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Summary of 850419 Meeting W/Util & Westinghouse Re Current Draft of Tech Specs.List of Attendees,Slide Presentation & Draft Tech Specs Encl
	ML20128D361
Person / Time
Site:	South Texas
Issue date:	05/15/1985
From:	Kadambi N; Office of Nuclear Reactor Regulation
To:	; Office of Nuclear Reactor Regulation
References
	NUDOCS 8505290024
	Download: ML20128D361 (59)
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i' !gn, .. UNITED STATES

[ g NUCLEAR REGULATORY COMMISSION

r. - 'j wasHmGTON, D. C. 20666 I

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/ MAY 151985 Ui Docket Nos.: 50-498 y and 50-499

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APPLICANT: Houston Lighting & Power Company 9

l' FACILITY: South Texas Froject, Units 1 and 2 i

SUBJECT:

SUMMARY

OF MEETING HELD ON APRIL 19, 1985 TO DISCUSS

[ THE TECHNICAL SPECIFICATIONS CURRENTLY BEING DRAFTED The' applicant requested this meeting to acquaint NRC staff with the approach being used to draft the Technical Specifications for the South Texas Project.

They saw a need for the meeting because the design of the plant has unique

.! differences with respect to the typical Westinghouse plant undergoing safety

, review.

The attendees at the meeting are listed in Enclosure 1. The package of view graphs handed out at the meeting is enclosed as Enclosure 2.

Discussion:

The applicant imformed the staff that a Technical Specifications package would be submitted in June 1985. The intent of this' package would be to initiate a

review using available staff resources even though the beginning of the formal review process would not be expected to begin before November 1985. Also, the .

package is not expected to be complete in all respects. NRC staff generally 1 approved of this approach because the additional time could be used to accom-

.1- modate portions of the review which may take longer on account of the plant specific considerations.

The applicant made a presentation using the enclosed view graphs showing 1

[! significant examples of design differences between the South Texas design and the typical Westinghouse reactor design for which the Standard Technical 4 -Specifications (STS) are applied. .They' included proposed mark-up of the j STS pages.

NRC staff infonned the applicant that a standardized review process similar to 4.I recently issued licenses would be used for South Texas. The staff review would

i. be comprehensive. In addition, the applicant would be asked to certify that l complete consistency with the FSAR, the staff SER and as-built plant is assured.

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An example of the description of the Proof and Review phase of the Technical Specification development process is shown in the memorandum enclosed herein as Enclosure 3 applicable to the Perry Nuclear Plant. Enclosure 3 was distributed to the attendees at the meeting.

l5' N. Prasad Kadambi, Project Manager Licensing Branch No. 3 Division of Licensing

Enclosure:

As stated cc: See next page

Previous concurred on by: 7 1,

DL:LB#3 D l B#3 *D NPKadambi/es 'l ighton t er Etu,/85 f/p/85 f /85 6/1

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., An example of the description of the Proof and Review phase of the Technical J Specification development process is shown in the memorandum enclosed

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! herein as Enclosure 3 applicable to the Perry Nuclear Plant. Enclosure 3 was distributed to the attendees at the meeting.

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N. Prasad Kadambi. Project Manager

. Licensing Branch No. 3 Division of Licensing

Enclosure:

As stated cc: See next.page e

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! HAY 151985

.. MEETING

SUMMARY

DISTRIBUTION M S~

h [ 735igggi499 Local POR NSIC PRC System LB3 Reading Attorney, OELD

. GWKnighton i

Project Manager NPKadambi JLee NRC PARTICIPANTS .

Brian W. Sheron

, N. P. Kadambi Ed Butcher derry Wilson B. Mann l Calvin W. Moon 3

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,i bec: Applicant & Service List I

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. South Texas

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-1 Mr. J.-H. Goldberg .

William S. Jordan, III, Esq.

.; Group Vice President, Nuclear Harmon, Weiss & Jordan ti- Houston Lighting and Power Company 2001 S Street, N.W.

2- P. 0. Box 1700 Suite 430 7 Houston, Texas 77001 Washington, D. C. 20009 l . Brian Berwick, Esq.

Mr. J. T. Westermeir Assistant Attorney General

~[ Manager, South Texas Project . Environmental Protection Division

~i . Houston Lighting and Power Company P. O. Box 12548 P. O. Box 1700 Capitol Station Houston, Texas 77001 Austin, Texas 78711 hj

-1 Mr. E. R. Brooks Mr. Claude E. Johnson, Resident

1. Mr. R. L. Range Inspector / South Texas Project

Central Power and Light Company c/o U. S. NRC

/.i P. O. Box 2121 P. O. Box 910 4

Corpus Christi, Texas 78403 Bay City, Texas 77414 Mr. H. L. Peterson Mr. Jonathan Davis Mr. G. Pokorny Assistant City Attorney City of Austin City of Austin P. O. Box 1088 P. O. Box 1088 Austin, Texas 78767 Austin, Texas 78767 Mr. J. B. Poston Mr. A. Von Rosenberg Ms. Pat Coy City Public Service Board Citizens Concerned About Nuclear P. O. Box 1771 Power

San Antonio, Texas -78296 5106 Casa Oro .

I San Antonio, Texas 78233 J Jack R. Newman, Esq.

Ej Newman & Holtzinger, P.C. Mr. Mark R. Wisenberg j 1615 L Street, NW Manager, Nuclear Licensing 1 Washington, DC 20036 Houston Lighting and Power Company P. O. Box 1700 Melbert Schwartz,Jr., Esq. Houston, Texas 77001 Baker & Botts

] One Shell Plaza Mr. Charles Halligan

, - Houston, Texas 77002 Mr. Burton L. Lex

'.- Bechtel Corporation

] Mrs. Peggy Buchorn P. O. Box 2166 1 Executive Director Houston, Texas 77001 Citizens for Equitable Utilities, Inc.

