 6.9.2 describing the additional data from these instruments.

1.4-1 Rev. O

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ATTACHMEFT 1 DRAFT TECHNICAL REQUIRENDIT 1.4 TABLE 1.4.1 SEISMIC MONITORING INSTRUMENTATION MINIMUM !

INSTRUMENTS l

INSTRUMENTS AND SENSOR LOCATIONS OPERABLE I

1. Triaxial Time-History Accelerographs

a. Accelerometer-Fuel Building 1 ,

b. Accelerometer-Containment 1

c. Accelerometer-Electrical Manhole 1 .

d. Seismic Trigger-Fuel Building 1 i

e. Recorder Unit. SMA-3 1

f. Playback Unit, SMP 1 1

2. Triaxial Peak Accelerographs

a. Pressurizer Lifting Tr*2nion 1

b. Reactor Coolant Piping 1 i c. CCW Heat Exchanger 1

.1 Triaxial Seismic Switch 1

Fuel Building 1*

4. Triaxial Response-Spectrum Recorders

! a. Fuel Building I

b. neactor Blds. Internal Structure 1

c. Safeguards Building 1 1

5. Response Spectrum Annunciator 18

^With control room indication.

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ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 1.4 TABLE 1.4.2 SEISMIC MONITORING INSTRUMENTATION SURVEILLANCE REQUIREMENTS ANALOG

F CHANNEL CHANNEL CHANNEL OPERATIONAL INSTRUMENTS AND SENSOR LOCATIONS __ CHECK , CALIBRATION TEST

1. Triaxial Time-History Accelerographs

a. Accelerometer-Fuel Building M R SA

b. Accelerometer-Containment M R SA 1 c. Accelerometer-Electrical Manhole M R SA

d. Seismic Trigger-Fuel Building M R SA

e. Recorder Unit, SHA-3 M R SA

f. Playback Unit, SMP-1 M R SA

2. Triaxial Peak Accelerographs

a. Pressurire? Lif ting Trunion N.A. R N.A.

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

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

3. Triaxial Scismic Switch Fuel Building ** M R SA j 4. Triaxial Respense-Spectrum Recorders 4

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

b. Resetnr Bldg. Internal Structure N.A. R N.A.

c. Safeguards Building N.A. R N.A.

$. Respc.ise Spectrum Ann'inciator** M R SA t .-

S:',.oint verification is not applicable.

- With control room indication.

1.4-3 Rev. O s

4 ATTACHMENT 1 DRAFT ,

4 BASES 5 1.4 SEISMIC INSTRUMENTATION !

! l The OPERABILITY of the seismic instrumentation ensures that sufficient i espsbility is available to promptly determine t*se magnitude of a seismic event and evaluate the respons1 of those features important to safety.

This capability is required to petrit comparison of the acasured response to that used in the design basis for the facility to detet_ine if plant shutdown is required pursuant to Appendix A of 10CFR100. The instrumentation is consistent with the recommendations of Regulatory Guide L 1.12. "Instrumentation for Earthquakas." April 1974. !

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ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 1.5 METEOROLOGICAL INSTRUMENTATION OPERABILITY CRITERIA 1.5 The meteorological monitoring instrumentation channels shown in Table 1.5.1 shall be OPERABLE.

APPLICABILITY At all times.

COMPENSATORY ME.iSURES:

a. k'ith one or more required meteorological monitoring channels fraperable for more than 7 days, prepare and submit a Special

'leport 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.

TESTS / INSPECTIONS 1.5 Each of the above meteorological monitoring instrumentation char.nels shall be demonstrated OPERABLE:

a. At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by performance of a CHANNEL CHECK, and

b. At least once per 184 days by performance of a CHANNEL CALIBRATION.

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1.5-1 Rev. O

ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 1.",

TABLE 1.5.1 METEOROLOGICAL MONITORING INSTRUMENTATION MINIMUM INSTRUMENT LOCATION OPERABLE

1. WIND SPEED 1 of 3

a. X-SY-4117 Nominal Elev. 60 m.

b. X-SY-4118 Nomina Elev. 0 m.

c. X-SY-4128* Nominal Elev. 10 m.

2. WIND DIRECTION 1 of 3

a. X-ZY-4115 Nominal Elev. 60 m.

b. X-ZY-4116 Nominal Elev. 10 e.

c. X-ZY-4126* Nominal Elev. 10 m.

3. AIR TEMPERATURE - a T 1 of 2

a. X-TY-4119 Nominal Elev. 60 m. and Nominal Elev. 10 m.

b. X-TY-4120 Nominal Elev. 60 m. and Nominal Elev. 10 m.

Mounted on backup tower.

BASES 1.5 METEOROLOGICAL INSTRUMENTATION The OPERABILITY of the meteorological instrumentation enJures that sufficient meteorological data are available for estimating potential radiation doses to che public as a result of routine or accidental release of radioactive materi'Is to the atmosphere. This capability is required to evaluate the need for initiating protective measures to protect the health and safety of thc public and is consittent with the recommendations of Regulatory Guide 1.23. "Onsite Meteorological Programs," September 1980.

1.5-2 Rev. 0

O ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 1.6 LOOSE-PART DETECTION SYSTEM OPERABIL?TY CRITERIA 1.6 The Loose-Part Detection System shall be OPERABLE.

APPLICABILITY,3 MODES 1 and 2.

COMPENSATORY MEASUR3 :

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

TESTS /INSPECl IONS 1.6 Each channel of the f.oose-Part Detection Systems shall be demonstrated OPERABLE by performance of t

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

b. An ANALOG CRANNEL OPERATIONAL TEST

at least once per 31 days, and

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

Setpoint verification is not applicable.

BASEC 1.6 LOOSE PARTS DETECTION SYSTEM The OPERABILITY of the Loose-Part Detection System ensures that sufficient capability is available to detect loose metal..c parts in the Reactor System and avoid or mitigate damage. to Reactor System components. The allavable 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.

1.6-1 Rev. O

ATTACHMENT 1 DRAFT

, REACTOR COOLANT SYSTEM LPERATIONAL LEAXAGE LIMITING CONDITION FOR OPERATION 3.4.6.2 Raactor Coolant System leakage shall be limited to:

a. No PRESSURE BOUNDARY LEAYJ.GE,

b. 1 OPM UNIDINTIFIED LEAKAGE,

c. 1 GPM total reactor-to-secondary leakage through all steam h generators not isolated from the Reactor Coolant System and 500 gallons per day through aay one steam generator not isolated from y the Reactor Coolant System, @

d. 10 GPM IDENTIFIED LEAKAGE from the Reactor Coolant System, ,

>=

e. 40 GPM CONTROLLED LEAKAGE at a Reactor Coolant System pressure of 2235 2 20 psig, and g'

f. 0.5 GPM leakage per nominal inch of valve size up to a maximum of 5 GPM at a Reactor Coolant Syrtem pressure of 2235 2 20* psig 7

from any Reactor Coolant System Pressure Isolation Valve. g APPLICABILITY: MODES 1, 2, 3, and 4.

ACTION:

h

a. With any PRESSURE BGUNDARY LEAKAGE, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and 1n COLD SHUTDOWN within the following 30 y

hours. D

b. With any Reactor Coolant System leakage greater than any one of O

the above limits, excluding PRESSURE BOUNDARY LEAKAGE and Icakage Q ym.

from Reactor Coolant System Pressure Isolation Valves, reduce the q 1eakage rate to within limits within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in a" least ***

HOT STANDBY vithin the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTD^

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

vithin O g

M' ame Test pressures less than 2235 psig but greater than 150 psig are C allowed for valves where the higher pressure vould tend to diminish g the leakage chant.el opening. Observed leakage shall be adjusted for actual pressure to 2235 psig assuming the leakage to be directly proportional to pressure dif ferential to the one-half power.

