Text

Proposed Tech Specs 3/4.3.1 Re Reactor Protection Sys instrumentation,3/4.3.2 Re Isolation Actuation Instrumentation & 3/4.3.3 Re Emergency Core Cooling Sys Actuation Instrumentation
	ML20135E810
Person / Time
Site:	Hope Creek
Issue date:	03/03/1997
From:	; Public Service Enterprise Group
To:	;
Shared Package
ML20135E807	List: ML20135E804; ML20135E810;
References
	LCR-H97-01, LCR-H97-1, LR-N97113, NUDOCS 9703100225
	Download: ML20135E810 (16)
	v • d • e

- _ _ _ _. _.

Documont Control Desk LR-N97113 LCR H97-01 HOPE CREEK GENERATING STATION FACILITY OPERATING LICENSE NPF-57 DOCKET NO. 50-354 REVISIONS TO THE TECHNICAL SPECIFICATIONS (TS)

TECHNICAL SPECIFICATION PAGES WITH PROPOSED CIIANGES The following Technical Specifications for Facility Operating i

License No. NPF-57 are affected by this change request:

l Technical Specification Page 4.0.5 3/4 0-2 4.3.1.3 3/4 3-1 4.3.2.3 3/4 3-10 4.3.3.3 3/4 3-32 4.6.1.2.d 3/4 6-4 4.6.1.2.1 3/4 6-4 3.6.1.8 3/4 6-11 3.7.7 3/4 7-21 Bases 3/4.6.1.8 B 3/4 6-3 Bases 3/4.8 B 3/4 8-1 970310022S 970303 ADOCK 05000354 yDR PDR

l APPLICABILITY j

SURVEILLANCE REQUIRENENTS l

4.0.1 Survel11ance Requirements shall be met during the OPERATIONAL CON 0!TIONS

{

or other conditions specified for individual Limiting Conditions for Operation j

unless otherwise stated in an individual Surveillance Requirement.

}

4.0.2 Each Surveillance Requirement shall be performed within its specified l

surveillance interval with a maximum allowable extension not to exceed 25 percent of the specified surveillance interval.

1 4.0.3 Failure to perform a Surveillance Requirement within the allowed surveillance interval, aefined by Specification 4.0.2, shall constitute a failure to meet the OM P. ABILITY requier o d for a Limiting Condition for Operation.

The time limits of the ACTION ro uirements are applicable at the time it is identified that a Surveillance Req >irement has not been performed.

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

completion of the sdrveillance when the allowable outage time limits of the ACTION requir"er'ts are less than 24 ' hours.

Surveillance requirements do not have to be pe-ormed on inoperable equipment.

j 4.0.4 Entry into an OPERATIONAL CONDITION or other specified applicable condi-tion shall not be made unless.the Surveillance Requirement (s) associated with the Limiting Condition for Operation have been performed within the applicable surveillance interval or as otherwise specified.

This provision shall not prevent passage through or to OPERATIONAL CONDITIONS as required to comply with ACTION requirements.

j 4.0.5 Surveillance Requirements for inservice inspection and testing of ASNE i

Code Class 1, 2, & 3 compoaents shall be applicable as follows:

Inservice inspection of ASME Code Class 1, 2, and 3 compone-and a.

inservice testing of ASME Code Class 1, 2, and 3 pumps and as i

shall be performed in accordance with Section XI of the ASA:

ailer and pressure Vessel Code a CFR 50, " " #"^ ** ' *nd applicable Adctnda as required oy 10 except where spe:,1fic written relief has

'l been granted by the Commission pursuant to 10 CFR 50,gSection 50.55a(g) i (6) (i).

I Surveillance intervals specified in Section XI of the ASME Boiler h.

and Pressure Vessel Code and applicable Addenda for the inservice inspection and testing activities required by the ASME Boiler and l

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HOPE CREEK 3/4 0-2 Amendment No. 37 j

APR 3 1990 4

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324 3 !NSTRUME?T*AT!0N 3/4 3 1 REACTOR PROTE***fCft SYSTEM INS *RUMEN*ATION LIMITING CONDITION FOR OPERATION 3.3.1 As a minimum, the reactor protection system instrumentation channels shown in Table 3.3.1 1 shall be OPERABLE.