Route 1. Box 1684

'.! Brazoria, Texas 77422

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Regional Administrator - Region IV U. S. Nuclear Regulatory Commission j 611 Ryan' Plaza Drive-

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Arlington, Texas 76011 il Mr. Lanny Sinkin ti Citizens Concerned About Nuclear Power j- c/o Nuclear Information and Research

. Service i 1346 Connecticut Avenue, N.- W.

.i Fourth Floor

'I Washington, D. C. 20036 j 'Mr. S. Head

': HL&P Representative

-i Suite 1309 7910 Woodmont Avenue Bethesda, Maryland 20814 i

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SOUTH TEXAS PROJECT ELECTRIC GENERATING STATION TECHNICAL SPECIFICATION STP/STS COMPARISON REVIEW

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Presentation: M.A. McBurnett STP Nuclear Licensing

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? INTRODUCTION p

i I. REASON FOR MEETING j.

A. UNIQUE PLANT DESIGN B. GET ACQUAINTED

" HISTORY II.

III. SCHEDULE IV. AGENDA i -

A. OVERVIEW OF DIFFERENCES i

i B. SYSTEM - TECHNICAL SPECIFICATION REVIEW

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f' DIFFERENCES TECHNICAL SPECIFICATION-SIMILAR 1 3/4.1 BORATION CONTROL CVCS NOT USED FOR ECCS BORATION SYSTEMS RWST INSIDE TEMPERATURE CONTROLLED BUILDING F.WST BORON CCNCENTRATION BASED ON RAPID REFUELING SIMILAR CONTROL RODS SIMILAR 3/4.2 POWER DISTRIBUTION LIMITS SIMILAR .

! 3/4.3 INSTRUMENT &CONTR0k.S i

SIMILAR 3/4.4 REACTOR COOLANT LOOPS 0 .

l SIMILAR SAFETY YALVES t

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HEATERS ALWAYS ON ESF POWER PRESSURIZER c ;

SIMILAR(MODELE's)

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' ISSUE Cont.

HIGH PRESSURE TO LOW PRESSURE ISOLATION VALVES DO NOT INDLUDE AN RHR w

SIMILAR

' RCS CHEMISTRY SIMILAR

- SPECIFIC ACTIVITY SIMILAR PRESSL'RE/ TEMPERATURE LIMITS 3 TRAIN 3/4.5 ACCUMULATORS s

NO CCP ECCS .

NO RHR PUMP NO THROTTLE VALVES RWST

, INSIDE BUILDING TEMPERATURE NOT AN ISSUE l1 .

SIMILAR 3/4.6 CONTAINMENT

l 3iRAIN(2TRAINSREQUIRED)

CSS 3

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~! RCFC 3 TRAIN 6 FANS

! CSS /RCFC NOT REDUNDANT

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' UNDER DEVP.0PMENT FIRE PROTECTION

,i 3 TRAINS -

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RAPID REFUELING j, 3/4.9 REFUELING

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OTHER TECHNICAL SPECIFICATION ACTIVITIES WOG t

AIF/ INDUSTRY

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1. ALLOW USE OF HHSI FOR CHARGING IN SHUTDOWN MODE q

2. RWST BORON CONCENTRATION

3. SG TUBE PLUGGING LIMIT

4. ACCUMULATOR BORON CONCENTRATION l S. MODE 4 & 5 DG REQUIREMENTS i

6. CSS /RCFC REQUIREMENTS 3

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, 3-TRAIN SYSTEhtS l1 il TRAINS NURIBER OF TRAINS WHICH OPERATE UNDER VARIOUS PLANT .

j I W ALLEO MST OsA l NORGAAL OPERATION SHUT 00WN ,

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3 i GENERATORS Ii ESSENTIAL .

COOLING 3 lI WATER

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3/4.8 ELECTRICAL POWER SYSTEMS

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, LIMITING CONDITION FOR OPERATION .

3. 8.1.1 As a minism, the following A.C. electrical power sources shall be d] OPERA 8LE:

b a. Two physically indtpendent circuits between the offsibnsmission net.w.o.rk V tha.Esita R"M.avWistrTMtrom Systea, anh and l i! - m ..

y- b. HRseparate and' independent diesel generators, each withy __

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l* dies / gene torun[ . /

'i APPLICA8ILITY: M00ES 1, 2, 3,gM ACTION: g oga. g ,

(; a'. WithfanWakoffsita required A.C. electrical circuit orAdiesel power sources operable,$generategof demonstrate the the ab OPERABILITY of the remaining A.C. sources by performing Speciff-q:] cations 4.8.1.1.la. and 4.8.1.1.2a.4) within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once er 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restore at least two offsite circuits

.i Ci diesel generators to OPERA 8LE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or 9 _

an ITn eaW be in at least NOT STAN08Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD Li

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

b. WithYne offsite circuit and perable, demonstrate the recuired A.C. electrical power sources

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d- @h- QPERASILITY of the)gghthag A.C. within sources by- "perforr ing Specific

{1 tions 4.8.1.1.la. and 4.8.1.1.2a.4) a ha s. s.

least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restorek V M asd**** MW O'l '

least HOT STAND 8Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN 9] within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Restore at least two offsite circuTts

.d g anct9gdiesel generators to 0PERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from the t< me of initihl loss or be in at least HOT STAN08Y 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 .

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c. With one diesel generator inoperable in addition to ACTION a. or b.

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above, verify that:

All required systems, subsystems, trains, components, and devices l 1

1.

that depend on the remaining CPERA8LE diesel generator as a source of emergency power are also OPERA 8LE, and

}

W-STS 3/4 8-1 -

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. i f.N wilft ELECTRICAL POWER SYSTEMS LIMITING CONDITION FOR OPERATION i

O ACTION (Continued)

When in MODE 1, 2, or 3, the steam-driven auxiliary feedwater !

j 2.

l pump is OPERABLE.

