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Amend 4 to License NPF-57,granting Relief from ASME Boiler & Pressure Vessel Code,Section XI Re Valve Leakage Test Requirement & Extends Surveillance Intervals for 27 RCS Pressure Isolation & Primary Containment Isolation Valves
	ML20234C422
Person / Time
Site:	Hope Creek
Issue date:	06/09/1987
From:	Butler W; Office of Nuclear Reactor Regulation
To:	;
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ML20234C425	List: ML20234C422;
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	NUDOCS 8707060463
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UNITED STATES j

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NUCLEAR REGULATORY COMMISSION n

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WASHING TON, D. C. 20555

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i PUBLIC SERVICE ELECTRIC & GAS COMPANY j

1 ATLANTIC CITY ELECTRIC COMPANY DOCKET NO. 50-354 HOPE CREEK GENEPATING STATION AMENDMENT TO FACILITY OPERATING LICENSE Amendment No. 4 License No. NPF-57 i

1.

The Nuclear Regulatory Commission (the Commission or the NRC) has found that:

A.

The application for amendment filed by the Public Service Electric &

Gas Company (PSE&G) dated April 3, 1987, as supplemented May 8, 1987, I

complies with the standards and requirements of the Atomic Energy

)

Act of 1954, as amended (the Act), and the Comission's rules and i

regulations set forth in 10 CFR Chapter I; i

B.

The facility will operate in conformity with the application, the l

provisions of the Act, and the rules and regulations of the Comission; i

C.

There is reasonable assurance: (1) that the activities authorized by this amendment can be conducted without endangering the health and safety of the public, and (ii) that such activities will be conducted in compliance with the Comission's regulations set forth in 10 CFR

)

Chapter I; D.

The issuance of this amendment will not be inimical to the common defense and security or to the health and safety of the public; and E.

The issuance of this amendment is in accordance with 10 CFR Part 51 of the Comission's regulations and all applicable requirements have been satisfied.

2.

Accordingly, the license is amended by changes to the Technical Specifica-tions as indicated in the attachment to this license amendment, and paragraph 2.C.(2) of Facility Operating License No NPF-57 is hereby amended to read as follcws:

(2) Technical Specifications and Environmental Protection Plan The Technical Specifications contained in Appendix A as revised through Amendment No. 4, and the Environmental Protection Plan contained in Appendix B, are hereby incorporated in the license.

PSE&G shall operate e

the facility in accordance with the Technical Specifications and the t

i Environmental Protection Plan, j

8707060463 870609 PDR ADOCK 05000354 P

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- i 3.

This license amendment is effective as of its date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION

/s/

Walter R. Butler, Director Project Directorate I-2 Division of Reactor Projects I/II

Attachment:

Changes to the Technical J

Specifications Date of Issuance: June 9, 1987 I

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, 3.

This license amendment is effective as of its date of issuance.

FOR THE NUCLEAR REGULATORY COMMISSION Walter R. Butler, Director Proiect Directorate I-2 Division of Reactor Pro,iects I/II

Attachment:

Changes to the Technical Specifications.

Date of Issuance: June 9, 1987 o

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ATTACHMENT TO LICENSE AMENDMENT NO. 4 FACILITY OPERATING LICENSE NO. NPF-57 DOCKET NO. 50-354 Replace the following pages of the Appendix "A" Technical Specifications with the attached pages. The revised pages are identified by Amendment number and contain vertical lines indicating the area of change.

Overleaf pages are provided to maintain document completeness.

Remove Insert 3/4 4-11 3/44-11(overleaf) 3/4 4-12 3/4 4-12 3/4 6-3 3/4 6-3 (overleaf) 3/4 6-4 3/4 6-4 t

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REACTOR COOLANT SYSTEM OPERATIONAL LEAKAGE-LIMITING CONDITION FOR OPERATION 3.4.3.2 Reactor coolant system leakage shall be limited to:

a.

No PRESSURE BOUNDARY LEAKAGE.

b.

5 gpm UNIDENTIFIED LEAKAGE.

c.

25 gpm IDENTIFIED LEAKAGE averaged over any 24-hour period.

d.

0.5 gpm leakage per nominal inch of valve. size up to a maximum of 5 gpm from any reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1, at rated pressure.

APPLICABILITY: OPERATIONAL CONDITIONS 1, 2 and 3.

ACTION:

a.

With any PRESSURE BOUNDARY LEAKAGE, be in at least HOT SHUTDOWN within 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months and in COLD SHUTDOWN within the next 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months , b.

With any reactor coolant system leakage greater than the limits in b and/or c, above, reduce the leakage rate to within the limits 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 .

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 one other closed manual or deactivated automatic or check

valves, 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 .

d.

With one or more of the high/ low pressure interface valve leakage pressure monitors shown in Table 3.4.3.2-2 inoperable, restore the inoperable monitor (s) to OPERABLE status within 7 days or verify the pressure to be less than the alarm setpoint at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ; restore the inoperable monitor (s) to OPERABLE status within 30 days or be in at least HOT SHUTOOWN 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 .

Which have been verified not to exceed the allowable leakage limit at the last refueling outage or the after last time the valve was disturbed, whichever is more recent.

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HOPE CREEK 3/4 4-11 i

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4 REACTOR COOLANT SYSTEM SURVEILLANCE REQUIREMENTS 4.4.3.2.1.The reactor coolant system leakage shall be demonstrated to be within each of the above limits by:

t Mohitoring the drywell atmospheric gaseous radioactivity at least a.

once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (not a means of quantifying leakage),

b.

