ML18095A701

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LER 90-026-04:on 901130,leakage of ASME Code Class 2 & 3 Piping Occurred.Caused by Equipment Failure.Piping Upgrade Continuing & Pipe Replacement Reviewed & Modified Based on Routine Insp activites.W/910116 Ltr
ML18095A701
Person / Time
Site: Salem PSEG icon.png
Issue date: 01/16/1991
From: Labruna S, Pollack M
Public Service Enterprise Group
To:
NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM)
References
LER-90-026, LER-90-26, NUDOCS 9101280149
Download: ML18095A701 (13)
v • d • e


Text

PS~G Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station January 16, 1991

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 SUPPLEMENTAL LICENSEE EVENT REPORT 90-026-04 This Licensee Event Report supplement is being submitted to address additional ASME Code pipe leaks discovered since the last issue of this LER. This is a voluntary report pursuant to the requirements of C9de of Federal Regulations 10CFR 50.73.

Sincerely yours, r

L S. LaBruna General Manager -

Salem Operations MJP:pc i

Distribution L 9101280149 910116 ~

PDR ADOCK 05000272 S PDR The Energy People *

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95-2189 (10M) 12-89

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  • LICENSEE EVENT REPORT (LER)
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I0.73(11121111 I0.7,1111211wtlllll Voluntary I0.7'1all2111UI I0.731el1211*1 LICENSEE CONTACT FOR THll LEll (Ill NAME TELEPHONE NUMIER AREA CODE M. J. Pollack - LER Coordinator COMPLETE ONE LINE FOR EACH COMPONENT FAILUllE DEICRllED IN THll llEPOllT (1'1 CAUSE SYSTEM COMPONENT MANUFAC- MANUFAC-TURER 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 IUl"PLEMENTAL REPORT EXPECTED 1141 MONTH DAY Y~AR EXPECTED n YES (If ya, complor. EXPECTED SUBMISSION DATE/ ~NO ANTRACT (Limit ID 1400 -

  • l.o., oppro1tlmoNly flffffn rlngl*-IPICO rypowritr.n lina} 1111 SUllM1$SION DATE 1161 I I I This Licensee Event Report (LER) addresses several occurrences of ASME Code 2*and 3 piping leakage. Based upon discussion with the Nuclear Regulatory Commission (NRC), notifications were made for each occurrence as agreed .in accordance with Code of Federal Regulations 10CFR 50.72. In all cases, Salem Unit 1 Technical Specification 3.4.10.1 Actions b and c and Salem Unit 2 Technical Specification 3.4.11.1 Action c were complied with. The Salem Unit 1 and Unit 2 Technical Specification for "Structural Integrity" are identical except for their number (i.e., 3.4.10.1 v~. 3.4.11.1). The root cause of the listed ASME Code 2 and 3 component leakage has been attributed to equipment failure. The equipment failure component SW leaks were the result of erosion/corrosion factors. The 11 RHR Pump suction pressure gage tubing failure was the result of metal fatigue. The components which exhibited leakage were declared inoperable in accordance with Technical Specifications. The components were not declared operable until completion of repairs, which were done in accordance with the ASME code for Class Code components. The requirements of the Technical Specifications were complied with in all cases. An ongoing program, at Salem Generating Station, for the upgrade of Service Water System piping is continuing. The scope and prioritization of pipe replacement is reviewed' and modified, as applicable, based upon routine inspection activities and the leaks identified in this report. The 11 RHR Pump suction pressure gage equipment arrangement is being investigated.by System Engineering. Design modifications will be considered and implemented as appropriate.

NRCFwm*

Ill-Ill

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 2 of 12 PLANT AND SYSTEM IDENTIFICATION:

Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS} codes are identified in the text as (xxf IDENTIFICATION OF OCCURRENCE:

ASME Code Class 2 and 3 piping leakage caused-by equipment failure Event Date: See Table in Description of Occurrence Section Report Date: 1/16/91 This report was initiated by Incident Report Nos.90-388, 90-456,90-463, 90-512,90-517, 90-531,90-540, 90-585,90-657, 90-746,90-758, 90-759,90-793, 90-803,90-811, 90-884,90-885, 90-893,90-894, 90-897,90-912, 90-929,90-930, 90-932,90-935, 90-936, 90~937, and 90-951.