AFPLICABILITY: As shown in Table 3.3.1 1.

bCTION:

With the number cf OPERABLE channels less than required by the Minimum a.

CPERABLE Channels per Trip System requirement for one trip system, place the inoperable channeus) and/or that trip system in the tripped condi-tion

within twelve hours. The provisions of Specification 3.0.4 are not applicable.

b.

With the number of OPERABLE channels less than required by the Minimum CPERABLE Channels per Trip System requirement for bcth trip systems, place at least one trip system *

in the tripped condition within one hour and take the ACTION required by Table 3.3.1-1.

SURVEILLMICE REQUIREME?frS 4.3.1.1 Each reactor protection system instrumentation channel shall be demonstrated OPERABLE by the performance of the CHA!OiEL CHECK, CHA!QiEL FUNCTIONE TEST and CHANNEI. CRIBRATION operations for the OPERATIONE CONDITIONS and at the f requencies shown in Table 4.3.1.1-1.

4.3.1.2 LOGIC SYSTEM FUICTIONR TESTS and simulated automatic operation of all channels shall be performed at least once per 18 months.

4.3.1.3 The REACIOR PRCrrWCTION SYSTEM RESPONSE TIME of each reactor trt; 3

functional unit shall be demonstrated to be within its limit at least once per 18 months. Neutron detectocs are exempt from response time testing.S Each test shall include at least one channel per trip system such that all channels are tested at least once every at times 18 months where N is the total number of f

redundant channels in a specific reactor trip system.

l 4.3.1.4 The provisions of Specification 4.0.4 are not applicable for entry into OPERATIONAL CONDITICBf 2 or 3 f rom CPERATIONR CONDITION 1 for the Inter-mediate Range Monitors.

An inoperable channel need not be placed in the tripped condition where this would cause the Trip Function to occur. In these cases, the inoperable i

channel shall be restored to OPERABLE status within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months or the ACTION

-cquired by Table 3.3.1-1 for t'at

rip 'unct'-- = hall be taken,

- If more channels are inoperable in one trip system than in the other, place the trip system with more inoperable channels in the tripped condition, except when this would cau.se the Trio Function to occur.

HOPk CREEK 3/4 3-1 Amendm E No.85 l

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INSTRLNEN*ATICN i

i SURVE:LLANCE REQUIREMDCS 4.3.2.1 Each isolation actuation instrumentation channel shall be demonstrated OPERABLE by the performance of the CHANNEL CHECK, CHANNEL FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL

^

CONDITIONS and at the f requencies shown in Table 4.3.2.1-1.

l 1.3.2.2 14GIC SYSTEM FUNCTIONAL TESTS and sinulated automatic operation of all channels shall be performed at least once per 13 lrionths.

4.f. 2.3 The ISOLATION SYSTEM RESPONSE TIME of each isolation trip function shall be demonstrated to be within its limit at least once per 18 months.

Radiation detectors are exempt from response time testing, dEach test shall include at least one channel per trip system such that all channels are tested i

j at least once every N times 18 months, where N is the total nt.mber of 1

redundant channels in a specific isolation trip syste:n.

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HOPE CREEK 3/4 3-10 Amendment No.85 f

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' I N S UU'4D."TATIO N 3/4 3 3 EMERGENCY CORI COOLING SYSTEM ACT'JATION INSTRLHDITATION LIMITING CONDITION FOR OPERATION 3.3.3 The emergency core cooling system s'0CS) actuation i..Jtrumentation channels shown in Table 3.3.3-1 shall be OPERABLE with their trip setpoints j

set consistent with the values shown in the Trip Setpoint column of Table 3.3.3-2.

l APPLICABILITY: As shown in Table 3.3.3 1.

ACTION:

a.

With an ECCS actuation 1.strumentation c' annel trip setpoint less conservative than the value shown in the Allowable Values column of Table 3.3.3-2, declare the channel inoperable until the channel is 4

restored to OPERABLE status with its trip setpoint ad]usted i

consistent with the Trip Setpoint value.

b.

With one or store ECCS actuation instrumentation channels inoperable, take the ACTION required by Table 3.3.3-1.