I If these conditions are not satisfied within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months be in at least F' HOT STAND 8Y 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 l

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

d. With two of the above required off!ite A.C. circuits inoperable, demonstrate the OPERA 8ILITY of , diesel generators by performing the requirements of Specification 4 . L1.2a.4) within I hour and at least l once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter, unless the diesel generators are already operating; restore at least one of the inoperable offsita sources to OPERAELE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least HOT STAfC8Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . With only one offsite source restored, restore at

- least two offsita circuits to 0PERA8LE status within'72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from time of initial loss or be in at least HOT STAM08Y 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 ,

e. With two of the above required diesel generators inoperable, demonstrate the OPERABILITY of two offsite A.C. circuits by perfoming the require-ments of Specification 4.8.1.1.la. within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at least once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; restore at leastmof the inoperable diesel trmLM generators to CPERABLE status within 2 heu'rs or be in at least HOT STAND 8Y 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 Msg .

'; following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months . Restoreldr>easvmondiesel generators to 1 OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months from time'bf initial loss or be in

v. least HOT STAM08Y within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within fj -

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

J; h SURVEILLANCE REQUIREMENTS i 4.8.1.1.1 Each of the abovt.reovired indanendent ci+cuits hat =m the offsite transmission network and theTBfism44VW Drsp')MWYgeef shall be: l

1 4Kik draw any adssu

' t a. Determined OPERABLE at least once per 7 days by verifying correct breaker alignments, indicated power availability, and

.}

b. Demonstrate ( 0PERA8LE at least once per 18 monD s during sh gdown by ---

l" y transferringymamwrMAarJuwmaTxa.orarM power sunelvh *[ 788.7ms as w.m.nor i normal circuft to T.no alternata circu~t.

1 9 4.8.1.1.2 Each diesel generator shall be demonstrated OPERABLE:

i

') a. In accordance with the frequency specified in Table 4.8-1 on a

,'. STAGGERED TEST BASIS by:

~

l 1). Verifying the fuel level 4 in =rdaMrterci(ededVdfuel tank, I

3/4 8-2

'l -

y-STS_ _ _ ._ . _

.C ' ELECTRICAL p0WER SYSTEMS gg !

, I M Til i SURVEILLANCE REQUIREMENTS (Continued)

)) ri ing the el vel in ef 1 ora e nk,

- ) Verifyi fuel tra sfa p s ts. d ran er fue f th st' age yst to e y d gi ao te ta f ri ing I ri ti off inv to

' i sto age - .

Q 5) L .innwp r -

b Verifying the diesel starts fros/s@

li . to at least (900] rpe in less than o%Iy4 condition and accelerates

r. equal to (10] seconds.*

,' The and (60] generator

+ 1 voltage and frequency shall be (4160] + (420] volts ,

L -

The dieseT g(en.2] Hz within (10]' seconds h fter the start signal.

one of the following signals:erator shall be started for this test by us a) Manual, or l

b) l Simulated loss-of-offsite power by itself, or I c) ,

Steulated loss of-offsite power in conjunction with an ESF Actuation test signal, or !

d) An ESF Actuation test signal by itself.

]

1 C..- 6[ Verifying the generator is synchronized, loaded to greater or equal to (continuous rating] kW in less than or equal to (60]

seconds", and operates with a load greater than or equal to (continuous rating] for at least 60 minutes, and 4

7) s Verifying the diesel generator is aligned to provide standby power to the associated emergency busses. l

yJ , b.

At least once per 31 days and after each operation cf the diesel

?. . where the period of operation was greater than or equal to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months by j W pfyf3 fuel tanks @ checking for and removing accumulated wa ITS c-1 i

"%wuw;MMA4%1%Ydf&

fue bilstoragetanks;4 by checking for and removing accumulate

^ t.

4

d. .

By sampling addition new fuel to storage oil inand:

tanks accordance with ASTM-04057 prior to 1

0 1) j By verifying is accordance with the tests specified in ASTM-0975-81 L.'i prior to addition to the storage tanks that the sample has:

y - , > - ?- , ,

i has di sel entra or art from ion condit ons s 11 be perfo lj L -

onc pe 184 days t se rvei ance sts an all her e gine s d on) .

th pu osa of th< rts f

?

. k 's p 1 pe od a /or oth s vet ance esti shall prec ded b an en ne we proc dures t t nec ic 1 s ss omne ded b the ufactu r dwearonthepleselengin is af sized.

W-STS 3/4 8-3

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hy ELECTRICAL POWER SYSTDes SURVEILLANCE REQUIREMENTS (Continued) -

i a) An API Gravity of within 0.3 degrees at 60*F, or a specific gravity of within 0.0016 at 60/60*F, when compared to the

,? supplier's certificate, or an absolute specific gravity at 60/60*F of greater than or equal to 0.83 but less than or

' equal to 0.89, or an API gravity of greater than or equal to.

27 degrees but less than or equal to 39 degrees; b) A kinematic viscosity at 40*C of greaf.ar than or equal tc 1.9 contistokes, but less than or equal to 4.1 centistokes (alternatively, Saybolt viscosity, SUS at 100*F of greater than 3

i or equal to 32.6, but not less than or equal to 40.1), if gravity was not deterisined by comparison with the supplier's certification; c) A flash point equal to or greater than 125'F; and d) A clear and bright appearance with proper color when tested

in accordance with ASTM-04176-82.