2.1-1 Rev. O

?

e ATTACHMENT 1 DRAFT M TOR COOLANT SYSTEM LIMITING CONDITION FOR OPERATION (Continued) ,

ACTION (Continued)

c. With any Reactor Coolant System Pressure Isolation Valve leakage greater than the above limit, isolate the high pressure portion of the affected system from the low pressure portion within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months by use of at least two closed manual or deactivated automatic valves, or be in at least HOT STANDBY vithin 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 . %

SURVEILLANCE REQUIREMENTS 4.4.6.2.1 Reactor Coolant System leakages shall be demonstrated to be W

within each of the above limits by: ,

a. Monitoring the Reactor Coolant System Leakage Detection System required by Specification 3.4.6.1 at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; g'

g

b. Naasurement of the CONTROLLED LEAKAGE to the reactor coolant pump seals when the Reactor Coolant System pressure is 2235 t 20 psig E

at least once per 18 months or following any modification. g maintenance or operation that ef fects the seal path injection g flow and at least once per 31 days by verifying that valves 8369 A, B, C and D aire locked in their thro'stle position. The h provisions of Spet fication 4.0.4 are not applicable for entry into MODE 3 or 4;

c. Performance of a Reactor Coolant System water inventory balance within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months afta- echieving steady state operation

and at least once per 72 . tire thereafter during steady state operation, D

except that no more .aan 96 hours0.00111 days 0.0267 hours 1.587302e-4 weeks 3.6528e-5 months shall elapse between any two successive invintrry balances. The provisions of Specification Q 4.0.4 are not applicable for entry into MODE 3 or 4; and q mee

d. Monitoring the Reactor Head F.*ange Leakoff System at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , O g

M' une

T,yg being changed by less than 5'F/ hour. C g

t 2.1-2 Rev. O

e ATTACHMENT 1 DRAFT REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS (Continued) 4.4.5.2.2 Each Reactor Ceolant System Pressure Isolation Valve shall be demonstrated OPERABLE by verifying leakage to be within its limits

a. At least once per 18 months,

b. Prior to entering MODE 2'.vhenever the plant has been in COLD b

SHUTDOWN for 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or more and if leakage testing has not been performed in the previous 9 months, enept for valves 8701A, @

8701B, 8702A, and 8702B.

c. Prior to returning the valve to service following maintenance, repair or replacement work on the valve, and @

d. Following check valve actuation due to flow through the valve and

e. As outlined in ASME Code,Section XI, paregraph IWV-3427(b). O The provisions of Specification 4.0.4 are not applicable for entry into @*

HODE 3 or 4.

g a.

O W

sum.

'O O

.O.

M m..

O l

s W

l

.P.9 i

O l D l

l l

l 2.1-3 Rev. O I

o ATTACHMENT I DRf,T <

Technical Requirement 2.1 TABLE 2.1-1 REACTOR COOLANT SYSTEM PRESSURE ISOLATION VALVE 3 VALVE NUMBER FUNCTION ,

8948 A, B, C D Accumulator Tank Discharge f 8956 A, B C, D Accumulator Tank Discharge i 8905 A B, C, D SI Hot Leg Injectton '

894.1 A, B, C, D SI Hot Leg Injection 8818 A, B, C D RHR Cold Leg Injection ;

8819 A, B, C D SI Ce1d L eg Injection J701 A, B RHR Suction Isolation 8702 A, B RHR Suction Isolation 8841 A, B RER Hot Leg Injection 8815 CCP Cold Leg Injection !

t 8900 A B C. D sCP Cold Leg Injection l r

1 1

1 2.1-4 Rev. 0 l

ATTACHMENT I DRAFT TECHNICAL REQUIRTRENT 3. ' CONTAINMENT ISOLATION VALVES NOTE: This Technical Requirement contains the listing of Containment Isolation V$ives, and their respective testing requirements, which are subject to CPSES Techt.ical Specification 3.6.3.

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

l i

l 3.1-1 Rev. 0

ATTACHMENT 1 DRAFT CONTAINMENT SYSTEMS 3/4.6.3 CONTAINMENT ISOLATION VALVES LIMITING CONDITION FOR OPERATION 3.6.3d ne containment isolation valves shall be OFERABLE.

APPLICABILITY MODES 1, 2, 3, and 4.

ACTION:

With one or more of the containment isolation valve (s) inoperable, maintain at least one isolation valve OPERABLE in each affected penetration y 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 e ch 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 ceactivated automatic valve secured in the isolation position, or O

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.

m Be in at least HOT STANDBY vithin the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD O SHUTDOWN v1. thin the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

g sum

_ SURVEILLANCE REQUIR,EMENTS 4.6.3.1 The containment isolation valves shall be demonstrated operable prior to returning the valve to service after maintenance, repair or replacement work is performed on the valve or its associated actuator, D

control or power c.ircuit by performance of a cycling test, and verification O of isolation time. g 9

a..

Ythe requirements of Specification 3.6.3 do not apply for those valves O cevered by Specifications 3.7.1.1, 3.7.1.5 and 3.7.1.6.

g

CAUTION: The inoperable isolation valve (s) may be part of a systes(s), ame Isolating the affected penetration (s) may effect the use of the system (s).

Consider the Technical Specif $ cation' requirements oc the affected system (s) Q sq and act accordingly. w 3.1-2 Rev. 0 i

ATTACHMENT 1 DRAFT CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) 4.6.3.2 Each containment isolation valve shall be demonstrated OPERABLE at least once pet 18 months by:

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

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

c. Verify that on a Containment Ventilation Isolation test signal, each ventilation valve actuates to its isolation position. %

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

O O

llr D.

O W

umn 2

0 0 .

==.

O N

.P.9 O

D 3.1-3 Rev. O

J:

l.

ATTAC* DENT 1 . DRAFT TECHNICAL REQUIRl! MENT 3.1 TABLE 3.1.1 C0NTAINMENT ISOLATION VALVES MAXIMLP*

ISOLATION - TYPF.

FSAR TABLE TIME LEAK TEST ;

VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS

1. Phase "A" Iso 16 lon Valves '. .'

1HV-2154 20 Feedwater Sample 5 Note 1 (FW to Sta con #1) 1HV-2155 22 Feedwater Sample 5 Nota 1 ,

-(FW to Sta Cen #2) r 1HV-2399 27 Blowdown From Steam 5 Note 1 Cenerator #3 1HV-2398 28 Blowdown From Steam 5 Note 1 Generator #2 INV-2397 29 Blowdown From Steam 5 Note 1 ;

Cenerator #1 l

, i

) 1HV-2400 30 Blowdown From Steam 5 Note 1 i

Generstor #4 ,

1

( 1-8152 32 Letdown Line to 10 C !

Letdown Heat Exchanger I 1-8160 32 Letdown Line to 10 C

Letdown Heat Exchanger ;

W 1-8890A 35 RHR to Cold Leg Loops 15 Note 2

1 & #2 Test Line [

t 1-88908 36 RHR to Cold Leg Loops 15 Note 2 :

f3 & #4 Test Line '

i 1-8047 41 Reactor Makeup Yater 10 C to Pressure Relief r Tank & RC Pump Stand :

Pipe

[

1-8843 42 SI to RC System Cold 10 Note 2 ;

Leg Loops fl. #2. f3. f4 ,

Test Line j i

t k

3.1-4 Rev. 0 i

I ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 3.1 <

TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION TYPE (

FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.

LINE OR SERVICE (Seconds) REQUIREMENTS

1. Phase "A" Isolation Valves 1-8881 43 SI to RC System Hot Leg 10 Note 2 Loops #2 & #3 Test Line 1-8824 44 SI to RC System Hot Leg 10 Note 2 3 Loops #1 & #4 Test Line 1-8823 45 SI to RC System Cold Leg 10 Note 2 Loops #1, f2. f3 & #4 Test Line 1-8100 51 Seal Water Return 10 C and Excess Letdown 1-8112 51 Seal Water Return 10 C and Excecs Letdown

1-7136 52 RCDT Heat Exchanger 10 C

to Waste Hold Up Tank LCV-1003 52 RCDT !! eat Exchanger 10 C to Waste Hold Up Tank 1HV-5365 60 Demineralized Water Supply 5 C 1HV-5366 60 Demineralized Water Supply 5 C 1HV-5157 61 Containment Sump Pump 5 C Discharge 1HV-5158 61 Containment Stimp Pump 5 C Discharge 1HV-3487 62 Instrument Air to 5 C Containment 1-8825 63 RHR to Hot Leg Loops 15 Note 2 f2 & f3 Test Line 1HV-2405 73 Sample from Steam 5 Note 1 Cenerator #1 1HV-4170 74 RC Sample From Hot Legs 5 C 3.1-5 Rev. O

c. __ _

0 c.