1 i

SURVEILLANCE REQUIREMDITS 4.3.3.1 Each ECCS actuation instrumentation channel shall,be demonstrated OPFRABLE by the performance of the CH.ANNEL CHECK, CHANNEL' FUNCTIONAL TEST and CHANNEL CALIBRATION operations for the OPERATIONAL CONDITIONS and at the f requencies shown in Table 4.3.3.1-1.

4. 3. 3.2 LOGIC SYSTEM FUNCTIONAL TESTS and simulated automatic operation of all channels shall be performed at least once per is months.

4.3.3.3 The ICCS RESPONSE TIME of each ECCS trip function shall be l

demonstrated to be within the limit at least once per le monthis.vtach test shall include at least one channel per trip system such that all channels are tested at least once every N times 18 months where N is the total number of 4

J redundant channels in a specific ECCS trip system.

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HOPE CREEK 3/4 3-32 Amendment No.85 1

e CONTAlNMENT SYSTEMS l

SURVEILLANCE REQUIREMENTS (Continued) 2.

Has duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.

3.

Requires the quantity of gas injected into the containment or bled from the containment during the supplemental test to be between 0.75 L, and 1.25 L

a 1

The formula to a used is:

[L

+L 0.25 L,] 3 Lc I El * 'am

a am o

0.25 L,] where L a supplement test result; La = superimposed leakage; c

and L, a measured Type A leakage.

4 d.

Type B and C tests shall be conducted with gas at P,, 48.1 psig*,

at intervals no greater than 24 months except for tests involving:

1.

Air locks, 2.

Main steam line isolation valves, 3.

Valves pressuri:ed with fluid from a seal system, 4.

All containment isolation valves in hydrostatically tested lines in Table 3.6.3-1 which penetrate tte primary containment, and i

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Air' locks shall be tested and demontitratt.d OPERABLE per Surveillance i

e.

Requirement 4.6.1.3.

f.

Main. steam line isolation valves shali be leak tested at least once per 18 months.

k g.

Containment isolation valves which form the boundary for the long-term seal of the feedwater lines in Table 3.6.3-1 shall be hydrostati-cally tested at 1.10 P,, 52.9 psig, at least once per 18 months.

h.

All containment isolati:n valves in hydrostatically tested lines in Table 3.6.3-1 which pe wtrate the primary containment shall be leak tested at least once p r 18 months.

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The provisions of Specification 4.0.2 are not applicable t.o Specifications 4.6.1.2.a, 4.6.1.2.b, 4.6.1.2.c, 4.6.1.2.d, and 4.6.1.2.e.

"Unless a hydrostatic test is required per Table 3.6.3-1.

I HOPE CREEK 3/4 6-4 Amendment No. 48

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J CON *AINMENT SYSTEMS

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ORYWELL AND SUPPRESSION CHAMBER PURGE SYSTEM LIMITING CONDITICN FCR OPERATIONS i

a 3.6.1.8 The drywell and suppression chamber purge system, including the 6-inch nitrogen supply line, may be in operation for up to SCO hours each 365 l

days with the supply and exhaust isolation valves in one supply line and one exhaust line open for containment prepurge cleanup, inerting, deinerting, or i

pressure control.*

APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

i With a drywell or suppression chamber purge supply and/or exhcust isolation i

a.

valve and/or the nitrogen supply valve open, except as permitted above, close the valves (s) or otherwise isolate the penetration (s) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HOT SKUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD i

SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

l

b. With a drywell purge supply or exhause isolation valve, or a suppression l

chamber purge supply or exhaust isolat on valve c: ene nitrogen supply

valve, "it' rerilient ::: riel :::1-aving a measured leakage rate e...eeding t..s

_. of Surveillance Requirement 4.6.1.8.2, restore the Inoperable valve (s) to CPERABLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least 24 j

HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

i l

SURVEILLANCE REQUIREMENTS d

4.6.1.9.1 Before being opened, the drywell a.d supptession chamber purge supply and exhaust, and nitrogen supply butte.r 'ly isolation valves shall be verified not to have been open for more than 50C' hours in the previous 365 l

days.*

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)j 4.6.1.8.2 At least once per i -55Ehe *- but n: :::: th n cace ye. ^^

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the 26-inch drywell purge supply and exhaust isolation valves and the 24-inch suppression chamber purge supply and exhaust isolation valves and the 6-inch nitrogen supply valve eith :::ili:nt ::: i:1 :::1: %f.all be demonstrated OPERABLE by verifying that the measured leakage rate is less *.han or equal to j

0.05 La per penetration when pressurized to P 48.1 psig.

a Valves cpen for pressure control are not suhject to the 500 hours0.00579 days 0.139 hours 8.267196e-4 weeks 1.9025e-4 months per 365 l

days limit, provided the 2-inch bypass lir es are being utilized.