CONDITIONS PRIOR TO OCCURRENCE:

N/A DESCRIPTION OF OCCURRENCE:

This Licensee Event Report (LER) addresses several occurrences of ASME Code 3 piping leakage and one case of ASME Code 2 piping leakage.

Based upon discussion with the Nuclear Regulatory Commission (NRC) notifications, were made of each occurrence. This was done, as agreed, in accordance with Code of Federal Regulations 10CFR 50.72.

In all cases, Salem Unit 1 Technical Specification 3.4.10.1 Action b and c (as applicable) and Salem Unit 2_ Technical Specification 3.4.11.1 Action c were complied with. The Salem Unit 1 and Unit 2 Technical Specification for "Structural Integrity" are identical except for their number (iee., 3.4.10.1.vs. 3.4.li.1).

Salem Unit 1 Technical Specification 3.4.10.1 states:

"The structural integrity of ASME Code Class 1, 2 and 3 components shall be maintained in accordance with Specification 4.4.10.1.

Salem Unit 1 Technical Specification 3.4.10.1 Action b and c state:

b. "With the structural integrity of any ASME Code Class 2 component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) prior to increasing the Reactor Coolant System temperature above 200°F."
c. "With the structural integrity of any ASME Code Class 3

LICENSEE EVENT. REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 3 of 12 DESCRIPTION OF OCCURRENCE: (cont'd) component(s) not conforming to the above requirements, restore the structural integrity of the affected component(s) to within its limit or isolate the affected component(s) from service."

Identified leakage from ASME Class Code 3 components/piping and ASME Class Code 2 component(s)/piping (specifically identified) include:

COMPONENT DATE CONCERN Unit 2 No. 24 6/11/90 Service Water (SW) System {Bii minor leakage Containment from motor cooler Fan Coil Unit (CFCU) {BK)

Technical Specification Applicability:

No. 24 CFCU leakage was identified with the Unit in Mode 4; CFCUs are required to be operable in Modes 1, 2, and 3.

Therefore, the Technical Specification Action Statement for inoperable CFCUs did not apply.

Unit 1 12B 7/02/90 Inlet flange weld cracked; SW leak (SW Component side) of approximately 15 gpm Cooling (CC) Heat Exchanger {CCI Technical Specification 3.7.4.1 Applicable. It states:

"At least two independent service water loops shall be OPERABLE.

ACTION:

With only one service water loop OPERABLE, restore at least two loops 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 />."

Unit 2 #2 7/05/90 2" inlet SW pipe developed through wall Auxiliary minor pipe leak Feedwater (AFW)

Room Cooler {VF)

Technical Specification Applicability:

The room coolers are not identified in Technical Specifications; however internal procedural requirements, which provide the administrative limits for being out of service, were met.

Salem Generating Station

  • DOCKET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 90-026-04 *4 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT DATE CONCERN Unit 1 14 7/23/90 Thru wall SW leak CFCU downstream sid.e of the 14SW223 valve Technical Specification Applicability:

No. 14 CFCU leakage was identified with the Unit in Mode 4; CFCUs are required to be operable in Modes 1, 2, and 3.

Therefore, the Technical Specification Action Statement for inoperable CFCUs did not apply.

Unit 2 21 7/23/90 Thru wall minor SW leak

& 22 Chillers f KMI 4" Supply Line Technical Specification Applicability: None (other than 3.4.10.1)

Unit 1 11 SW 7/28/90 SW Casing leak (leakage drains to the sump Pump via a drain line)

Technical Specification 3.7.4.1 applicable; however, the Unit was in Mode 5 during the period the No. 11 SW Pump was inoperable, therefore the Action Statement did not apply since the LCO is only applicable in Modes 1, 2, 3 and 4 Unit 1 12SW74 8/01/90 Thru wall minor SW leak at P-3 connection valve (12 CFCU Valve was tagged out at time of discovery Flow Tap Valve)

Technical Specification Applicability:

No. 12 CFCU leakage was identified with the Unit in Mode 4; CFCUs are required to be operable in Modes 1, 2, and 3.