ATTAC10ENT 1 DRAFT TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAXIMLH ISOLATIDW TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCit NO.* LINE OR SERVICE (Seconds) REQUIREMENTS

1. Phase "A" Isolation Valves (Continued) 1HV-4168 74 RC Sample From Ho.t Les #1 5 C IHV-4169 74 RC Sample From Hot Les f4 5 C INV-2406 76 Sample from Steam 5 Note 1 Generator #2 1HV-4167 77 Pressuriser Liquid 5 C Space Sample i

1HV-4166 77 Pressuriser Liqvid 5 C Space Sample 1HV-4176 78 Pressuriser Steam 5 C Space Sample JHV-4165 78 Pressuriser Steam 5 C Space Sample I

1HV-2407 ,9 Sample Trom Steam 5 Note 1 Cenerator #3 i

i 1HV-4175 80 Accumulators 5 C 1HV-4171 80 Sample From 5 C Accumulator il 1HV-4172 80 Sample From 5 C Accumulator #2

) 1HV-4173 30 Sample From 5 C l Accumulator #3 JHV-4174 80 Sample From 5 C Accumulator #4 j 1HV-7311 81 RC PASS Sample 5 C Discharge to RCDT l IHV-7312 81 RC PASS Sample 5 C l Discharge to RCDT f 1HV-2408 82 Sample from Steam 5 Note 1 i Cenerator f4 i

I 3.1-6 Rev. O

'/'

ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE No.* LINE OR SERVICE (Seconds) REQUIREMENTS

1. Phase "A" Isolation Valves (Continued)

1-8871 83 Accumulator Test and Fill 10 C 1-8888 83 Accumulator Test and Fill 10 C 1-8964 83 Accumulator Test and Fill 10 C 1HV-5556 84 Containment Air PASS 5 C

. Return 1

1HV-5557 84 Containment Air PASS 5 C Return 1HV-5544 94 Radiation Monitoring 5 C Sample 1HV-5545 94 Radiation Monitoring 5 C Sample 1HV-5558 97 Containment Air PASS Inlet 5 C 1HV-5559 97 Containment Air PASS Inlet 5 C 1HV-5560 100 Containment Air PASS Inlet 5 C 1HV-5561 100 Containment Air PASS Inlet 5 C 1HV-5546 102 Radiation Monitoring 5 C Sample Return e

1HV-5547 102 Radiation Monitoring 5 C Sample Return 1-8880 104 Na Supply to Accumulators 10 C 1-7126 105 H Supply to RC Drain 10 C Tank 3.1-7 Rev. O

C f

ATTACHMENT 1 DRAFT '

TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued) !

CONTAINMENT ISOLATION VALVES MAXIMUM i ISOLATION TYPE FSAR TABLE TIME LEAK TF.ST i VALVE NO. RFFERENCE NO.

LINE OR SERVICE (Seconds) REQUIREMENTS i

1. Phase "A" Isolation Valves (Continued)

(

1-7150 105 H Supply to RC Drain 10 C I Tank l 1HV-4710 111 CC Supply to Excess 5 Nota 1 l Letdown & RC Drain '

Tank Heat Exchanger !

1HV-4711 112 CC Return From Excess 5 Note 1 [

Letdown & RC Drain ;

Tank Heat Exchanger i 1HV-3486 113 SLrvice Air to 5 C Containment 1HV-4725 114 Containment CCY Drain 5 C j- Tank Pumps Discharge L i 1HV-4726 114 Containmeat CCW Drain 5 C !

Tank Fumps Discharge !

l-8027 116 Nitrogen Supply to PRT 10 C 1-8026 116 Nitrogen Supply to PRT 10 C INV-6084 120 Chilled Water Supply 10 C !

to Containment Coolers i

{

1HV-6082 121 Chilled Water Return 10 C !

From Containment Coclers (

i -

1HV-6083 121 Chilled Water Return 10 C I From Containment Coolers !

l'

) 1HV-4075B 124 Fire Protection dy.66c 10 C

Isolation i t

. 1HV-4075C 124 Fire Protection System 10 C L

Imolation r

l I

t 3.1-8 Rev. O i i

.O .

s

. l ATTACHMENT 1 ,

DRAFT i TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES 4

MAXIMUM ISOLATION TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Secondel REQUIREMENTS

2. Phase "B" Isolation Valves -

lHV-4708 117 CC Return From RCP's 10 C Motors INV-4701 117 CC Return From RCP's 10 C Motars INV-4700 118 CC Supply to RCP's 10 C Motors iKV-4709 119 CC Return From RCP's 10 C Thermal Barrier 1HV-4696 119 CC Return From RCP's 10 C Thermal Barrier

3. Containment Ventilation Isolation Valves I

1HV-5542 58 Hydrogen Purge Supply NA C 1HV-5543 38 Hydrogen Purge Supply NA C INV-5563 58 Hydrogen Purge Supply NA C 1HV-5540 59 Nydrogen Purge Exhaust NA C

1NV-5541 59 Hydrogen Purge Exhaust NA C i 1HV-5562 59 Hydrogen Purge Exhaust NA C i lHV-5536 109 Co tainment Purge Air NA C Supply 1HV-5537 109 Containment Purge Air NA C Supply IHV-3538 110 Containment Purge Air NA C Exhaust IHV-5539 110 Containment Purge Air NA C Exhau1t 3.1-9 Rev. O

ATTACHMENT 1 DRAFT TTCHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAXIMUM ISOLATION TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* 1.INE OR SERVICE (Seconde) REQUIREHENTS

3. Containment Ventilation Isolation Valvis (Continued) 1HV-5548 122 containment Pressure 3 C Relief 1NV-5549 122 Containment Pressure 3 C Relief

4. Manual Valves 1MS-711 4a TDAFW Pump Warm-up Valve N.A. Note 1. 11 IMS-390 5a Na Supply to Steam N.A. Note 1 Generator il 1MS-387 9a Na Supply to Steam N.A. Note 1 Generator #2 1MS-384 13a Na Supply to Steam N.A. Note 1 Generator #3 1MS-712 17a TDAfW Pump Warm-up Valve N.A. Note 1. 11 1MS-393 18a Na Supply to Steam N.A. Note 1 Generator f4 1TW-106 20b Na Tupply to Steam N.A. Note 1 Centrator #1 1FW-104 22b Na Supply to Steam N.A. Note 1 Generator #2 1rW-110 24 Secondary Saepling N.A. Note 1 1TW-102 24b Na Supply to Steta N.A. Note 1 Generator #3 IFW-119 26 Secondary Sampling N.A. Note 1 IFW-108 26b Na Supply to Steam N.A. Note 1 Cenerator #4 1-7135 52 RCDT Heat Exchanger to N.A. C Waste Holdup Tank 3.1-10 Rev. 0

3 !4 ATTACHMENT 1' DRAFT

TECHNICAL REQUIREMENT 3.1-TABLE 3.1.1 (Contint.ed) [

l CONTAINMENT ISOLATION VALVES, MAXIMUM L ISOLATION TYP.. !

FSAR TABLE TIME LEAK TEST !

,V,,ALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS f a i

4. Manual Valves (Cont.inued) [

, ISFe011 56 Refueling Water N.A. C I Purification to I Refueling Cavity ISF-012 56 Refueling Water N.A. C l Purification to

, Refueling Caving l l

ISF-021 67 Refueling Cavi,; to N.A. C Refueling Water "

Purification Pump j ISF-022 67 Refueling Cavity to N.A. C l Refueling Water i Purification Pump ,

ISF-053 71 Refueling Cavity N.A. C l Skimmer Pump Discharge i

. ISF-054 71 Refueling Cavit;- N.A. C t Skimmer Pump Dist.fiarse ;

j. lHV-2333B 2 MSIV Bypass from Ste m N.A. Note 1. 6 !

t Generator il ;

i lHV-2334B 7 MSIV Bypass from Steam N.A. Note 1, 6 i Generator #2 1HV-2335B 11 MSIV Bypass from Stea.m N.A. Note 1. 6

, Generator #3 1HV-2336B 15 MSIV Bypass from Steam N.A. Note, 1, 6 t Generator f4

5. Power-Operated Isolation Vaav.s 1HV-2452-1 4 Main Steam to Aux. FPt N.A. Note 1 !

From Steam Line il !

t l IPV-2325 5 Atmospheric Relief N.A. Note 1 !

i Steam Generator il f s

l t i 3.1-11 Rev. 0 l\

ATTACHMENT 1 DRAFT TECHNICAL REQUIR2 MENT 3.1 TABLE 3.1.1 (Continued)

CONTAINNENT ISOLATION VALVES MAXIMUM i ISOLATION TYPE !

FSAR TABLE TIME LEAK TEST ;

VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS

5. Power-Ope. rated Isolation Valves (Continued) i i

IPV-2326 9 Atmospheric K lief N.A. Note 1 h Steam Generator #2 ;

i 1PV-2327 13 Atmospheric Relief N.A. Note 1 !