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Pre"ided *k-t the vale: h:c et be: Operated ein : the previeu te:.

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l HOPE CREEK 3/4 6-11 Amendment N,o 84;ig, l

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LIMITING CONDITION FOR OPERATION

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I 3.7.7 The main turbine bypass system sh 11 be OPERABLE.

APPLICABILITY:

OPERATIONAL CONDITION ACTION: With the main turbine bypass system inoperable, restore the system to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to less than or equal to 25% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

SURVEILLANCE REQUIREMENTS 4.7.7 The main turbine bypass system shall be demonstrated OPERABLE at least once per:

a.

31 days by cycling each turbine bypass valve through at least one complete cycle of full travel, and b.

18 months by:

1.

Performing a system functional test which includes simulated automatic actuation and verifying that each automatic valve actuates to its correct position.

2.

Demonstrating TURBINE BYPASS SYSTEM RESPONSE TIME meets the following requirements when measured from the initial movement of the main turbine stop or control valve:

a) 80% of turbine bypass system capacity shall be established in less than or equal to 0.3 second.

b)

Bypass valve opening shall start in less than or equal to 0.1 second.

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CONTAINMENT SYSTEMS BASES ORWELL AND SUPPRESSION CHAM 9ER PURGE SYSTEM (Continued)

The use of the.drywell and suppression chamber purge exhaust lines for i

I provided 1) only the inboard purge exhaust isolation valves ex.,4ust isolation valves remain closed.the vent valves on the 2-inch vent pa the vent valves will sufficiently choke the flow and additionally the appl i

cable valves will close in a timely manner during a LOCA or steam line breat accident and therefore the control room and the site boundary dose guidelines of applicable 10 CFR dose limits will not be exceeded in the event of an acci-

[

dent.

The design of the purge supply and exhaust isolation valves and the 6

6-inch nitrogen supply valve meets the requirements of 8 ranch Technic.a1 Posi-t t

tion C58 6-4, " Containment Purging During Norsal Plant Operations".

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. The 0.60 L leakage limit shall not be exceeded when I

the leakage rates determined by the l$akage integrity tests of these valves i

are added to the previously determined total for all valves and penetrations subject to Type 8 and C tests.

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3/4.6.2.

DEPRESSURIZATION SYSTEMS i

The specifications of this section ensure that the primary containment i

pressure will not exceed the design pressure of 62 psig during primary system blowdown free full operating pressure.

The suppression chamber water provides the heat sink for the reactor coolant systes energy release following a postulated rupture of the system.

8 i

The suppression chamber water volume sust absorb the associated decay and j

structural sensible heat released during reactor coolant system blowdown free j

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1020 psig.

Since all ef the gases in the drywell are purged into the suppression chamber air space during a loss of coolant accident, the pressure j

of the liquid must not exceed 62 psig, the stepression chamber anximum internal design pressure. The design volme of the stspression chamber, water and air, 3

was obtained by considering that the total volume of reactor coolant to be considered is discharged to the suppression chamber and that the drywell volume j

is purged'to the suppression chamber.

i Using the minimum or maximum water volumes given in this specification, i

containment pressure during the design basis accident is approximately 48.1 psig i

whi:h is below the design pressure of 62 psig. Maxion water volume of 122,000 fta results in a downconer submergence of 3.33 ft and the minimum volume i

of 118,000 fts results in a submergence of approximately 3.0 ft. The majority of the Sodega tests were run with a senerged length of four feet and with completa condensation. Thus, with respect to the downcomer submergence, this i

specification is adequate. The maximum temperature at the end of the blowdown

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i HOPE CRIEK B 3/4 6-3 Amerstment No.16 o

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3/4 s ELECTRICAL PCWYR SYSTEMS j

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1 sASES l'4 8.1 3/4 8.2 and 3/4 0 3A0 SOUR ES. D7 SC07CES and CNSIT1 POWER i

DISTRIntf! ION SYSTEMS

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The OPERASILITY of the A.C. and D.C.

power sources and associated distributton systema during operatton ensures that suffletent power will be i

available to supply the safety related equipment required for (1) the safe shutdown of the facility and (2) the mitigation and control of acetdent

endations within the facility. The minimum specified independent and j

redundant A.C. and D.C. power sources and distributton systems satisfy the l

requirements of General Design Criteria 17 of Appendix "A"

to 10 CTR 50.

