ML18093B431

LER 89-001-00:on 890104,Tech Spec 3.0.3 Entered Due to Inoperability of Three Groups of Containment Fan Coil Units. Caused by Equipment Problems.Blind Flange Installed on Stated HX 12A Svc Water Inlet piping.W/880201 Ltr

ML18093B431
Person / Time
Site:	Salem
Issue date:	02/01/1989
From:	Miller L, Pollack M Public Service Enterprise Group
To:	NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
LER-89-001-01, LER-89-1-1, NUDOCS 8902090477
Download: ML18093B431 (5)

Text

NRC Form - U.I. NUCLEAR llEGULATO!'h' *'.:*. *:a111SION

!!Hill Al'PROV EO OMI NCI. :lo;~{,.° 11 J' EXPIRES: 8/31185 LICENSEE EVENT REPORT lLER)

FACILITY NAME (1) DOCKET NUMaER (2) I r,...., (31 Salem Generating station - Unit 1

• o 1s 10101c1217 i2 , loF 01 4 TITLE l*l.

Tech. Spec. 3.0.3 Entry; 3 Groups of CFCUs Inoperable Due To Equipment Problems EVENT DATE (8) LER NUMBER (8) REPORT DATE (7) OTHER FACILITIES INVOLVED (I)

MONTH QAY YEAFi YEAR tt SE~~~~~~AL ft ~5~~~ MONTH DAY YEAR FACILITY NAMES DOCKET NUMBER!Sr 01s1010101 I I o I 1 o 14 s 9 s i9 - o I o I1 - oI o o t2 oI1 s I9 01S1010101 I I OPERATING THll.REPORT 11 IUBMITTED PURIUANT TO THE REQUIREMENTI OF 10 CFR §: (Ch<<k OM or more of 1111 followln11I 1111

• t---MOO-E-.1-ll_........L.l-+~ 20,'°2(bl I - 20.408Ccl ___. ll0.731alC21CIYl

- 73.71Cbl POWER L~~~L 1 p I0 -

20.'°8C*IC1lCU.

20.'°8C*H1Hlll -

--I ll0.38Ccll1 l ll0.38Ccll2l *--

80.731all21Cvl 80.73(a)(21Cwlll -- 73.711*1 OTHER (Sf*lfy In Ablf>'Kt

/>>low *ntl In T1xr, NRC Form ll0.73(o)(2)Cll 80.731alC21CwllllCAl 366AI

--- ll0.73Coll21Clll ll0.73(a)(2)(111)

LICENSEE CONTACT FOR THIS LER (121 ll0.73C*IC2H*lllllll ll0.73C*ll2Hxl NAME' TELEPHONE NUMBER AREA CODE M. J. Pollack - LER Coordinator 6 1 0 19 3 1 3 19 1- I 4 IO I 2 1 2 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DEICRllED IN THll REPORT 1131 CAUSE SYSTEM COMPONENT MANUFAC* MANUFAC:.

TUR ER SYSTEM COMPONENT TUR ER I I I I I I I I I I I I I I I I I I I I I I I I .I I I I IUPPLEMENTAL REPORT EXPECTED 11*1 MONTH DAY V~AR EXPECTED

- , YES (If ya, eomp/m EXPECTED SUllMISSION DATE/ 1xi* NO AllTRACT (l./m/r ro 1400 _ . , l.o., .,,proxlm1r.ly fiftHn llngl**IPIC* rypowritton linnl (18)

SUBMISSION DATE 1151 I I I On January 4, 1989, Technical Specification Action Statement 3.0.3 was entered due to inoper~bility of three groups of Containment Fan Cbil Units (CFCUs). Two groups, Nos. 14 and .15 CFCUs, were inoperable due to a No. 12 Service Water (SW) Header {BI} outage. The third group, No. 11 CFCU, became inoperable when.it developed a SW leak. The root cause of this event has been attributed to equipment problems. The SW leak associated with No. 11 CFCU was located on a "T" on the c6oler discharge line. The SW header outage was needed to support No. 12A Component Cooling Heat Exchanger (CCHX) SW inlet piping.weld leakage repair. A blind flange was installed on the No. 12A CCHX SW inlet piping allowing th~ SW header to be rele~sed and making the.Nos. 14 and 15 CFCUs operable. With the CFCUs operable Technical Specification Action Statement 3.0.3 was exited. The SW leak on the No. 11 CFCU piping repairs were completed on January 8, 1989 at 0613.

hours. No. 11 CFCU was declared operable at that time resulting in.

full compliante with Technical Specification 3.6.2.3~

8902090~77 890201 PGG 1***

ADOCK n~00017; NRC Form 31111 .::*

19-83)

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1 LICENSEE EVENT _REPORT (LER) TEXT CONTINUATION

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Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Uni_t 1 _______ __?__Q_Q0~_7_L ______~_~_-:-_Q_Q_:t::*_O_Q_ _ _ _-=2 of 4 Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS} codes are identified in the text as (xx}

I'DENTIFICATION _QF OC<;'._l;_J_RR_E_l:ic:'._~_;

Entry Into Technical Specification 3.0.3 - Three Groups of Containment Fan Coil Units Inoperable Due To Equipment Problems

-Event Date: 1/04/89 Report Date: 2/01/89 This report was initiated by Incident Report No.89-014.

Mode 1 Reactor Power 100% - Unit Load 1158 MWe DESCRIPTION----*----

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*----*-----*-. OF OCCURRENCE:

On January 4, 1989-at 1125 hours0.013 days <br />0.313 hours <br />0.00186 weeks <br />4.280625e-4 months <br />, Technical Specification Action Statement 3.0.3 was entered due to inoperability of three groups of Containment Fan Coil Units (CFCUs) (BKI. Two groups, Nos. 14 and 15 CFCUs, were inoperable due to a No. 12 Service Water (SW) Header {BI}

outage. The third group, No. 11 CFCU, became inoperable when it developed-a SW leak. The SW leak was first detected as a result of required calculations which indicated an increased leak rate to the Containment Sump of greater than 1 gpm. Subsequent investigation identified SW leakage from No. 11 CFCU as th~ source of the increased leak rate.