Steam Generator #3 ;

1HV-2452-2 17 Main Steam to Aux. FPT N.A. Note 1 From Steam Line #4 [

IPV-2328 18 Atmospheric Relief N.A. Note 1 f Steam Ger arator #4 l 1HV-2491A 20a Auxiliary Feedwater to N.A. Note 1 l Steam Generator #1 F 1HY-2491B 20a Auxiliary Feedwater to N.A. Note 1 -

l Steam Generator il

. IhV-2492A '?a Auxiliary Feedvater to N.A. Note 1 Steam Generator #2 3 ,-

1HV-2492B 22s Auxilia:y Feedwater to N.A. Note 1 Steam Generator #2

'l

1HV-2493A 24a Auxiliary Feedwater to N.A. Note 1

Steam Generator #3 l

l 1HV-24938 24a Auxiliary Feedwater to N.A. Note 1 Steam Generator #2 1HV-2494A 26a Auxiliary Feedwater to N.A. Note 1 Steam Generator f4 i

f 1HV-21.'94 E 26a Auxiliary Feedwater to N.A. Note 1 l Steam Generator #4

1-8701B 33 RHR From Hot Leg Loop #4 N.A. Note 5 l 1-8701A 34 RHR From Hot Leg Loop fl N.A. Note 5 i 1-8809A 35 RHR to Cold Leg Loops N.A. Note 4 il and #2 3.1-12 Rev. 0 4

L

I e

ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES i,

MAXIMUM r ISOLATION TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS

5. Power-Operated Isolation Valves (Continued) 1-8809B 36 RHR to Cold Leg Loops N.A. Note 4 :

3 and #4 '

1-8801A 42 High Head Safety Injection N.A. Note 7 i to Cold Les Loops #1, #2,

, #3, and f4 ,

l 1-8801B 42 High Head Safety Injection N.A. Note 7 !'

to Cold Leg Loops #1 !2, ,

3, and #4

' 1 1-8802A 43 SI Injection to Hot Leg N.A. Note 8 j Loops #2 and #3 1-8802B 44 SI Injection to Hot Leg N.A. Note 8 Loops #1 and #4 .

1-8835 45 SI Injection to Cold Leg N.A. Note 4 ft Loops #1, #2, 81, and #4

! l-8351A 47 Seal Injection to RC N.A. C i

Pump (Loop #1) i 1-8351B 48 Seal Injection to RC N.A. C i Pump (Loop #2) '

, 1-8351C 49 Seal Injection to RC N.A. C j Pump (Loop 3) [

l 1-8351D 50 Seal Injection to RC N.A. C !

Pump (Loop #4) j lHV-4777 54 Containment Spray to N.A. Note 3 I Spray Header (Tr. B) [

i IHV-4776 55 Containment Spray to N.A. ..ote 3 [

Spray Header (Tr. A) 1 e840 63 RHR to Hot Leg Loops N.A. Note 8 I

2 and #3 f

3.1-13 Rev. 0 l l

(

e .

?

r ATTACHMENT 1 DRAFT ,

TECHNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued) i C0ATAINMENT ISOLATION VALVES f

MAXIMUM ISOLATION TYPE [

FSAR TABLE TIME LEAK TEST !

VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS

5. Power-Operated Isolation Valves (Continued) 1-8811A 125 Contair:sent Recire. N.A. Note 1, 10 ;

Sump to RHR Pumps !

(Train A) j 1-88118 126 Containment Recire. N.A. Note 1. 10 !

Susp to RER Pumps (Train B) 1HV-4782 127 Containment Recire. N.A. Note 1. 10 to Spray Pumps (Train A)

) 1HV-4783 128 Containment Recire. N.A. Note 1. 10 4 to Spray Pumps y (Train B) l

6. Check Valves i

i 1-8818A 35 RHR to Cold Leg Loop fl N.A. Note 2 1 9818B 35 RHR to Cold Leg Loop f2 N.A. Note 2

1-t818C 36 RHR to Cold Leg Loop f3 N.A. Note 2 1-8818D 36 RER to Cold Leg Loop #4 N.A. Note 2 4

1-8046 41 Reactor Makeup Water to N.A. C j Pressurizer Relief Tank i and RC Pump Stand Pipe l 1-8815 42 High Head Safety Injection N.A. Note 2 i

to Cold Leg Loops #1, f2 j #3, and #4 l 1SI-8905A 44 SI co RC System Hot Les N.A. Note 2 Loop fl ISI-8905B 43 SI to RC System Hot leg N.A. Note 2 Loop #2 ISI-8905C 43 SI to RC System Hot '.eg N.A. Note 2 Loop #3 3.1-14 Rev. O

v e.

ATTACHMENT 1 DRAFT TECHNICAL REQUIRDCNT 3.1 TABLE 3.1.1 (continued)

CONTAINMENT ISOLATION VALVES :

MAXIMUM ISOLATION TYPE FSAR TABLE TIME LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS '

6. Check Valves (Continued) f l

1SI-8905D 44 SI to RC System Hot Leg N.A. !!ote 2 .

Loop #4 !

ISI-8819A 45 SI to RC System Cold N.A. Note 2 E Leg Loop #1 ,

t 1SI-8819B 45 SI to RC System Cold N.A. Nota 2 Les Loop #2 1SI-8819C 45 SI to RC System Cold N.A. Note 2 j Leg Loop #3 l 1SI-8819D 45 SI to RC System Cold N.A. Note 2 7

Leg Loop #4 1-8381 46 Charging Line to N.A. C i Regenerative Heat I l

Exchanger !

ICS-8368A 47 Seal Injection to RC N.A. C

Puer G.oo? f1) [

1CS-8368B 48 t'eal Injection to RC N.A. C.

Pump (Loop #2) !

s 1

1CS-8368C 49 Seal Injection to RC N.A. C '

Pump (Loop #3) 1CS-8368D 50 Seal Injection so RC N.A. C Pump (Loop #4) f L

1C5-8180 51 Seal Water Return and N.A. C L Excess Letdown l t

ICT-145 54 Centainment Spray te N.A. Note 3 !

Spray Header (Tr. B) j

ICT-142 55 Containment spray to N.A. Note 3

) Spray Header (Tr. A) l ICT-030 62 Instrument Air to N.A. C Containment i

1 i

3.1-15 Rev. O I

ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 3.1 TAELE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES MAXIMUM IS( LATION TYPE FFAR TABLE TIME LEAK TEST VALVE NO. REFERENCE N0 i* LINE OR SERVICE (Seconds) REQUIREMENTS 1-8841A 63 RHR to Hot Leg Loop #2 N.A. Note 2 1-8841B 63 RHR to Hot Leg Loop #3 N.A. Note 2 1SI-8968 104 Na Supply to Accumulators N.A. C 1CA-016 113 Service Air to N.A. C Containment ICC-629 117 CC Return From RCP's N.A. C Motors 10C-713 118 CC Supply to RCP's Motors N.A. C 10C-831 119 CC Return From RCP's N.A. C Thermal Barrier ICH-024 120 Chilled Water Supply to N.A. C Containment Coolers

7. Steam Line Isolation Signal 1NV-2333A 1 MSIV #1 5 Note 1.9.12 1HV-2409 3 Drain Frau Main Steam 5 Note 1 Line il 1HV-2334A 6 MSIV #2 5 Note 1.9.12 1HV-2410 8 Drain From Main Steam 5 Note 1 Line #2 1HV-2335A 10 MSIV #3 5 Note 1.9.12 1HV-2411 12 Drain from Main Steam 5 Note 1 Line #3 1HV-2336A 14 MSIV #4 5 Note 1.9.12 1HV-2412 16 Drain From Main Steam 5 Note 1 Line #4 3.1-16 Rev. O

ATTACHMENT 1 DRAFT I J

TECHNICAL REQUIREMENT 3.1 j TABLE 3.1.1 (Continued)

CONTAINMENT ISOLATION VALVES ,

MAXIMUM ;

ISOLATION TYPE !

FSAR TABLE TIME LEAK TEST !

VALVE NO. REFERENCE No.* LINE OR SERVICE (Seconds) REQUIREMENTS

8. Feedwater Lino Isolation Signal A

1HV-2134 19 Feedwater Isolstion 5 Note 1, 12

Steam Generator il i i

1FV-2193 20e Feedwater Preheat Bypass 5 Note 1, 12 Line S.G. #1 1HV-2185 20d Feedvater Isolation 5 Note 1, 12 f q Bypass Line S.C. il 1HV-2135 21 Feedwater Isolation 5 Note 1. 12 !

Steam Generator #2 !

}

ITV-2194 22c Feedwater Preheat Bypass 5 Note 1, 11 2

Line S.C. #2 L 1HV-2186 22d Feedvater Isolation 5 Note 1, 12 i Bypass Line S.C. #2

{

1HV-2136 23 Feedwater Isolation 5 Note 1. 12 !

Steam Generator #3 !

j 1FV-2195 24c Feedvater Preheat Bypass 5 Note 1, 12 >

l Line S.C. f3

! 1HV-2187 24d Feedwater Isolation 5 Note 1, 12 [

! Bypass Line S.C. f3 i i

i 1HV-2137 25 Feedwater Isolation 5 Note 1. 12 !

j Steam Generator #4 j i i i t r'V-2196 26d Feedvater Preheat Bypass 5 Note 1. 12

)

Line S.G. f4 !

r 1HV-2188 26e Feedvater Isolation 5 Note 1. 12 Bypass Line S.C. #4 i 9. Safety Injection Actuation Isolation i i

' I 1-8105 46 Charging Line to 10 C j

] Regenerative Heat t i Exchanger j i

i !

j 3.1-17 Rev. O !

l - _ - . - _ _ -. - - - - - - - -

g --_ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _

,-+ >

I ATTACHMENT 1 DRAFT i TECHNICAL REQUIREMENT 3.1 i

TABLE 3.1.1 (Continued) i CONTAINMENT ISOLATION VALVES MAXIMLH I ISOLATION TYPE !