The ACTION requirement's specified for the levels of degrad4 tion of the 4

j power sources provide restriction upon continued facility operatton J

commensurate with the level of degradation. The CPERASILITY of the power i

sources are constatent with the initial condition assumptions of the safety analyses and are based upon maintaining at least one of the onatte A.C. and

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the corresponding D.C. power sources and associated distribution systems OPERABLE during accident conditions coincident with an assumed loss of of f atte power and single f ailure of the other onsite A.C. or D.C. source.

The A.C. and D.C. source allowable out-of service times are based on Regulatory Guide 1.93, aAvailahtitty of Electrical Power Sources *, December l

1974 as modified by plant specific analysis and diesel generator manufacturer j

recommendations. When two diesel generators are inoperable, there is an additional ACTION requirement to verify that all required systems,

)

susbeystems, trains, components and devices, that depend on the remaining i

OPERABLE diesel ger.erators as a source of emergency power, are also CPERABLE.

This requirement *s intended to provide assurance that a loss of offsite power 1

event will not reault in a complete loss of safety function of critical l

systema during tha period two or more of the diesel generators are inoperable.

The term verify as used in this context means to administratively check by j

exmining logo or other information to determine if certain components are bDD out-of-service for maintenance or other reasons. It does not mean to perform i

l eM'T the surveillance requirements needed to...uonstrate the OPERABILITY of the g

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The OPERASILITY of the minimum specified A.C. and D.C. power sources and associated distribution systema during shutdown and refueling ensures that (1) l the f acility can be maintained in the shutdown or refueling condition for extended time periods ant (2) sufficient instrumentation and control capability is available for monitoring and maintaining the unit status.

t The surveillance requirements for de-..strating the OPERABILITY of the diesel generators are in accordance with the recommendations of Regulatory I

Guide 1.9.

" Selection of Diesel Generator Set Capacity for Standby Dower Supplies", March 10, 1971, Regulatory Guide 1.108, " Periodic Testing of Diesel l

Generator Units Used as Onsite Electric Power Systema at Nuclear Power Plants", Revision 1. August 1977 and Regulatory Guide 1.137' Puel-011 Systems 4

for Standby Diesel Generators *, Revision 1 October 1979 as modified by plant specific analysts, diesel generator manufacturer's recommendations, and f

Amendment 59, to the Facility operating License, issued November 22, 1993.

HOPE CREEK B 3/4 8-1 Amendment No.75.79 l

d 1

1 I

i 4

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CCNTAINHENT Sr5TEMS SURVEILLANCE REQUIREMENTS (Continuec) 2.

Has duration sufficient to establish accurately the change in leakage rate between the Type A test and the supplemental test.

3.

Requires the quantity of gas injected into the containment or bled from the containment during the supplemental test to be between 0.75 L, and 1.25 L -

a The formula to :.: used is:

[L, + L,, - 0.25 L,) $ Lc I El * 'am

o 0.25 L ] where Lc = supplement test result; La = superimposed leakage; a

and L, s measured Type A leakage.

d.

Type B and C tests shall be conducted with gas at P,, 48.1 psig*,

at intervals no greater than 24 months except for tests involv.ing:

1.

Air locks, 2.

Main steam line isolation valves, 3.

Valves pressuri:ed with fluid from a seal system, 4.

All containment isolation valves in hydrostatically tested lines in Table 3.6.3-1 which penetrate the primary containment, and 5.

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Va.\\e4/h.

Air' locks shall be tested and demonstrated OPERABLE per Surveillance e.

Requirement 4.6.1.3.

f.

Main. steam line isolation valves shall be leak tested at least once per 18 months.

g.

Containment isolation valves which form the boundary for the long-term seal of the feedwater lines in Table 3.6.3-1 shall be hydrostati-cally tested at 1.10 P, 52.9 psig, at least once per 18 months.

a h.