Monitoring the drywell floor and equipment drain sump flow rate at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and c.

Monitoring the drywell air coolers condensate flow rate at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months , and d.

Monitoring the drywell pressure at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months (not a means of quantifying leakage), and Monitoring the reactor vessel head flange leak detection system at e.

least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (not a means of quantifying leakage), and f.

Monitoring the drywell temperature at least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months (not a

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means of quantifying leakage).

4.4.3.2.2 Each reactor coolant system pressure isolation valve specified in Table 3.4.3.2-1 shall be demonstrated OPERABLE by leak testing pursuant to Specification 4.0.5 and verifying _the leakage of each valve to be within the specified limit:

a.

At least once per 18 months,** and b.

Prior to returning the valve to service following maintenance, repair or replacement work on the valve which could affect its leakage rate.

The previsions of Specification 4.0.4 are not applicable for entry into OPERAT100.! CONDITION 3.

l 4.4.3.2.3 The high/ low pressure interface valve leakage pressure monitors shall be demonstrated OPERABLE with alarm setpoints per Table 3.4.3.2-2 by performance of a:

CHANNEL FUNCTIONAL TEST at least once per 31 days, and a.

b.

CHANNEL CALIBRATION at least once per 18 months.

" P.I.V. leak test extension to the first refueling outage is permissible for each RCS P.I.V. listed in Table 3.4.3.2-1, that is identified in Public Ser-vice Electric & Gas Company's letter to the NRC (letter No. NLR-N87047),

dated April 3, 1987, as needing a plant outage to test.

For this one time test interval, the requirements of Section 4.0.2 are not applicable.

HOPE CREEK 3/4 4-12 Amendment No. 4 I

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CONTAINMENT SYSTEMS LIMITING CONDITION FOR OPERATION (Continued)

ACTION (Continued) b.

The combined leakage rate for all penetrations and all valves listed in Table 3.6.3-1, except for main steam line isolation valves *, valves-which form the boundary for the long-term seal of the feedwater lines, and l

other valves which are hydrostatically tested per Table 3.6.3-1, subject 1

to Type B and C tests to less than or equal to 0.60 L,, and

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c.

The leakage rate to less than or equal to 46.0 scfh combined through all four main steam lines, and d.

The combined leakage rate for all containment isolation valves which form the boundary for the long-term seal of the feedwater lines in Table 3.6.3-1 to less than or equal to 10 gpm, and e.

The combined leakage rate for all other containment isolation valves in I

hydrostatically tested lines in Table 3.6.3-1 which penetrate the primary containment to less than or equal to 10 gpm, prior to increasing reactor coolant system temperature above 200 F.

SURVEILLANCE REQUIREMENTS

4. 6.1. 2 The primary containment leakage rates shall be demonstrated at the following test schedule and shall be determined in conformance with the criteria specified in Appendix J of 10 CFR 50 using the methods and provisions of ANSI N45.4 - 1972:

Three Type A Overall Integrated Containment Leakage Rate tests shall a.

be conducted at 40 1 10 month intervals during shutdown at P,,

48.1 psig, during each 10 year service period.

The third test of each set shall be conducted during the shutdown for the 10 year plant inservice inspection.

j If any periodic Type A test fails to meet 0.75 L,, the test schedule b.

for subsequent Type A tests shall be reviewed and approved by the Commission.

If two consecutive Type A tests fail to meet 0.75 L,,

a Type A test shall be performed at least every 18 months until two consecutive Type A tests meet 0.75 L,, at which time the above test schedule may be resumed.

c.

The accuracy of each Type A test shall be verified by a supplemental i

test which:

.1.

Confirms the accuracy of the test by verifying that the difference between the supplemental data and the Type A test data is within 0.25 L,.

2.

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

3.

Require's 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,.

Exemption to Appendix "J" of 10 CFR 50.

HOPE CREEK 3/4 6-3 li

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<1 CONTAINMENT SYSTEMS SURVEILLANCE REQUIREMENTS (Continued)

The formula to be used is:

[L

+L

- 0.25 L,] $ Lc 5 El

L

+

o am o

am 0.25 L ] where L s supplement test result; L a superimposed leakage; a

c g

and L s measured Type A leakage, a

d.

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

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

l 1.

Air locks, 2.

Main steam line isolation valves, 3.

Valves pressurized 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.

Purge supply and exhaust isolation valves with resilient material seals.

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

Requi rement 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 isolation valves in hydrostatically tested lines in Table 3.6.3-1 which penetrate the primary containment shall be leak tested at least once per 18 months.

i.

Purge supply and exhaust isolation valves with resilient material seals shall be tested and demonstrated OPERABLE per Surveillance Requirements 4.6.1.8.2 and 4.6.1.8.3.

j.

The provisions of Specification 4.0.2 are not applicable to Speci fi cati ons 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.

RUnless a hydrostatic test is required per Table 3.6.3-1.

00A Type C test interval extension to the first refueling outage is permissible for primary containment isolation valves listed in Table 3.6.3-1, which are identified in Public Service Electric & Gas Company's letter to the NRC (letter No. NLR-N87047), dated April 3, 1987, as needing a plant outage to test.

For this one time test interval, the requirements of Section 4.0.2 are not applicable.

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

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ML20234C422

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