FSAR TABLE TIME LEAK TEST ,

VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconde) REQUIREMENTS ;

10. Relief Valves !

b I 1-8708B 33 RHR From Hot leg Loop f4 N.A. Note 5 l

l-8708A 34 RHR From Hot Les Loop fl N.A. Note 5 f

1MS-021 5b Main Steam Safety Valve N.A. Note 1, 12

S.G. il 1 1 1MS-022 $b Main Steam Safety Valve N.A. Note 1, 12 !

S.C. il !

IMS-023 Sb Main Steam Safety Valve N.A. Note 1, 12 S.G. fl IMS-024 Sb Main Steam Safety Valve N.A. Note 1. 12 {

S.G. #1 j IMS-025 Sb Main Steam Safety Valve N.A. Note 1, 12 '

! S.C. #1 IMS-058 9b Main Steam Safety Valve N.A. Note 1, 12 ,

S.C. f2 ;

IMS-059 9b Main Steam Safety Valve N.A. Note 1. 12 i S.G. f2 >

i IMS-060 9b Main Steam Safety Valve N.A. Note 1, 12 !

S.C. f2 -

r IMS-061 9h Main Steam Safety Valve N.A. Note 1,12 i S.G. f2 l

, IMS-062 9b Main Steam Safety Valvo N.A. Note 1, 12 S.G. #2 {

IMS-093 13b Main Steam Safety Valva N.A. Note 1, 12 S.C. f3 (

j IMS-094 13b Main Steam Safety Valve N.A. Note 1. 12 f

S.C. f3 i 1MS-095 13b Main Steam Safety Valve N.A. Note 1, 12 [

l S.G. f3 I

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3.1-18 Rev. O !

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ATTACHMENT 1 DRAFT

" i f

TECKNICAL REQUIREMENT 3.1 TABLE 3.1.1 (Continued) !

CONTAINMENT ISOLATION VALVES C

MAXIMUM ISOLATION TYPE FSAR TABLE TIM 2 LEAK TEST VALVE NO. REFERENCE NO.* LINE OR SERVICE (Seconds) REQUIREMENTS L

10. Relief Valves (Continued) h I i

1MS-096 13b Main Steam Safety Valve N.A. Note 1. 12 S.G. f3 i IMS-097 13b Main Steam Safety Valve N.A. Note 1. 12 l S.G. f3 ,

IMS-129 18b Main Steam Safety Valve N.A. Note 1. 12 .

S.G. f4 l r

i 1MS-130 18b Main Steam Safety Valve N.A. Note 1. 12 S.G. #4 l 1MS-131 18b Main Steam Safety Valve N.A. Note 1. 12 ;

S.C. f4 '

1MS-132 18b Main Steam Safety Valve N.A. Note 1. 12 S.G. f4 1MS-133 18b Main Steam Safety Valve N.A. Note 1. 12 S.C. f4 1RC-036 41 RMUV To PRT & RCP N.A. C Standpipe IWP-7176 52 RCDT HX to Waste N.A. C Holdup Tank 1DD-430 60 Dominera11:ed Water Supply N.A. C IVD-907 61 Containment Sump Pump N.A. C Discharge 1PS-193 80 Sample from Accumulators N.A. C 1CC-1067 114 Containment CCW Drain N.A. C Tank Pump Discharge ICH-271 120 Chilled Vater Supply to N.A. C Containment Coolers ICH-272 121 Chilled Water Supply N.A. C from Containment Coolers 3.1-19 Rev. O

ATTACHMENT 1 DRAFT TABLE 3.1.1 (Continued)

TABLE NOTATIONS

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

Note 1: These are closed systems which meet the requirements of VUREG-0800 Section 6.2.4. II.6 paragraph o. These valves are trerefore not required to be leak tested.

Note 2: These valves inside containment are part of closed systfas outside containment which are in service post accident at a presimre in excess of containment design pressure and satisfy singit failure criterion. These valves are therefore not required to be leak tested.

Note 3: These are closed systems outside containment which are in service post accident and have a water filled loop seal on the containment side of the valves for a period greater than 30 days following the accident. These valves are therefore leak rate tested with water of a pressure of P,.

Note 4: These ESF valves are normally open and remain open during post-accident conditions. Post-accident they are continually pressurized in excess of containment pres.nure from an ESF source which meets the single failure criterion. These valvas are therefore not required to be leak tested.

Note 5: An effective fluid seal on these penetrations is provided by the suction sources to the residual heat removal pumps during and following an accident. In addition, these containment isolation valves are non-automatic, are not required to operate ,

post-accident and are located inside containment. These valves !

are therefore not required to be tested. I Note 6: All four MSIV bypass valves are locked closed in Mode 1. During Mode 2. 3. and 4 one MSIV bypass valve may be opened provided the other three MSIV bypass valves are locked closed and their i associated MSIVs are closed.

Note 7: These are parallel ESF valves that are normally closed, but are designed to open during post-accident conditions. Failure of one 1 valve to open vill not prevent system pressurization on both sides of both valves in excess of containment pressure. These ,

valves are sherefore not req:iire6 to be leak tested. I Note 8: These valves located outside con ainment are normally closed and see a pressure in excess of containment pressure in post-accident ,'

conditions. A valve stem leakage check vill be performed on a quarterly basis to ensure no significant stem leakage would occur in post-accident conditions.

i Note 9: These valves require steam to be tested and are thus not required [

to be tested until the plant is in MODE 3.

I 3.1-20 Rev. 0 '

ATTACHMENT 1 DRAFT TABIE 3.1.1 (Continued)

TABLE NOTATIONS Note 10 These valves vill have water against them during post-accident conditions to praclude any release of containment atuosphere to the environment.

Note 11: These valves are normally locked closed and are open only to warm up the steam supply lines prior to normal surveillance testing.

Note 12 These valves are included for table completeness, the requirements of Specification 3.6.3 do not apply. Instead, the requirements of Specification 3.7.1.1, 3.7.1.5 and 3.7.1.6 apply for main steam safety valves, mainsteam isolation valves, and feedvater isolacion valves, respectively.

BASES 3.1 CONTAINMENT ISOLATION VALVES The OPERABILITY of the containment isolation valves ensures that the containment atmosphere vill be isolated from the outside environment in the event of a release of radioactive material to the containment atmosphere or pressurization of the containment aad is consistent with the requirements of General Design Criteria 54 through 57 of 10CFR50 Appendix A.

Containment isolation within the time limits specified for those isolation valves designed to close automatically enseres that the release of radioactive material to the environment will be consistent with the assumptions used in the analyses for a LOCA.

l f

f 3.1-21 Rev. O

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l. >

ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 4.i $NURBER INSERVICE INSPECTION PROGRAM NOTE: This Technical Requirement contains the augmented insetvice inspection program for snubbers. Although the CPSES Technical Specification is repeated here, in part, care must be taken not l to overlook Technical Specification requirements.

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t 4.1-1 Rev. O i

ATTACHMENT 1 DRAFT 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 tsquirements are those installed on nonsafety-related systems and then only if their failure, or failure of the system on which they are installed would have no adverse effect on any safety-related system.

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

on systems required OPERABLE in those MODES.

MODES 5 and 6 for snubbers located %

ACTION:

With one or more snubbers inoperasle, within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months replace or restore the inoperable snubber (s) to OPERJ.BLE status and perform an engineering evaluation in accordance with the approved augnented inservice inspection program, on the attached component or declare the attached system (s) inoperable and follow the approprfate ACTION statement for that system (s). 4 <

SURVEILLANCE REQUIREMENTS O

Q 4.7.9 Each anubber sball be demonstrated OPERABLE by performanes of E the requirements of the approved augmented inservice inspection program. g O

W

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13 O

O N

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0 3

4.1-2 Rev. O

O e

ATTAC10ENT 1 DRAFT Technical Requirement 4.1 SNUBBER INSERVICE INSPECTION PROGRAM (1.ATER) a 4.1-3 Rev. O

O ATTACHMENT 1 DRMT TECHNICAL REQUIREMENT 4.2 SEALED SOURCE CONTAMINATION OPERABILITY CRITERIA 4.2 Each sealed source containing radioactive matsrial either in excess of 100 microcuries of beta and/or gamma emitting material or 5 microcuries of alpha emitting material shall be fres of greater than or equal to 0.005 microcurie of removable contamination.