All containment isolati:n valves in hydrostatically tested lines in Table 3.6.3-1 which pentrate the primary containment shall be leak tested at least once pc 18 months.

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The provisions of Specification 4.0.2 are not applicable to Specifications 4.6.1.2.a. 4.6.1.2.b, 4.6.1.2.c, 4.6.1.2.d. and 4.6.1.2.e.

^Unless a hydrostatic test is required per u.. ele 3.6.3-1.

I HOPE CREEK 3/4 6-4 Amendment No. 48

)

8.*.

l CONTAINMENT SYSTEMS PYWELL AND SUPPRESSION CMA."BER PURGE SYSTEM 4

LIMITING CONDITION FOR OPERATIONS 3.6.1.8 The drywell and suppression chamber purge system, including the 6-inch nitrogen supply line, may be in operation for up to 500 hours0.00579 days 0.139 hours 8.267196e-4 weeks 1.9025e-4 months each 365 l

days with the supply and exhaust isolation valves in one supply line and one l

exhaust line open for containment prepurge cleanup, inerting, deinerting, or

]

pressure control.'

i APPLICABILITY:

OPERATIONAL CONDITIONS 1, 2 and 3.

5 ACTION:

a. With a drywell or suppression chamber purge supply and/or exhaust isolation i

valve and/or the nitrogen supply valve open, except as permitted above, close the valves (s) or otherwise isolate the penetration (s) within 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months or be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4 l

I

b. With a drywell purge supply or exhaust isolation valve, or a suppression chamber purge supply or exhaust isolat ~ on valve or the nitrogen supply

valve, ith recilient meter;:1 :

aving a measured leakage rate e...eeding t...

.... of Surveillance Requirement 4.6.1.8.2, restore the j

inoperable valve (s) to OPERASLE status within 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months or be in at least og.

HOT SHUTDOWN within the next 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

4 f

SURVEILLANCE REQUIREMENTS J

4.6.1.8.1 Before being opened, the drywell and suppression chamber purge supply and exhaust, and nitrogen supply butterfly isolation valves shall be verified not to have been open for more than 500 hours0.00579 days 0.139 hours 8.267196e-4 weeks 1.9025e-4 months in the previous 365 l

'2.j nc % s Y

4.6.1.8.2 At least once per Y -55$he-, but n: :::: :han once pos ^2 u f.-

the 26-inch drywell purge supply and exhaust isolation valves and the 24-inch suppression chamber purge supply and exhaust isolation valves and the 6-inch nitrogen supply valve citt r;;ili:nt m :; rial ::al: Thall be demonstrated OPERASLE by verifying that the measured leakage rate is less than or equal to 0,05 La per penetration when pressurized to P 48.1 psig.

a Valves Open for pressure control are not subject to the Soc hours per 365 l

days limit. provided the 2,-inch bypass lines are being utilizad.

S' Pre"ided that the "21v: h:

_c t 5::7 eper:ted cine: the pre"icue-tect.

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Amendment No.84,,

l HOPE CREEK 3/4,6-11

,4

,n PLANT SYSTEMS When TMeM. Pow C(l. \\s N' "

3/4.7.7 MAIN TURiilNE BYPASS SYSTEM 2 6 Yo oC C6TED THOCDAL 6 wctt i

LIMITING CONDITION FOR OPERATION-3.7.7 The main turbine bypass system sh 11 be OPERABLE.

APPLICABILITY:

OPERATIONAL CONDITION ACTION: With the main turbine bypass system inoperable, restore the system to OPERABLE status within 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months or reduce THERMAL POWER to less than or equal to 25% of RATED THERMAL POWER within the next 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

SURVEILLANCE REQUIREMENTS 4.7.7 The main turbine bypass system shall be demonstrated OPERABLE at least once per:

a.

31 days by cycling each turbine bypass valve through at least one complete cycle of full travel, and b.

78 months by:

1.

Performing a system functional test which includes simulated automatic actuation and verifying that each automatic valve actuates to its correct position.

2.

Demonstrating TURBINE BYPASS SYSTEM RESPONSE TIME meets the following requirements when measured from tne initial movement of the main turbine stop or control valve:

a) 80% of turbine bypass system capacity shall be established in less than or equal to 0.3 second.

b)

Bypass valve opening shall start in less than or equal to 0.1 second.