2) By verifying within 30 days of obtaining the sample that the other properties specified in Table 1 of ASTWD975-81 are set when tested in accordance with ASTM-0975-81 except that the analysis for sulfur may be perforised in accordance with ASTW01552-79 or ASTWO2622-82.

l, l e. At least once every 31 days by obtaining a sample of fuel oil in -

accordance with ASTM-02276-78, and verifying that total particulata

[: contamination is less than 10 ag/ liter when checked in accordance L!

with ASTWD2276-78, Method A; i

).

l= f. At least once per la months, during shutdown, by: .

g lt Subjecting the diesel to an inspection in accordance with 1) procedures prepared in conjunction with its manufacturer's 1

recommendations for this class of standby service; 1

2) Verifying the generator capability to reject a load of greater l than or equal to (largest single emergency load] kW while

maintaining voltage at (4160] + (420] volts and frequency at l

[60] + [1.2] Hz (less than or equal to 75% of the difference l between nominal speed and the Overspeed Trip setpoint, or 15%

' above nominal whichever is less];

Li~ ]

3) Verifying the generator capability to reject a load of (continuous

!{' rating] kW without tripping. The generator voltage shall not j-exceed (4784] volts during and following the load rejection; l Simufating a loss-of-offsite power by itself, and: l 4) l a) Verifying doenergization of the emergency busses and load r

shedding from the emergency busses, and l

1 b) Verifying the diesel starts on the auto-start sianalv f4r91)ds Agepdys5updes,41ttAerp6np6tJ9 ponrytted )

u , a-,

STS

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I ELECTRICAL POWER SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) -

I loads within (10] seconds, energizes the auto-connected

,. shutdown loads through the load sequencer and operates for greater than or equal to 5 minutes while its generator is loaded with the shutdown loads. After energization, the '

stea@-state voltage and frequency of the emergency busses shall be maintained at (4160] ! (420] volts and l

. [60] f,[1.23 Hz during this test.

5) Verifying that on an ESF Actuation test signal, without loss-of-l- .

offsite power, the diesel generator starts on the auto-start signal and operates on staney for greater than or equal to 5 minutes. The generator voltage and frequency shall be

+ + (1.23 Hz within (10] seconds i (4160]

after t 5e(420]

auto-start volts and signal;(60]

t Ee steady-state generator voltage and frequency shall be maintained within thesa limits de:ing

l this test; Simulating a loss-of-offsite power in conjunction with an ESF l e 6)

Actuation test signal, and:

I a) Verifying doenergitation of the emergency busses and load shedding from the emergency busses; f

Verifying the diesel starts on the auto-start signal, l.

b) energizes the emergency busses with permanently connected I l .,

loads within (10] seconds, energizes the auto-connected R;

emergency (accident) loads through the load sequencer and l7 operates for greater than or equal to 5 einutes while its l ,? generator is loaded with the emergency loads. After energitation, the steady-state voltage and frequency of

d. the emergency busses shall be maintained at (4160] !

4' (420] volts and (60] f, [1.2] Hz during this test; and q; ,

l c) Verifying that all automatic diesel generator trips, except engine overspeed and generator differential, are automatically bypassed upon loss of voltage on the j emergency bus concurrent with a Safety Injection Actuation j

l' signal.

Verifying the diesel generator operates for at least 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months . l 7)

N .

During the f.irst 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months of this test, the diesel generator l shall be loaded to greater than or equal to [2-hour rating] kW and daring the remaining 22 hours2.546296e-4 days 0.00611 hours 3.637566e-5 weeks 8.371e-6 months of this test, the diesel

generator shall be loaded to greater than or equal to (con-tinuous rating] kW. The generator voltage and frequency shall be (4160] 1 (420] volts and (60] ! [1.2] Hz within (10] seconds after the start signal; the steady-state generator voltage and

,)

_Y ?? ?.?- l. ::~ _--_~ : : Y 7 ~ ~2

ELECTRICAL POWER SYSTEMS .

SURVEILLANCE REQUIREMENTS (Continued) frequency shall be maintained within these limits during this test. Within 5 minutes after completing this 24-hour test, perfom Specification 4.8.1.1.2e.6)b);" l

~ ~

8) Verifying that the auto-connected loads to each diesel generator do not exceed the 2000-hour rating of W; -

9)' Verifying the diesel generator's capability to: l a) Synchronize with the offsite power source while the

- generator is loaded with its emergency loads ipon a simulated restoration of offsite power, 4

b) Transfer its loads to the offsita power source, and c) Se restored to its staney status.

10) Verifying that with the diesel generator operating in a test l mode, connected to its bus, a simulated Safety Injection signal overrides the test mode by: (1) returning the diesel generator l' to standby operation, and (2) automatically energizing the g emergency loads with offsite power; fuel tr nsfer ual e

[ Veri f

ing sto ge t

to tr sfer day an engina soun tan of ea / ,

esel ta nstall cross onnergon1 s; / l l

12) Verifying that the autcastic load sequence timer is OPERA 8LE 1

with the interval between each load block within -+ 10% of its I 2 design interval; . .

l-

13) Verifying that the following diesel generator lockout features l prevent diesel generator starting only when required:

1 a) (Turning gear engaged), or b) (Emergency stop).

j

14) Verifying that with all diesel generator air start receivers lj pressurized to less than er equal to _ psig and the compressors secured, the diesel generator starts at least

.s

' [5] times from ambient conditions and accelerates to at least

[900] rps in less than or equal to (103 seconds.