Therefore, the Technical Specification Action Statement for inoperable CFCUs did not apply.

Unit 2 2MS57 8/14/90 Thru wall main steam (MS) leak at body of Check Valve valve for the MS & Turbine Bypass AFW Pump Drain Header Technical Specification Applicability: None Unit 1 #12 9/06/90 The outlet SW pipe developed a through wall Charging Pump pipe leak

  • Room Cooler

Salem Generating Station*

  • DOCKET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 90-026-04 5 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT CONCERN Technical Specification Applicability:

The room coolers are not identified in Technical Specifications; however internal procedural requirements, which provide the administrative limits for being out of service, were met.

Unit 1 lA 10/03/90 Small weld leak upstream of 1SW909 SW Diesel Generator Vent Valve, which is located on the (D/G) {EKI vent line coming off the 6" SW inlet SW piping line to the Jacket Water Cooler; the leak was discovered after removal of insulation Technical Specification 3.8.1.1.b Action "a" applicable: It was entered on 10/03/90 at 1612 hours0.0187 days <br />0.448 hours <br />0.00267 weeks <br />6.13366e-4 months <br /> and exited on 10/06/90 at 1503 hours0.0174 days <br />0.418 hours <br />0.00249 weeks <br />5.718915e-4 months <br />. The other two (2) D/G remained operable during the period when the lA D/G was inoperable. The Action Statement states:

"With either an offsite circuit or diesel generator of the above required A.C. electrical power sources inoperable, demonstrate the OPERABILITY of the remaining A.C. sources by performing Surveillance Requirements 4.8.1.1.1.a and 4.8.1.1.2.a.2 within one hour and at least once per 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> thereafter; restore at least two offsite circuits and three diesel generators 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 />."

Unit 2 2B 10/08/90 Thru wall Leakage below the 22SW39 D/G SW Piping valve; Jac.ket Water Cooler Inlet Pipe weld Technical Specification 3.8.1.1.b Action "a" applicable: It was entered on 10/08/90 at 1330 hours0.0154 days <br />0.369 hours <br />0.0022 weeks <br />5.06065e-4 months <br /> and exited on 10/11/90 at 0859 hours0.00994 days <br />0.239 hours <br />0.00142 weeks <br />3.268495e-4 months <br />. The other two (2) D/Gs remained operable during the period when the 2B D/G was inoperable. The Action Statement is identical to the Unit 1 Action Statement stated above.

Unit 1 12A CC 10/09/90 Small pipe leak (pin hole) next to Heat Exchanger 12SW383 (Outlet Valve) pipe weld 14" SW Header Technical Specification Applicability: None

Salem Generating Station* DOCKET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 90-026-04 6 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT CONCERN Unit 2 21 RHR 10/19/90 Pinhole leak in the instrument supply Pump Room Cooler tubing to the differential pressure controller for the Room Cooler SW flow control valve Technical Specification Applicability:

The room coolers are not identified in Technical Specifications; however internal procedural requirements, which provide the administrative limits for being out of service, were met.

Unit 1 12SW268 10/23/90 Weld SW leakage valve (#12 CFCU Header Drain Valve)

Technical Specification Applicability: None (other than 3.4.10.1)

Unit 2 Piping 10/24/90 SW leakage; two (2) pinhole leaks Between the 2SW27 between valves and the 2SW28 Valves Technical Specification Applicability: None (other than 3.4.10.1)

Unit 1 Piping 11/19/90 SW thru wall leakage (pinhole size)

Downstream of The 1R13D Radiation Monitoring System the 14SW405 Valve (RMS} {ILi channel (No. 14 CFCU SW discharge monitor} was declared inoperable since the leak was on the line going to the monitor Technical Specification Applicability:

Technical Specification 3.3.3.8 Action "28" applicable: It was entered on 11/19/90 at 0330 hours0.00382 days <br />0.0917 hours <br />5.456349e-4 weeks <br />1.25565e-4 months <br /> and exited on 11/26/90 at 1430 hours0.0166 days <br />0.397 hours <br />0.00236 weeks <br />5.44115e-4 months <br />. The channel deals with the sampling requirements which must be performed when the 1R13D channel is inoperable.