4 e

7' HOPE CREEK 3/4 7-21

I' 5

CONTAINMENT SYSTEMS

. BASES i

i j

DRWELL AND SUPPRES$10N CHAM 8ER PURGE SYSTEM (Co The use of the.drywell and suppression chamber purge exhaust lines for

(

provided 1) only the inboard purge exhaust isolation va I

i the vent valves on the 2-inch vent paths are used and 2) the outboard pur ex.4ust isolation valves remain closed.

the vent valves will sufficiently choke the flow and additionally the ap cable valves will close in a timely manner during a LOCA or steam line breat accident and therefore the control room and the site boundary dose guidelines t

of applicable 10 CFR dose limits will not be exceeded in the event of an acci-j i

dent.

The design of the purge supply and exhaust isolation valves and the i

6-inch nitrogen supply valve meets the requirements of Branch Technica1 Post-tion CS8 6-4, " Containment Purging During Norsal Plant Operations",.

t :k ;; iat: grit supply :nd ::h:;;t i:.y4::t: with :.=i r :11 2 1: 1::b;; r:t: f:r ;u--

hti v:!v:: 111 ; :vid: :;rly indi::ti:n :f 7;;i1I::n; 8

ri:1 :::1 d;;r:d:ti:n 3

-knese f:i-1we-dev:1:;;.gnd vill :11= th: :;;;rtunity-f:7 r;;:tr 5:fer: gre:: ?

The 0.60 t theleakageratesdeterminedbythellakagefntegritytestsofthesevalveslea i

]

are added to the previously determined total for all valves and penetrations j

subject to Type 8 and C tests.

j 3/4.6.2.

DEPRESSURIZATION SYSTEMS The specifications of this section ensure that the primary containment 3

blowdown free full operating pressure. pressure will not exceed the design 1

The suppression chamber water provides the heat sink for the reactor The suppression chamber water volume must absorb the

{

structural sensible heat released during reactor coolant systes blowdown fros 1020 psig.

Since all of the gases in the drywell are purged into the suppression chamber air space during a loss of cociant accident, the pressure

{

of the liquid must not exceed 62 psig, the suppression chamber maximum internal i

design pressure.

The design voltme of the suppression chamber, water and air, i

was obtained by considering that the total voltme of reactor coolant to be j

considered is discharged to the suppression chamber and that the drywell volume is purged to the suppression chamber.

j 1

1 Using the sinimum er maximum water voltmes given in this specification, I

containment pressure during the design basis accident is approximately 44.1 psig which is below the design pressure of 52 psig.

{

Maximum water volume of 122,000 fta results in a downconer submergence of 3.33 ft and the minieue volume

{

of 118,000 fts results in a submergence of approximately 3.0 ft.

of the Bodega tests were run with a submerged length of four feet and withThe majority completa concensation.

}

specification is adequate.Thus, with respect to the downconer submergence, this The maximum tasperature at the end of the blowdown

]

HOPE CREEK B 3/4 6-3 Amendment No.16 i

l 1

1 l

e

._m_.

1.*

3/ 4 e E '_E C'""P I TAL PcwrR SYS~ EMS 4

4 l

aAsES

,3/4 a1 3/4 8.2 and 3/4 9 3 A0 5 0'. A TE S. O?

SC',~ ACES and ONS !"1 PCVER D I S *R I B t.** ION S YSTEMS The OPERASILITY of the A.C. and D.C.

power sources and associated distributton systems during operatton_ ensures that sufficient power will be available to supply'the safety related equipment required for (1) the safe shutdown of the factlity and (2) che mitigation and control of accident

]

enditions within the f acility. The taintmum specified independent and redundant A.C. and D.C. power sources and distribution systems sattsfy the requirements of General Design criteria 17 of Appendix *A*

to 10 CTR $0.

The ACTION requirement's specified for the levels of degradation of the 3

power sources provide restriction upon continued factitty operation i

comensurate with the level of degradation. The OPERABILITY of the power l

sources are consistent with the initial condition assumptions of the safety analyses and_are based upon maintaining at least one of the onette A.C. and the corresponding D.C. power sources and associated distribution systems CPERABLE during accident conditions coincident with an assumed loss of offstte power and single failure of the other onsite A.C. or D.C. source.