R ij li

If Specification 4.8.1.1.2e.6)b) is not satisfactorily completed, it is not necessary to repeat the preceding 24-hour test. Instead, the diesel generator

'd

'j any be operated at (continuous rating] W for 1 hou'r or until operating temper- ,

Ej ature has stabilized.

i f

W-STS 3/4 3-6 er 93 -** Ty *N %g y'w-- w ey-~r -r s-w yy ++-e

~

t e

ELECTRICAL POWER SYSTEMS

~

$URVEILLANCE REQUIREMENTS (Continued)

g. At least once per 10 years or after any modifications which could

'! affect diesel generator interdependence by starting both diesel generators simultaneously, during shutdown, and verifying that both diesel generators accelerate to at least (9003 rps in less than or equal to (10] seconds; and .

h. At least once per 10 years by:

Draining each fuel oil storage" tank, removing the acctmulated l 1)

' sediment and cleaning the tank using a sodium hypochlorite

,sciution, and- ,

2) Performing a pressure test of those portions of the diesel fuel l i-

- oil system designed to Section III, subsection MD of the ASME

~

Code at a test pressure equal to 1105 of the system design pressure. ,

4.8.1.1.3 Reports - All diesel generator failures, valid or nonvalid, shall be reported to the Commission in a Special Report pursuant to Specification 6.9.2 within 30 days. Reports of diesel generator failures shall include the infoma-tion recommended'in Regulatory' .osition C.3.b of Regulatory Guide 1.108, Revi-I sfon 1, August 1977. If the number of failures in the last 100 valid tests (on a per nuclear unit basis) is greater than or equal to 7, the report shall be supplemented to include the additional information recommended in Regulatory '

" Position C.3.b of Regulatory Guide 1.108, Revision 1, August 1977.

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'. TA8LE 4.8-1 i

,. 'O!ESEL GENERATOR TEST SCHEDULE- -

NUISER OF FAILURES IN

~ TEST FREQUENCY LAST 100 VALIO TESTSa .

At least once per 31 days f' f,1

) At least once per 14 days 5 3 At least once per 7 days

>4 At least once per 3 days 5

4

{l .

t 1;

" Criteria for detemining number of failures and neber of valid tests shall be in accordance with Regulatory Position C.2.e of Regulatory Guide 1.108, Revision 1, August 1977, where the last 100 tests are detamined on a per nuclear unit basis. For the punose of this schedule, only valid tests conducted after the completion of the preoperational test requirements of Regulatory Guide 1.108, Revision 1 August,1977, shall be included in the computation of the "Last s 100 Valid Tests."

Ie P

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ii ll li 6

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STP TS 1

a a ELECTRICAL F0VER SYSTEMS _

A.C. SOURCES j

OPERATING - 0FFSITE TO ONSITE DISTRIBUTION LIMITING CONDITION FOR OPERATION

( .A

! The circuit from each 13.8kV standby bus to its associated auxiliary 3.8.1.3 ESF transformer and ESF bus shall be OPERABLE MODES 1, 2, 3 and 4.

i AFFLICABILITY:

f;.

ACTION:

j a.

With one circuit free a 13.8kV standby Bus to its associated EST Bus inoperable, demonstrate the OPERABILITY of th 4.8.1.1.1.s within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months and at Isast once per 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months thereafter; and Surveillance Requirement 4.8.1.1.2.a.2 within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months restore t' the circuit from each 13.8kV standby bus to its associated ESF bus

' to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least BO within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in a COLD SHUTDOWN within the following i

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

b. With two or more of the above required circuits from the 13.8kV 1 standby buses to the ESF buses inoperable, demonstrate the

'Q- OPERABILITY of three diesel generators by performing Surveillance .

Q Requirement 4.8.1.1.2.a.2 within 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months unless the diesel generators are alreadyWith operating; restore at leas s only two of the circuits STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

r. _; restored, to OPERABLE status restore all circuits from the 13.8kV I standby buses to ESF buses to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months 6 f lj j

time of initial loss or be in at least BOT STANDBY within bours and in COLD SEUTDOWN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

a q

?>

4 SURVEILLANCE REQUIREMENTS

j.

The above required A.C. circuits shall be demonstrated operable at 4.8.1.3 least c,nce per 7 days by verifying correct breaker alignment and indica N-d voltage on the ESF busses.

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ESSENTIAL COOLING WATER SYSTEM i

e SUPPLIES COOLING WATER TO VARIOUS SAF.ETY-RELATED SYSTEMS -

1 1

i FOR NORMAL PLANT OPERATION ASWELL AS NORMAL SHUTDOWN AND l

DURING AND AFTER POSTULATED DBA'S I

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4 PLANT SYSTEMS ESSENTIAL COCLING l 3/4.7.4 SFRWTNF, WATER SYSTEM i .,

-),

LIMITING CON 0! TION FOR OPERATION 1

+,

TM ESS9VTIAL CocuNd i 3.7.4 At least tun independent aeossaur-water A loops shall be OPERA 8LE. .

g -

i s~

- APPLICA81LITY: MODES 1, 2, 3, and 4.

s ACTION: -

Tko EM&'WTIAL C00L8Mg TbGthC

1. With only4eammunesdam w"ater loop OPERA 8LE, restore at. leastatus. loops to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STAN08Y 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 .

2 WITH ONLY CAff EMENTIAL lattiher N!ATER ** * * ' Sk HeltS i

SURVEILLANCE REQUIREMENTS

=)

I .

t 4.7.4 At least two service water loops shall be demonstrated OPERA 8LE:

a. At least once per 31 days by verifying that each valve (sanual, power-operated, or automatic) servicing safety-related equipment that is not locked, sealed, or otherwise secured in position is in its

, l,

-( correct position; and

b. At least once per 18 months during shutdown, by verifying that:

e

.' 1) Each automatic valve servicing safety-related equipment actuates to its correct position on a test signal, and

'l{

s 2) Each Service Water System puep starts automatically on a

' test signal.

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5 COMPONENT COOLING WATER SYSTEM e PROVIDE COOLING WATER TO VARIOUS NUCLEAR PLANT COMPONENTS DURING ALL MODES OF PLANT OPERATION ,

PROVIDE COOLING WATER TO COMPONENTS REQUIRED FOR NORMAL OPERATION .

) e PROVIDE AN INTERMEDIATE FLUID BARRIER BETWEEN POTENTIALLY '

RADIOACTIVE COMPONENTS ANDTHE ESSENTIAL COOLING WATER SYSTEM TO REDUCE THE POSSIBILITY OF RADIDACTIVE CONTAMINATION TO OUTSIDE ENVIRONMENT - .