Unit 1 No. 3 11/19/90 SW leak between the 15 SW Pump SW Bay overpressure protection line and the SW Bay Technical Specification Applicability: Technical Specification 3.7.4.1 It states: "At least two independent service water loops shall be OPERABLE."

Salem Generating Station* DOC.KET NUMBER LICENSEE EVENT REPORT (LER) TEXT CONTINUATION LER NUMBER PAGE Unit 1 5000272 90-026-04 7 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT CONCERN Its Action Statement states: "With only one service water loop OPERABLE, restore at least two loops 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 />."

The SW leak was repaired and the Action Statement exited prior to initiation of a plant shutdown.

Unit 1 No. 15 11/23/90 Thru wall SW leak (pinhole size)

CFCU 3/4" pressure tap line Technical Specification Applicability: Technical Specification 3.6.2.3 requires operability of three (3) groups of CFCUs.

Since No. 14 CFCU was also inoperable, due to a SW motor cooler flange leak. The Action Statement ("b") which applied states:

"With two groups of the above required containment cooling fans inoperable and both containment 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 />."

The SW leaks were repaired and the Action Statement exited prior to initiation of a plant shutdown.

Unit 1 No. 12 11/23/90 14" Nuclear Header SW Leak SW Nuclear Header Technical Specification Applicabilfty: Technical Specification 3.7.4.1.

The SW leak was repaired and the Action Statement exited prior to initiation of a plant shutdown.

Unit 2 No. 2A 11/24/90 21SW39 valve thru wall leak (pinhole D/G size); Jacket Water Cooler Inlet Pipe Technical Specification 3.8.1.l.b Action "a" applicable: It was entered on 11/24/90 at 1403 hours0.0162 days <br />0.39 hours <br />0.00232 weeks <br />5.338415e-4 months <br /> and exited on 11/26/90 at 2031 hours0.0235 days <br />0.564 hours <br />0.00336 weeks <br />7.727955e-4 months <br />. The other two (2) D/Gs remained operable during the period when the 2A D/G was inoperable. The Action Statement is identical to the Unit 1 Action Statement stated previously on page 4.

Salem Generating Station DOCKET NUMBER LICENSEE EVENT REPORT (LER} TEXT CONTINUATION LER NUMBER . PAGE Unit 1 5000272 90-026-04 8 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT DATE CONCERN Unit 1 No. 14 11/28/90 Weld leakage on SW outlet pipe CFCU where 10" header meets 3/4" vent line; This is an ASME Code Class 2 component Technical Specification Applicability: Technical Specification 3.6.2.3 was entered to support repair of the leak. It requires operability of three (3) groups of CFCUs. The Action Statement

("a") which applied states:

"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 />."

The SW leak was repaired and the Action Statement exited prior to initiation of a plant shutdown.

Unit 1 No. 14 11/30/90 Leak in instrument tubing located in the No.

CFCU Instrument Line 12 SW Valve Room (i.e., not the Containment)

Technical Specification Applicability: None (other than 3.4.10.1); The CFCU remained operable during repairs Unit 1 No. 14 11/30/90 Thru wall leak in the gland injection SW Pump line flex hose Technical Specification Applicability: None (other than 3.4.10.1); The Room Cooler remained operable during repairs Unit 1 No. 12 12/03/90 SW Thru wall leak in piping in the CFCU Piping penetration area (i.e., not the Containment)

Technical Specification Applicability: Technical Specification Applicability: Technical Specification 3.6.2.3 was entered to support repair of the leak. It requires operability of three (3) groups of CFCUs. The Action Statement ("a") was entered (see above for Action Statement requirements).