Technical Specification Action Statement 3.6.2.3.b was first entered on January 3, 1989 at 0029 hours3.356481e-4 days <br />0.00806 hours <br />4.794974e-5 weeks <br />1.10345e-5 months <br /> in support of the SW Header outage.

Technical Specification 3.6.2.3 states:

"Three independent groups of containment cooling fans shall be OPERABLE.with two fan systems to each of two. groups and one fan system to the third group."

Technical Specification Action Statement 3.6.2.3 states:

"a. With one group of the above required containment cooling fans inoperable and both containment spray systems OPERABLE, restore the inoperable group of cooling fans to OPERABLE status within 7 days or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

b. With two qrouos of the above required containment cooling

I LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 *----------5~002_7_2_ __ 89-001-00

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- - - - 3 __g_f_4_ _

£ans inoperable and both containm~nt spray systems OPERABLE, restore at least one group of cooling fans to OPERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. Restore both above required groups of cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />.

c. With one group of the above required containment cooling fans inoperable and tine containment spray system inoperable, restore the inoperable spray system. to O~ERABLE status within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> or be in at leasi HciT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />. Restore the inoperable group of containment cooling fans to OPERABLE status within 7 days of initial loss or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> and in COLD SHUTDOWN within the following 30 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br />."

Technical Specification Action Statement 3.0.3 states:

"When a Limiting Condition for Operation is not met except as provided in the associated ACTION requirements, within one hour action shall be initiated to place the unit in a MODE in which the specification does not apply by placing it, as applicable, in:

1. At least HOT STANDBY within the next 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />,

2. At least HOT SHUTDOWN within the following 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />, and

3. At least COLD SHUTDOWN within the subsequent 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

Where corrective measures are completed that permit operation uhder the ACTION requirements; the ACTION may be taken in accordance with the specified time limits as_ measured from the time of failure to meet the Limiting Condition of Operation.

Exceptions to these requirements are stated in the individual specifications."

APPARENT CAUSE OF OCCURRENCE:

The root cause of this event has been attributed to equipment problems.

The SW leak associated with No. 11.CFCU was located on a "T" on the cooler discharge line. The SW header outage was needed to support No. 12A Component Cooling Heat Exchanger (CCHX) SW inlet piping weld leakage repair. The SW leakage from the CCHX inlet piping and the CFCU cooler discharge line have both been attributed to erosion/corrosion effects.

The CFCUs are designed to ensure the containment air temperature will be maintaine~ within limits (i.e., 120°F) during nor1nal operation,

Salem Generating Station LICENSEE EVENT REPORT (LER) TEXT CONTINUATION DOCKET NUMBER LER NUMBER PAGE Unit ~1____________ 5000272 ____ i~..:-_9_0 l -_9_9________ 4__9J_~--

and adequate heat removal capacity is available when.operated in conjunction with the Containment Spray System during post-LOCA conditions. Th~ design is such that with all five CFCUs operable, the resulting temperature/pressure transient within Containment after a design base accident (e.g., LOCA) will be mitigated without support from the Containment Spray_System.

There are five separate CFCUs which are broken up into three distinct groups. No. 11 CFCU is Group l, Nos. 12 and 14 CFCUs are Group 2, and Nos. 13 and 15 CFCUs are Group 3. If either CFCU in Groups 2 or 3 become inoperable,* that respective Group becomes inoperable.

Therefore, ~ith Nos. 11.* 14, and 15 CFCUs inoperable, thiee groups of CFCUs.wer~ inoperable req~iring.erttry into Technical Specific~tion Action Statement 3~0.3.

During this event, the Containment Spray System was operable.

Therefore, this event did not affect the public. However, this event is reportable in accordance with Code of Federal Regulations 10CFR 50.73(a) (?) (i) (B) since Technical Specificatioh Action Statement 3.0.3 was required to be entered.

CORRECTIVE ACTION:

A blind flange was installed on the No. 12A CCHX SW inlet piping.

This allowed the SW header to be released making the Nos. 14 and 15 CFCUs operable. With the CFCUs operable Technical Specification Action Statement 3.0.3 was exited at 1312 hours0.0152 days <br />0.364 hours <br />0.00217 weeks <br />4.99216e-4 months <br /> on January 4, 1989.

The SW leak on the No .. 11 CFCU piping repairs (reference Action Request #890104141) were completed on January 8, 1988 at 0613 hours0.00709 days <br />0.17 hours <br />0.00101 weeks <br />2.332465e-4 months <br />.

No. li CFCU. was declared operable at that time resulting in full compliance with Technical Specification 3.6.2.3.

General Manager -

Salem Operations MJP:pc SORC Mtg.* 89-005

/f

e PS~G f.' *'

(_.

Public Service Electric and Gas Company P.O. Box E Hancocks Bridge, New Jersey 08038 Salem Generating Station February 1, 1989 U. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555

Dear Sir:

SALEM GENERATING STATION LICENSE NO. DPR-70 DOCKET NO. 50-272 UNIT NO. 1 LICENSEE EVENT REPORT 89-001~00 This Licensee Event Report is being submitted pursuant to the requirements of the Code of Federal Regulations 10CFR 50.73(a) (2) (i) (B). This report is required within thirty (30) days of discovery.

Sincerely yours,

/tLtIL I.I. K. Miller General Manager-Salem Operations MJP:pc Distribution