APPLICABILITY: At all times.

COMPENSATORY MEASURES:

i With a sealed source having removabis .ontamination in excess of the above limits, immediately withdraw the sealed source from use and either:

1. Decontaminate and repair the sealed source, or

2. Dispose of the sealed source in accordance with Commission Regulations. l TESTS / INSPECTIONS 4.2.1 Test Requirements - Each sealed source shall be tested for leakage and/or contamination by

a. The licensee, or

b. Other persons specifically authorized by the Commission or an Agreement State.

The test method shall have a detection sensitivity of at least 0.005 microcurie per test sample.

4.2.2 Test Frequencies - Each category of sealed sources (excluding startup sources and fission detectors previously subjected to core flux) shall be tested at the frequency described below. l

a. Sources in use - At least once per 6 months for all sealed sources containing radioactive materials

1) With a half-life greater than 30 days (excluding -

Hydrogen 3), and i

2) In any form other than gas, i

l 4.2-1 Rev. O !

l

O ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT 4.2 SURVEII.I.ANCE REQUIREMENTS (Continued)

b. Stored sources not in use - Each sealed source and fission detector shall be ested prior to use or transfer to another

licensee unless tested within the previous 6 months. Sealed ;

sources and fiJsion detectors transferred without a certificate indicating the last test date shall be tested prict to being [

placed into use: and

c. 3tartup sources and fission detectors - Each sealed startup source and fission detector shall be tested prior to installation or within 31 days prior to being subjectes to core flux and following repair or maintenance to the source.

4.2.3 Repotta - A report shall be prepared and submitted to the Commission on an annual basis it sealed source or fission detector leakage tests reveal the presence of greater than or equal to 0.005 microcurie of removable contamination.

i I

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BASES r

4.2 SEALLD TOURCE CONTAMINATION The limitations on removable contamination for sources requiring leak (

testing, including alpha emitters, in based on 10Cra70.39(c) limits for plutonium. This limitation vill ensure that leakage from Byproduct. 1 Source, and Special Nuclear Material sources vill not exceed allowabla intake values. i l

Sealed sources are classified into three groups according to their use, with Surveillance Requirements commensurate with the probability of damage ,

to a source in that group. Those sources which are frequently handled are !'

required to be tested more often than those which are not. Sealed sources which are continuously enclosed within a shielded techanism (i.e., sealed '

sources within radiation monitoring or boron reasuring devices) are considered to be stored and need not be tested unless they are removed from :

the shielded mechanism. l l

4.2-2 Rev. O

r l-e ATTAsIOIENT 1 DRAFT {

' i TEC10lICA1, REQUIREMENT $.1 CONTAflOGNT PDIETRATION CONDUCTOR OVERCURRENT l PROTECTION DEVICEg NOTE: This Technical Requirement contains the listing of overcurrent !

protection devices subject to the requirements of Specification j 3.8.4. Although the Specification is repeated here, care must be j taken not to overlook Technical Specification Requirements, j l !

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1 5.1-1 Rev. O

ATTACHMENT 1 DRAFT 3/4.8.4 ELECTRICAL EQUIPMENT PROTECTIVE DEVICES CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES LIMITING CONDITION FOR OPERATION 3.8.4 The containment penetration conductor overcurrent protective devices shall be OPERABLE.

APPLICABILITY: Mndes 1, 2. 3. and 4 ACTION:

kith one or more of the containment penetration conductor overcurrent protective device (s) inoperablet

a. Restore the protective device to OPERABLE status ort

1. Deenergize the circuit (s) by racking out. locking open, or removing the iaoperable protective devica d tripping / removing the associated protective device within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months , declare the @

affected system or component inoperable, and verify the O inoperable protective device racked out. locked open, or removed at least once per 31 days thereaf ter, the provisions of Specification 3.0.4 are not applicable to overcurrent protective devices in circuits which have their associated protective device E

sua s -

tripped / removed and their inoperable protective devfte racked O out. locked open, or removed; or g' on

2. Deenergine the circuit (s) by tripping / removing the associated protectiva device g racking out. locking open, or removing the inoperable protective device within 72 hovrs. declare the @.

affected systes or component inoperable, and verify the g associated protective device to be tripped /renoved or the g inoperable protective dt..tec racked out. locked open, or removed w at least once per 7 days thereafter, the provisions of O Specification 3.0.4 are not appiteable to overcurrent protective m' devices in circuits which have their associated protective device tripped / removed or their inoperable protective device racked out, )

g locked open, or removed or b.

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

g"*

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

a. At least once per 18 monthst

1) By verifying that the medium voltage 6.9KV and lov voltage 480V svitchgear circuit breakers are OPERABLE by selecting, on a rotating basis, at least one or 10% of the circuit breaker (whichever is greater) of each current rating and performing the following:

5.1-2 Rev. O

ATTACMMENT 1 DRAFT ELECTRICAL EQUIPMENT PROTECTIVE DEVICES SURVEILLANCE REQUIREMENTS a) A CHANNEL C/LIBRATION of the associated protective 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 C c) For each circuit breaker found inoperable during these functional tests, one or an additional representative @

. ample of at least 10% of all the circuit breaker of the inoperable type shall also be functionally tested until no more failures are found or all circuit breakers of that @'

type have been functionally tested; and

2) By selecting and functionally testing a representative sample of '

at least 10% of each type of 480V molded case circuit breakers and lower voltage circuit breakers. Circuit breakers selected O

for functional testing shall be selected on a rotating basis.

O Testing of these circuit breakers shall consist of injecting a g.

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 3

trip element, and verifying that the circuit breaker operates within the time delay band width for that cur ent specified by O

the manufacturer. The instantaneous element shall be tested by suma injecting a current equal to 220% of the pickup value of the element and verifying that the circuit breaker trips ya instantaneously with no intentional time delay. Molded case VJ circuit breaker testing shall also follow this procedure except 'Q that generally no more than two trip elements time deley and g instantaneous, will be involved. The instantaneous element for molded case circuit breakers shall be tested by injecting a O current for a frame size of 250 amps or less with tolerances of '

+40% -25% and a frame size of 400 amps or greater of 225% and verifying that the circuit breaker trips instantaneously with no 2 g

apparent time delay. Circuit breakers found inoperable during a functional testing shall be restored to OPERABLE status prior to M resuming operation. For each circuit breaker found inoperable during these functional tests, an additional representative [

a sample of at least 10% of all the circuit breakers of the w inoperable type shall aleo be functionally tested uns ',1 no more failures are found or all circuit breakers of that type have been E

functionally 1isted.

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 recon =endations.

5.1-3 Rev. O

, e ATTAC10GNT 1 DRAFT I TECHNICAL REQUIRDfENT 5. I <

l TAlt.E 5.1.1 l i

CONTAINNENT PPNETRATION CONDUCTOR l NJrECTIVE DEVICES [

f DEVICE NUMBER SYTTEM !

AND I.0 CATION POWERED !

, 1. 6.9 RVAC from Switchgeara !

i

a. Switchgear Bus lAl RCP #11 l

!) Primary Breaker IPCPX1 i t

a) Relay 50H1-51 !

b) Relay 26 '

c) Relay 86M i f

2) Backup Mreakers IA1-1 or 1Al-2 I

a) Relay 51M2 ;

b) Relay 51 for 1Al-1 c) Relay 51 for 1Al-2 l d) Re',ay 86/1A1

b. Switchgear Bus 1A2 RCP (12 f

1) Primary Breaker IPCPX2 a) Rulay 50M1-51 (

b) Relay 26 I c) Relay 86M i

2) Backup Breakers lA2-1 or IA2-2 a) Relay 51M2 b) Relay 51 for IA2-1 c) Relay 51 for 1A2-2 d) Relay 86/1A2

c. Switchgear Bus IA3 RCP #13

1) Primary Breaker IPCPX3 !

a) Relay $1M1-51 k b) Relay 26 !

c) Relay 86M !