'

PERFORM ITS COOLING FUNCTION FOLLOWING A DESIGN BASIS ACCIDENT WITH OFFSITE OR STAND 8Y POWER SOURCES .

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!) 3/4.7.3 COMP 0NENT COOLING WATER SYSTEM K! -

i A'

[j LIMITING CONDITION FOR OPERATION

. i WRCC * .

+

3.7.3 AEEEEEEEEEEEEEEpHEEEEGAcomponent cooling water loops shall be OPERA 8LE.

9 APPLICA8ILITY: MODES 1, 2, 3, and 4. ,

I

,1 ACTION: -

n TWO a With only womponent cooling water loop OPERA 8LE, restore at least two

, J.

i loops to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least NOT STAN08Y 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 .

g. WsiM ONs.Y ONC ContPluvENT. . . . . 24 HOURS. . . .

SURVEILLANCE REQUIREMENTS 4.7.3 At least two component cooling water loops shall be demonstrated OPERA 8LE:

a. ' At least once per 31 days by verifying that each valve (manual, l

power-operated, or automatic) servicing safety-related equipment that j

is not locked, sealed, or otherwise secured in position is in its

-4 correct position; and E! -

[j b. At least once per 18 months during shutdown, by verifying that:

1

1) Each automatic valv.e servicing safety-related equipment actuates to its correct position on a test signal, and (d Each Component Cooling Water System pump starts automatically Q 2) on a test signal.

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j REACTOR CONTAINMENT FAN COOLERS e THREE TRAINS WITH TWO FAN COOLERS PER TRAIN .

i

. e OPERATES DURING ALL MODES OF PLANT OPERATION

- NORMAL - NON ESSENTIAL CHILLEO WATER

- LOCA - CCW e FOR LOCA THREE RCFC COOLERS MUST OPERATE I

e REMOVES HEAT AND LOWERS CONTAINMENT PRESSURE (IN CONJUNCTION WITH CS) AND REJECTSTO CCW

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! < SOUTH TEXAS PROJECT .

I 3 TRAIN SYSTEMS ,

.j I NUNSER OF TRAINS WHICH OPERATE UNDER VARIOUS PLANT i

TRAINS M TDSA INSTALLE0 NORMAL OPERATION SHUT 00WN _

! OlESEL

' 3 SENERATORS .,.

ESSEllTIAL ,

COOLING 3 I WATER .

I

COMPONENT i COOLING 3

! WATER REACTOR 2 CONTAINMENT 3 2 2 I (3 RCFC UNITS)

FAN COOLER 3 (2 RCFC (4 RCFC UNITS) (4 RCFC UNITS)

] UNITS PER I TRAIN) 1 RESIOUAL 3 -

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i e SAFETY l INJECTION 3 l- .

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! CONTAINGRENT SPRAY ,

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LIMITING CON 0! TION FOR OPERATION FsVE RencioR ,

3.6.2.3 lHiEFA #:entainment cooling fans shall be OPERA 8LE..I

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=-_- y r= :_ : -- = - - r ---- :j g= _r =: = --

= g _- ,--- uy_; g d APPLICA81LITY: 20E5 1, 2,(3,-ausa.

N O' ACTION:

f1 re Rr4c.rog

! a. Witha g:entainment cooling fans inoper age er d, . ak 1 e , ^ ^ - - ^ - = - - - - - - - =;-;r--- = =- =2=. restorehthe inoper- ~'l oj -

I able gueurmer cooling fans to OPEAA8LE status within 7 days or be in g

1 at least HOT STAN08Y 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 .

~

,$. WITH TMRG RCACTOR CoNTAtWNT CooMM6 W3 INCMRABLE, RESTORE TWo Of. e *

T2 HK l '

O. v1 wo g ps or soove r uireo nsei. ns sovi'nv i.n

. I rable nd both ntaf Spra ystems PERA8 , res e at 1 east on group o cooling ns to ERA 8LE tatus ithin : hours l: or be 5

at les HOT ST 8Y wi n the withi the foi ing 3 t6 rs n COLD l urs. esto both ve reg red l' g s of c ing fans OPE LE sta s vi 7 da of ini fal l 1 s or be n at lea NOT Y wi in next 6 urs a in

. Lfl withi the f lawine hau n.

l L. WITH fo0R REACTOR CONTAl#1GNt CB05AR$ FANS IN0MRA6LE, RESTDRE THREE of *

24ItWM L, c. v one g up or apove . m rea conymirmenT. c ing ren i . .w u r nt Sp l 1e and con Systaa <pIbperable restore inoper-E: able Sp y Syst to OPE status thin 72 urs or in at l least T ST withi he next 6 ours n COLD i wi n the f owing hours. A tore the noperabl group of bj c taineen cooling ns to OPE LE stat within 7 ays of i tial b oss or in at la st NOT ST 8Y with the next hours a in d COLD wit # n the foi owing 30 urs.

Ii l

L- SURVEILLANCE REQUIREMENTS

($

p

,b

] 4.6.2.3 Each group of containment cooling fans shall be demonstrated OPERABLE:

a. At least once per 31 days by:

[ 1) Starting each fan grog from the control room, and verifying j that each fan group operates for at least 15 minutes, and of H- 2) Verifying a cooling water flow rate of greater than or equal to l

} ,,,,,,gpa to each cooler.

J

. b. At least once per 18 months by verifying that each fan group starts

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autsmatically on a test signal.

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4 RESIDUAL HEAT REMOVAL SYSTEM e RsMOVE HEAT. ENERGY FROMTHE CORE AND REACTOR COOLANT SYSTEM DURING PLANT C00LDOWN, AND REFUELING OPERATIONS

TRANSFER REFUELING WATER FROM THE REFUELING CAVITY TO j.