1 The A.C. and D.C. source allowable out-of service times are based on l

Regulatory Guide 1.93, " Availability of Electrical Power Sources *, December I

1974 as modified by plant specific analysis and diesel generator manufacturer recomendations. When two diesel generators are inoperable, there is an j

additional ACTION requirement to verify that all required systems, susheystems, trains, components and devices, that depend on 'the remaining CPERABLE diesel generators as a source of emergency power, are also CPERABLE.

This requirement is intended to provide assurance that a loss of offsite power event will not. result in a complete loss of safety function of critical systems during the period two or more of the diesel generators are inoperable, j

The term verify as used in this context means to administratively check by exmining logo or other infornation to determine if certain components are j

bDI) out of service for mainte.ance or other reasons. It does not mean to perform MMM the surveillance requiteeents needed to...uonstrate the OPERASILITY of the N

Q component.

The-p-ic

/ in:::: ;f : M ex;er.ded = ie t h ; c 6 6.eded r,G '

g N

'.CT f;e; ? Nuse se l'. 4-ye a i 6 n..d.a Lw v sswam y..y i.smus g

aw maintenancuuch te t"*C---

--f

'ifi::ti;n: :h ; w.uld e;M s.;aee extend f

W y:nd th: ::igi 1 ?2 6.- "' 's The OPERABILITY of the minimum 'specified A.C. and D.C. power sources and l

associated distribution systems during shutdown and refueling ensures that (U the facility can be maintained in the shutdown or refueling condition for extended time periods and (2) sufficient instrumentaticn and control capability is available for monitoring and maincatning the unit status.

The surveillance requirements for de-..stratino the OPERABILITY of the i

diesel generators are in accordance with the recomendations of Regulatory Guide 1.9. " Selection of Die'sel Generator Set Capacity for Standby power j

Supplies", March 10, 1971, Regulatory Guide 1.100, " Periodic Testing of Diesel Generator Units Used as onsite Electric Power Systems at Nuclear Power j

Plants", Revision 1 August 1977 and Regulatory Guide 1.137" Fuel.011 Systems for Standby Diesel Generators *, Revision 1. October 1979 as modified by plant I

i specific analysts, diesel generator manuf acturer's recomendations, and f,

j Amendment 59, to the Facility operating Ltcense, issued November 22, 1993.

HOPE CREEK B 3/4 81 Amendment No.73,,*9 l

i 4

.i

1 1

o INSER.T The 14 day AOT for the "C" and "D" EDGs is based upon the following conditions being met:

1.

Hope Creek should verify through Technical Specifications, procedures or detailed analyses that the systems, subsystems, trains, components and devices that are required to mitigate the consequences of an accident are available and operable before removing an EDG for extended preventative maintenance (PM).

In addition, positive measures should be provided to preclude subsequent testing or maintenance activities on these systems, subsystems, trains, components and devices while the EDG is inoperable.

2.

The overall unavailability of the EDG should not exceed the performance criteria developed for implementation of 10CFR50.65 requirements as described in NUMARC 93-01, " Industry Guideline for Monitoring the Effectiveness of Maintenance at Nuclear Power Plants", as endorsed by Regulatory Guide 1.160, " Monitoring the Effectiveness of Maintenance at Nuclear Power Plants", June 1993.

3.

When the "C" or "D" EDG is removed from service for an extended 14 day AOT, any two of the remaining EDGs must be capable, operable and available to mitigate the consequences of a LOOP condition.

4.

The removal from service of safety systems and important non-safety equipment, including offsite power sources, should be minimized during the extended 14 day AOT.

5.

Entry into this LCO should not be abused by repeated voluntary entry into and exit from the LCO.

The primary intent of the extended EDG AOT is that the extended EDG AOT from 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months to 14 days may be needed to perform preplanned EDG maintenance such as teardowns and modifications that would otherwise extend beyond the original 72 hour8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months AOT.

6.

Any component testing or maintenance that increases the likelihood of a plant transient should be avoided.

Plant operation should be stable during the extended 14 day AOT.

7 Voluntary entry into this LCO action statement should not be scheduled if adverse weather conditions are expected.

ML20135E810

Text

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