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5.1-4 Kev. O

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

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ATTACHNUT 1 DRA/T l l

TECHNICAL REQUIREMENT 5.1 [

t TABLE 5.1.1 (Continued) i I

C0NTAINMENT PDETRATION CONDUCTOR l l

5 DEVICE NUMBER SYSTDI I AND LOCATION POWERED

1. 6.9 KVAC from Switchgears (Continued) i

2) Backup Breakers 1A3-1 or 1A3-2 i

a) Relay 51M2 l b) Relay 51 for 1A3-1 [

c) Relay 51 for 1A3-2 d) Relay 86/1A3

d. Switchgear tus 1A4 RCP #14 f

1) Primary Breaker ITCPX4 f

a) Relay 50M1-51 b) Relay 2f {

t c) Relay 86M I

\ I l 2) Backup Breaker 1A4-1 or 1A4-2 l a) Relay $1M2 f b) Relay 51 for 1A4-1 !

l c) Relay 51 for 1A4-2 i d) Relay 86/!A4 l

t

2. 480 VAC from Switchgears ,

1 2.1 Device Location - Containment l 480V Switchgears 1EBl. 1EB2 Recirc. Tans t IEB3 and 1EB4 and CRDM Vent Tans

( a. Primary Breakers - 13AV1 c l IfNAV2. 15AV3 ITILAVd,. l 1FNCBI and ITNCB2 i i

b. Backup Breakers - 1EB1-1 j 1EB2-1, 1EB3-1 and 1EB4-1

1) Long Time & Instantaneous Relays

50/51 50 gg (IEB1-1) g/51 (1EB2-1) y 50/51 50/51 -

g 3 (1E33-1) 797;74(1EB4-1) 50/51 50/51 I15Dil (1EB3-1) M 2(IEI'"I) 5.1-5 Rev. O ;

i

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ATTACHNENT 1 DRAFT L TECNNICAL REQUIRDfENT 5.1 t

TABLE 5.1.1 (Continued) '

CONTAINNENT PENETRATIC'd CONDUCTOR I I

t DEVICE NUMBER SYSTEM ,

AND LOCATION POWERED l

2. 460 VAC from Switchgears (Continued) l i

2) Time Delay Relays ,

t 62-1662-1X gggg,g) 62-1662-1X (IEB2-1) 1FNAV1 1FMAV2 l 62-1662-1X ggg gg) 62-1662-1X (1E32-1) I 1FNAV3 1FNAV4 (

l 62-1662-1X 1FNC81 (1EB3-1) 62-1662- 1FNCl2 n (1E34-1) i i

2.2 Device Location - 480V Containment [

Switchgear '3B4 Polar Crane !

t

a. Primary Breaker - ISCCP1

b. Backup Breaker 1EB4-1 l.

1) 51 ISCCP1 [

t

2) 62 !

TIN.TT

3. 430/AC from Mstor Control Centers 3.1 Dov'ee Location - MCC 1E31-2 Containment Numbers !

listed below. l Primary and Backup - Both primary and backup breakers Breakers have identical trip ratings and are (

in the same MCC Covt. These L breciers are General Electric type j 1HED or THFK with thermal-magnetic !

trip elements. I

Associated circuit breaker shown in parentheseJ; e.g. ,1EB3-1, is backed to ITNAV3 and 1TNCBl.

I 1

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3.1-6 Rev. O

o ATTACHMENT 1 DRAFT !

TECHNICAL REQUIREMENT 5.1 TABLE 5.1.1 (Continued) l CONTAINMENT PENETRATION CONDUCTOR -

OVERCURRENT PROTECTIVE DEVICES t DEVICE NUMBER AND LOCAT:0N

3. 480VAC from Motor Control Centers (Continued)

MCC 1EB1-2 C.E.

COMPT. NO.

~

BKR. TYPE SYSTEM POWERED 4G THED Motor Operated Valve 1-TV-4691 4M THED Motor Operated Valve 1-TV-4693 3P THED Containment Drain Tank Pump-03 9H THED Reactor Cavity Sump Pump-01 9h THED Reactor 9avity Sump Pump-02 7H THED Containment Sump fl Pump-01 7M THED Containment Sump fl Pump-02 6H ThED RCP #11 Motor Space Heater-01 6M THED RCP #13 Motor Space Heater-03 8D THED Incore Detector Drive "A" 8D THED incore Detector Drive "B" 7B THED Incore Detector Drive "P" 3B THG Stud Tensioner Holst Outlet-01 7D THED Hydraulic Deck Lift-01 i 4B THED deactor Coolant Pump Motor Hoist ,

Receptacle-42 Bli DIED RC Pipe Penetration Cooling Unit-01 SM THED RC Pipe Penetration Cooling Unit-02 5H DIED RCP 911 011 Lift Pump-01

SM THED RCP #13 011 Lift Pump-03 l

105 THED Preaccess P11ter Train Package l Receptacle-17 5B THED Containment Ltg XFMR-14 (PNL-C3) l 10P YHED S.C. Vet Layup Cire. Pump 01 l (CPI 4.MPRP-01) l 12M THED S.C. Vet Layup Cire. Pump 03 l (CPI-CTAPRP-03) 12H THFK Cont. Ltg. Transf. CPI-ELTRNT-28 !

(AULC-11AMC-12) i 5.1-7 Rev. 0

o ATTACHMENT 1 LRAFT TECHNICAL REQUIREMENT 5.1 TABLE 5.1.1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR

~

0VERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480VAC from Motor Control Centers .(Continued)

MCC IEB1-2 C.E.

COMPT. NO. BKR. TYPE SYSTDI POVERED 6D THED kefusiing stachine (Manipulator Crane-01) 2M THED RC Drain Tank Pump No. I 2F THED Containment Itg XFMR-16 (PNL C7 & C9)

IM THED Containment Ltg X*MR-12 (PNL Cl & C5) 3M THED Preaccess Fan No, 11 3.2 Device Location - MCC IEB2-2 Containment Numbers listed below.

Primary and Backup - Both primary and backup breakers have Breakers identical trip ratings and e e located in l the same MCC compt. These breakers are General Electric type THED and THFK with thermal-magnetic trip elements.

MCC lEB2-2 G.E. I COMPT. NO. BKR. TYPE SYSTEM POVERED ,

4G TH ED Motor Operated Valve 1-TV-4692 4M THED Motor Opsrated Valve 1-TV-4694 3F THED Containment Drain Tank Pump-04 ;

7H THED Containment Sump No. 2 Pump-03 7M THED Containment Sump No. 2 Pump 04 6H THED RCP No. 12 Motor Space Heater-02 1 6M THED RCP No. 14 Motor Spact Heater-04 I l 5B THED Incore Detector Drive "C" i 1

2B THED Incore Detector Drive "D" 7B THED Incore Detector Drive "E" ,

l 5D THED Containment Fuel Storage Crane-01 '

l 1

3B THED Stud Tensioner Heist Outlet-02

\

l 4B THED Containment Solid Rad Waste Compactor-01 l

5.1-8 Rev. 0

.c ATTACHMENT 1 DRAFT TECHNICAL REQUIRFMENT 5.1 TABLE 5.1.1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LOCATION

3. 480VAC from Motor Control Centers (Continued)

MCC IEB2-2 0.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 10B THED RCC Cha ige Fe:ture Hoist Drive-01 10F THED Refuel.ng Cavity Skimmer Pump-01 12B THED Pever Receptacles (Cont. E1. 841')

IM THED S.C. l'et Layup Cire. Pump 02 (CPI-cFAPRP-02) 12M THED S.C. Wet La>up Cire. Pump 04 (CPI /FAPRP-0()

8H THED RC Pipe Penetration Fan-03 8M THED RC Pipe Penetration Fan-04 5H THED RCP #12 011 Lift Pump-02 SM THED RCP #14 011 Lift Pump-04 12H THED Preaccess Tilter Train Package Receptacles - 18 ;

6D THED Convainment A2x111ary Upper Crane-01 i 2T THED Containment Ltg. XIER-13 (PNL C-2) 7D THED Containment Elevator-01 t 2D THED Containment Access Rotating i l Platform-01 l 2M THED Reactor Coolant Drain Ta k Pump-02 I 9F THID Containment Ltg. XFMER-47 (PNL C8&C10) ,

l 9M THID Containment Ltg. XFKR-15 (PNL C4&C6) I 1 [

3M THED Preaccess Tan-12 l IG THTK Containment Welding Mschine Power l Supply Unit l 3.3 Device Location - MCC lEB3-2 Containment numbers listed below. f Primary and Backup - Unless noted otherwise, both primary !

Breakers and backup breakara have identical trip ratings and are located in the same MCC coept. These breakers are General Electric type THED or THFK with thereal-magnetic trip elements. ;

I l

l 5.1-9 Rev. 0 1

\

O e

ATTACHMENT 1 DRAFT TEC.JiICAL REQUIRD(ENT 5.1 TABLE 5.1.1 (Continued)

CONTAINMENT PENETRATION C01 JUCTOR OVERCURRENT PROTEC*IVE DEVICES DEVICE NUMBER AND LOCATION

3. 480VAC from Motor Control Centers (Continued)

MCC IEB3-2 C.E.