REFUELING WATER STORAGE TANK FOLLOWING REFUELING

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RHR HX'S ACT IN CONJUNCTION WITH THE LHSI PUMPS FOR EME CORE COOLING AND LONG TERM RECOVERY FOLLOWING A DBA t

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SOUTH TEXAS PROJECT jj 3-TRAIN SYSTEMS

'1 is NUMSER OF TRAINS WHICH OPERATE UNDER VARIOUS PLANT 114 TRAINS POST DBA --

3, J SYSTEM INSTALLE0 SHUT 004UN ,

NORMAL OPERATION -e 4'

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H CAVITY PRIOR TO REFUELING OPERATIONS

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BRAF EMERGENCY CORE C00 LIM SYSTEMS

- 3/4.5.2 ECCS SUBSYSTEMS - T,,, GREATER MAN OR E @ L TO 3504 LIMITING CONDITION FOR OPERATION TnREc 3.5.2 .YmeA 1 ndependent Emergency Core Cooling System (ECCS) subsystems shall be-OPERA 8LE with each subsystem comprised of:

HI6N HEa0 SAFGrY sggc.TIO!4

a. One OPERA A 8LE :: r " c:! i .,"., pump,

. tovvHt40 a : b. One OPERABLE 3 5afety Injection pump One OPERA 8LE RHR heat exchanger, l c.

. l dt. An OPERA 8LE flow path capable of taking suction from the refueling water storage tank on a Safety Injection signal and automatically l transferring suction to the containment sump during the recirculation phase of operation.

APPLICA8ILITY: MDOES 1, 2 and 3.

c, ACTION:

,e a. With one ECCS subsystem inoperable, restore the inoperable subsystem ,

Il to OPERA 8LE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least HOT STAN08Y

J j within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in HOT SHUTDOWN within the following 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

f. w TH Two ECCS . .

24 NovRS. . -

lj .

i=' c.t In the event the ECC5 is actuated and injects water into the Reactor I;

,4 Coolant System, a special Report shall be prepared and submitted to i

the Commission pursuant to Specification 6.9.2 within 90 days describ-O i ing the circumstances of the actuation and the total accumulated l- -,

actuation cycles to data. The current value of the usage factor for each affected Safety Injection nozzle shall be provided in this l? Special Report whenever its value exceeds 0.70.

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4 EFERGENCY CORE C00 LING SYSTEMS ,

SURVEILLANCE REQUIREMENTS 4.5.2 Each ECCS subsystem shall be demonstrated OPERA 8LE:

a. At least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that the following valves are in the indicated positions with power to the valve operators

, removed:

Valve Number Valve Function Valve Position

.l

.e -

b. At least once per 31 days by:

1) Verifying that the ECCS piping is full of water by venting the ECCS pump casings and accessible discharge piping high points. *

. and '

2) Verifying that each valve (manual, power-operated, or automatic) l in the flow path that is not locked, sealed, or otherwise secured in position, is in its correct position.

c. By a visual inspection which verifies that no loose debris (rags, trash, clothing, etc.) is present in the containment which could be transported to the containment sump and cause restriction of the purs suctions during LOCA conditions. This visual inspection shall be performed:

, 1) Fce all accessible areas of the containment prior to establish- l -

ing CONTAIMIENT INTEGRITY, and n

,3

2) Of the areas affected within containment at the completion of I l9 sach containment entry when CONTAlle9ENT INTEGRITY,is established.

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p. AT LRST CNCE PER s8 gs DY -

on of the containment sump and verifying that l Eli A A visual ins the subsystam suction inlets are not restricted by debris and that the sump components (trash racks, screens, etc.) show no ij evidence of structural distress or abnormal corrosion.

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EMERGENCY CORE COOLING SYSTDtS .

SURVEILLANCE REQUIREMENTS (Continued)

e. At least once per 18 months, during shutdown, by:

i 4

1) Verifying that each automatic valve in the flow path actuates I to its correct position on (Safety Injection actuation and -

Automatic Switchover to Containment Sump) test signals, and l

2) Verifying that each of the following pumps start automatically

. p receipt of a safety Injection actuation test signal: ^

HIGH HEAD SAFETY INJECTioV

' [

a) gGEEEEEEugEEEEEEgEER pump, b) ofyInjectionpump,and . k N .

I

f. By verifykng that each of the following pumps develops the indicated differential ' pressure on recirculation flow when tested pursuant to Specification 4.0.5:

1) 1_ psid,

2) LOW HEADAsafety Injection pump 1 psid, and M p,' i - M

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EMERGENCY CORE COOLING SYSTEMS SURVEILLANCE REQUIREMENTS (Continued) '

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SPRAY CONTAINMENT BUILDING AND CONTROL pH TO ABSOR8E 1 2 IN ATMOSPHERE 1 t

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t CONTAlleIENT SYSTEMS 3/4.6.2 DEPRESSURIZATION AND COOLING SYSTEMS -

y i

CONTADe4ENT SPRAY SYSTEM (Credit taken for iodine removal]

g -

4 LINITING CCCITION FOR~ 0PERATION .

i THREE

j 3.6.2.1 1mm independent Containment Spray Systems shall be OPERA 8LE with each

~1 5 pray 5 tan capable of taking suction from the RWST and transferring suction 4- - to the containment sump.

- APPLICA8ILITY: MOES1,2,(3 -

ACTION:

t. With one Containment Spray System inoperable, restore the inoperable Spray

!' System to OPERA 8LE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or be in at least NOT STAN08Y within j the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months ; restore the inoperable Spray System to OPERA 8LE status t

within the next 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in COLD SHUT 00WN within the following 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

WITH Two CourA4erxr S AY .SysTEsts . . . . 44 Hour.5. . . . .

L. SURVEILL=CE REQUIR 5 4.6.2.1 Each containment Spray System shall be demonstrated OPERABLE: l l!'l a. At least once per 31 days by verifying that each valve (manual, -

. power-operated, or automatic) in the flow path that is not locked, I d, sealed, or otherwise secured in position, is in its correct position; :

By verifying, that on recirculation flow, each pump develops a De j.4 b.

discharge pressure of greater than or equal to psig when N tasted pursuant toispecification 4.0.5; l

}

I, c. At least once per la months during shutdown, by:

a l

1) Verifying that each automatic valve in the flow path actuates to its correct position on a test signal, and l

2) Verifying that each spray pump starts automatically on a c

- test signal.

F .

1

d. At least once per 5 years by performing an air or smoke flow test N through each spray header and verifying each spray noule is Lj unobstructed. .

0 l 1

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~~'/ I*,, UNITED STATES nelosure 3~~

~~[ y, NUCLEAR REGULATORY COMMISSION j r. ,~~

~~j wassmoTow. o. c.2 ossa~~

~~.,,,, *# April 8,1985~~

~~l Lt i~~
MEMORANDUM FOR: Those on Attached List 1
FROM: Dennis M. Crutchfield, Assistant Director for Safety Assessment
~~Division of Licensing~~
~~SUBJECT:~~
PROOF AND REVIEW OF THE PERRY UNIT 1 TECHNICAL SPECIFICATIONS t
The attached technical specifications for Perry Unit 1 are being forwarded to you at this time for proof and review. We request that you review those ,
sections which pertain to your particular area of responsibility and that the
' results of this review, identifying the sections reviewed, be forwarded to the Technical Specification Review Group (TSRG) by May 6,1985. We are distributing these technical specifications at the NRR branch level, however, we request that the responses be consolidated, reviewed and returned at the
~~Assistant Director level.~~
In making judgements about the correctness or adequacy of these technical specifications for Perry you should be guided by the principles of NRR Office Letter No. 38. Deviations from the GE STS should not be proposed or accepted by the staff 3unless they are:
J w Appb.M;- -
!! (1) necessary because of unique design features or unique ,
i organization characteristics, or
.! (2) represent a significant improvement over STS which should d be include'd in the next revision to the STS and do not
~~represent a change in generic requirements wiiTch must be~~
R]
i reviewed prior to implementation by CRGR.
i Deviations from the STS which have merit but are generic and require CRGR t i review should not be proposed at this time for Perry. Instead they should lN be processed thru CRGR as a revision to the STS which can later be applied ia to Perry at the Itcensee's request or as a backfit by the staff. Those i
generic changes involving an imediate safety concern should, however, not be delayed for CRGR review. Any such cases should be highlighted for expedited action by DL and other appropriate NRC Divisions.
Mr. Stewart Brown, of TSRG will be available during the proof and review period to answer any questions which arise. He is located in Room 518, i
Phillips, and his telephone extension is 49-27461.
'l L ..
I e *
- 2- April 8.1985 i
I f
1 Even if you have no connents and are in agreement with the technical specifications content in your area of review, it is requested that a written response to that effect identifying those sections of the technical specifications reviewed be provided by the above specified date.
M Dennis M. Crutchf e g y, ss.s ant Director for Safety Assessme Division of Licensing
~~Enclosure:~~
Perry Nuclear Power Plant, Unit 1 Technical Specifications cc: w/o enclosure -
H. Thompson
, T. Speis J. Knight R. Bernero W. Russell D. Crutchfield T. Novak G. Lainas F. Schroeder F. Rowsome W. Johnston R. Houston .
L. Rubenstein D. Muller j
4 4
e cl a
s .
e i
- - - . . - - - , , - - . , , - ---n. _ _ . - . . , , , , . , _ . . _, - ,--., . _ . . _ , , _ , , , , _ - ,n _ ,, ,,,,,,. -- . - , , -n -- - - -- - - ., -~n-, --
F 1 ,, *
~~i Proof & Review Distribution d* '~~
for Perry - Unit 1 Date: April 8. 1985 l
)
ATTACHED LIST
,! B. Joe Youngblood, Chief Olan D. Parr, Chief Licensing Branch No. 1 , DL Auxiliary Systems Branch, DSI d Gary Holahan, Chief William P. Gamill, Chief d Operating Reactors Assessment Meteorology and Effluent Branch, DL Treatment Branch, DSI
, B. D. Liaw, Chief Lewis G. Hulman, Chief j Materials Engineering Branch, DE Accident Evaluation Branch, DSI i Victor Benaroya, Chief Frank Congel, Chief i .
Equipment Qualification Branch, DE Radiological Assessment Branch, DSI l
Vincent Noonan, Chief Voss A. Moore, Jr., Chief "I Equipment Qualification Branch', DE Human Factors Engineering
~~j Branch, DHFS~~
! Robert E. Jackson, Chief Dennis Ziemann, Chief i
Geosciences Branch, DE Procedures & Systems Review 1 Branch, DHFS
+
George Lear, Chief James G. Keppler Structural & Geotechnical Regional Administrator
! Engineering Branch, DE Region III
Ronald L. Ballard, Chief Jack Grobe l Environmental & Hydrolo ic Senior Resident Inspector *
~~Engineering Branch, D Region III -~~
~~j William H. Regan, Chief R.,\ Olo oh ** LO '~~
~~Site Analysis Branch, DE .~~
,j .
/jt Brian W. Sheron, Chief Reactor Systems Branch, DSI e
, Faust Rosa, Chief G. Ted Ankrum, Chief 1,; Instrumentation & Control Quality Assurance Branch, IAE Lj Systems Branch, DSI
s 1 Walter R. Butler, Chief John Stefano, Project Manager J Containment Systems Branch, DSI Licensing Branch No. 1, DL 1 M. I. Srinivasan, Chief
~~Applicant: (3)~~
'i Power Systems Branch, DS!
Carl Berlinger, Chief
! Core Performance Branch, DSI I
i t
6_ - _ ... . r _ . . _ _ . . . . . . . . _ . . . - . . .

ML20128D361

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