COMPT. NO. BKR. TYPE SYSTEM POWERED 8RF TH ED JB-IS-1005 for Altern. Feed to Motor Operated Valve 1 a702A IG THED Motor Operated Valve 1-8112 90 THED Motor Operated Valv- 1-8701A 9M THED Motor Operated Valve 1-8701B 5M THED Motor Operated Valve 1-8000A 5G TH ED Motor Operated Valve 1-HV-6074 4G THED Motor Operated Valve 1-HV-6076 4M TH ED

Motor Operated Valve 1-HV-6078 2G INED Motor Operated Valve 1-HV-4696 2M THED Motor Operated Valve 1-HV-4701 3G THED Motor Operated Valve 1-HV-5541 3M THFD Motor Operated Valve 1-HV-5543 IM T'IED Motor Operated Valve 1-HV-f*83 6F FIED Motor Operated Valve 1-HV-8808A L 6M TH ED Motor Operated Valve 1-HV 8802C 7M THED Containment Ltg. XFMR-18 (PNL SCl&SC3)

BM THED Neutron Detector k' ell Fan-09 7F THFK Electric H Recombiner Power Supply FNL-01 BRM THED Fire Protection Containment Isolation l MOVI-HV-4075C l

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

l l

l l 5.1-10 Rev. O

.. i O

i LTTACNMENT 1 DRAFT TECHNICAL REQUIRDGNT 5.1 TABLE 5.1.1 (C,ontinued)

CONTAINMENT PENETRATION CONDUCTO ,R f vvsatvuRaux FRCFTECTIVE DEVICQ DEVICE NUMBER !

AND LOCATION i t

i

3. 480VAC from Motor Control Centers (Continued) i 3.4 Device Location - MCC 1E54-2 Csnts.inment numbere listed I below. [

primary and Backup - Unless noted otherwise, both primary Breakers and backup breakers have identical trip ratings and are located in the same MCC compt. These breakers are General Eltetric type W ED or THFK with thermal-sagnstic trip elements.

MCC lEB4-2 C.E.

COMPT. HO,, SKR. TYPE SYJTEM POWERED IM NED J3-IS-12300. Altern. Feed to Motor Operated Valve 1-87018 f 8G TIED Motor Operated Valve 1-8702A l

8M TdED Motor Operated Valve 1-87025 !

4M THED Motor Operated Valve 1-80005 I 4C THED Motor Operated Valve 1-HV-6075 !

3C THED Motor Operated Valve 1-HV-6077 JM THED* Motor Operated Valve 1-HV-6079 2G THED Motor Operated Valve 1-HV-5562 2M THED Motor Operated Valve 1-HV-5563 .

3F THED Motor Operated Valve 1-88085 f

$M THED Motor Operated Valve 1-8808D !

6M THED Containment Ltg. XD0t-19 (PNL SC2&SC4) f 7M THED Neutron Detector Vell Tan-10 !

j 6F T3FK Elect. H Recombir.er Power Supply FNL-02

Primary protection is prsvaded by Could Tronic TR5 fusible switch with j 3.2A fuse. ;

I i

I 5.1-11 Rev. 0

O ,

ATTACHMENT 1 DhAFT TECHNICAL REQUIREMENT 5.l_

TAB 1.E 5.1.1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRFA'T PROTECTIVE DEVICES DEVICE Nt*KBER SYSYEM AND LOCATION POVERED

4. 480VAC Trom Pane! boards Tor Prassuriser Pressuriser Heaters Heaters

a. Primary Breakers - Gereral Electric Type TJJ Thermal Magnetic !

breaker. I Breaker No. & Location - Ckt. Xos. 2 thru 4 of Panelbosrds (

1EB1-1. IEB1-2, 1EB2-2, 1EB3-7..

1EB4-1,1EB4-2 and Ckt. Nos. 2 thru 5 of Pane 1 boards 1EB2-1 and IEB3-1.

l

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

sensor. '

i t

Breaker No. & Location - Ckt. No. 1 of Pane 1 boards 1EB1-1 l 1EB1-2. 1EB2-1, 1EB2-2, 1EB3-1, 1EB3-2 t 1EB4-1 and 1EB4-2.

I

5. 120V Epace Heater circaits containment Rectre. Ten l frea 480V Switchgears and CRDM Vent. Tan Motor i Space Heaters L

a. Primary Breakers i BIR. LOCATION VESTINCHOUSE .

& NUMBER BER. TYPE I i

Svgr. 1EBl. 'JB 1010 Cubicle 3A

CP1-VATNAV-02 Space Heater Bkr.

Svgr. 1EB2 EB1010 Cubicle 3A CVP1-VATNAV-02 Space Heater Bkc.

Svgr. 1EB3 EB1010 Cubicle 9A CP1-VATNAV-03 Space Heater Bkr.

5.1-12 Rev. O

.h' O

ATTAC10fENT 1 DRAFT TECHNICAL REQUIREMEN" 5.1 TABLE 5.1.1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES

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

BKR. LOCATION VESTINGHOUSE

& NUMBER , 3KR. TYPE Swgr. IEB4, EB1010 Cubicla 9A CPI-VAFNAV-04 Swgr. IEB3, EB1010 Cubicle 8A, CP1-VAFNCB-01 Space Heater Bkr.

b. Backup Breakers BKR. LOCATION GENERAL ELECTRIC

& NUMBER BKk. TYPE Panel IEC3-2 TED Ckt. No. 3 Panel IEC3-2 TED Ckt. No. 4 Panel IEC4-2 TED Ckt. No. 3 Panel 1EC4-2 TED Ckt. No. 4

6. 125V DC Lighting Emerge

icy DC Lighting

a. Primary Breaker BREAKER LOCATION G.E. Bkr.

AND NUMBER TYPE DC Panelboard TFJ 1D2-1, Ckt #6

b. Backup Device - N/A (Fuse) 5.1-13 Rev. 0 l _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _

e l

~,

D ATTACHMENT 1 DRAFT TECHNICAL REQUIREMENT Sd TABLE 5.1.1 (Continued)

CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTIVE DEVICES DEVICE NUMBER AND LCCATION

7. 125V DC Control Power various

a. Primary Devices - N/A (Fuse)

b. Backup Breakers GENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XED1-1 1,6,7,8,9.10 TED XED2-1 1,3,6,7,8,9,10 TED XD2-3 8,9,12,14,17 TED 1ED2-1 7,10,12,15,16,17 TED 1EDI-1 7,10,14,17 TED .

1D2-3 7,10,11,14,17 TED XD2-1 11 TED

8. 11SV AC Instrument Distribution Panel Board 1C3-3

a. Primary Devices - N/A (Fuses)

b. Backup Breaker - GE Type TED located in Instrument '

Distribution Panel Board IC3-CKill

9. 120V AC Power for Personnel and Emergency Airlocks

a. Primary Devices - N/A (Fuses)

b. Backup BreikeTs GENERAL ELECTRIC PANELBOARD NO. CKT NO. BREAKER TYPE ,

XEC2 34 TED XEC1-2 2 TED L

t' r

5.1-14 Rev. 0

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

_r n

ATTAChifENT 1 DRAFT

10. 118V AC Control Power

a. Primary Devices - N/A (Fuses)

b. Backup Breakers CENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE XEC1-1 3.5,7,9,10,12 TED XEC2-1 3,5,7.9,10,12 TED :

IC2 12,22 TED 1 1C3 12,14 TED 1PCI 10,13 TED i IPC2 10 TED 1PC4 6,10 T ED IEC1 3,4,8,9 TED 1EC2 3,4,7,9 TED 1EC5 3,8 TED 1EC6 3,8 ten

11. Emergency Evacuation fratem Warning Lights Power

a. Primary Devices - N/A (Fuses)

b. Backup Breakers SQUARE D SINGLE POLE M ELB0ARD NO. CKT. NO. BREAKER TYPE XEC3 3 FAL-12020 XEC4 3 FAL-12020

12. DRPI Data Cabinet Power Supplies

a. Primary Devices - N/A (Fuses)

b. Backup Breakers CENERAL ELECTRIC PANELBOARD NO. CKT. NO. BREAKER TYPE l IC14 1,2 TED

BASES r

5.2 CONTAINMENT PENETRATION CONDUCTOR OVERCURRENT PROTECTION DEVICES The bases for OPERABILITY and surveillance of these devices are contained in the CPSES Technical Specifications.

All Clasa 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 OPER*BILITY or Surveillance Requirements for these devices, since they will not prevent safety-related valves from performing their function (refer to Regulatory Cuide 1.106, "Thermal Overload Protection for Electric Hotors on Motor Operated Valves," Revision 1, March 1977). ;

5.1-15 Rev. 0

,, - _----%

TXX-8877, Forwards Draft Rev 0 to Comanche Peak Steam Electric Station Tech Spec Improvement Program Tech Spec Requirements, Per NRC Rev 4a of Sts,For Review

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TXX-8877, Forwards Draft Rev 0 to Comanche Peak Steam Electric Station Tech Spec Improvement Program Tech Spec Requirements, Per NRC Rev 4a of Sts,For Review

Text

SUBJECT:

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