Unit 1 11SW6 12/07/90 "Weeping" type leaks on 4" pipe near the Valve Piping 11SW6 (2 leaks)

(Screen Wash Supply Valve)

Technical Specification Applicability: Technical Specification Applicability: Technical Specification 3.7.4.1 was entered to support repair of the leakq It requires operability of two (2)

SW headers during power operation. The Action Statement was entered (see page 6 for Action Statement requirements).

v LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 9 of 12 DESCRIPTION OF OCCURRENCE: (cont'd)

COMPONENT CONCERN Unit 1 12SW157 12/07/90 Thru wall leak on 3/8" tubing line Valve Piping (RBR Pump Room Cooler SW Pressure Tap Valve)

Technical Specification Applicability: None (other than 3.4.10.1): The Room Cooler remained operable during repairs Unit 1 11 RBR 12/12/90 Tubing fracture located where the 3/8" Pump Suction tubing connects to the 11RH30 valve (11 RHR Pressure Indication Pump Suction Pressure Tap Valve) (on Tubing pressure indication side)

This tubing is ASME Code Class 2 Additional The tubing crack was discovered by a Information: Maintenance-I&C technician who was installing a Heise test gage in support of an 11 RHR Pump inservice surveillance test. The 11RBR30 valve was found closed; no on-going leakage was evident.

Technical Specification Applicability: None (other than 3.4.10.1); The RHR System remained operable during repairs.

APPARENT CAUSE OF OCCURRENCE:

The root cause of the listed ASME Code component leakage has been attributed to equipment failure. The above listed component leaks were the result of erosion/corrosion factors except for the Unit 1 11 RHR Pump suction pressure* tubing (discovered on 12/12/90).

The RHR Pump suction pressure tubing failure occurred since the last successful completion of the RBR Pump surveillance test (September 1990). Its failure is attributed to metal fatigue and the configuration of the PI-631 gage. The configuration of the equipment includes a three-way valve vertically above the 11RH30 valve. The PI-631 gage is located on a discharge point of the three-way valve.

The other discharge point, on the three-way valve is used as a flush line.

This equipment arrangement is being investigated by System Engineering. Upon completion of the investigation, design modifications will be considered and implemented as appropriate.

ANALYSIS OF OCCURRENCE:

The ASME Code components which exhibited leakage are located in the Auxiliary Building except for the CFCUs which are located in Containment.

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 10 of 12 ANALYSIS OF OCCURRENCE: (cont'd)

The Containment Spray System is 100% redundant to the CFCUs. It was operable during the periods when the CFCU(s) had been declared inoperable. Therefore, the capability to mitigate the consequences of a design base accident was not affected.

An increase in Containment Sump inleakage is the primary indication of the development of RCS or other system leakage. Continuous monitoring of the sump inleakage allow early detection of a potential problem and provides a basis for initiation of appropriate actions to identify, isolate, and repair the leak. Due to the small size of the CFCU SW leakage involved, had it remained undetected during a LOCA, it would have had negligible immediate impact on Containment Sump boron concentration, chloride concentration, and pH levels. Therefore, the CFCU SW leakage did not affect the health or safety of the public.

The components which exhibited leakage were declared inoperable in.

accordance with Technical Specifications. The components were not (or have not been) declared operable until completion of repairs, which either were done or will be done, as applicable, in accordance with the ASME code. The requirements of the Technical Specifications were complied with in all cases. Therefore, the events identified in this LER involved no undue risk to the health or safety of the public. However, due to the concern that the NRC has expressed in regard to ASME Code component repairs (reference Generic Letter 90-05), these events are being reported as a "voluntary" LER in accordance with the guidance of NUREG 1022, "Licensee Event Report System".

CORRECTIVE ACTION:

In all cases, repair of the affected components either was completed or will be completed in accordance with the ASME Code. Specifically:

COMPONENT DATE OF REPAIR REPAIR 24 CFCU 6/11/90 Affected tube was plugged 12B CC Heat 7/05/90 Piping repaired per Code (reference DR No.

Exchanger SMD 90-213)

  1. 2 AFW Room 7/10/90 Piping repaired per Code (reference DR No.

Cooler SMD 90-214) 14 CFCU 8/04/90 Piping repaired per Code (reference DR No.

(14SW223) SMD 90-228) 21 & 22 Chil- Piping will be repaired per Code (reference lers 4" Supply DR No. SMD 90-233)

Line

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 11 of 12 CORRECTIVE ACTION: (cont'd) 11 SW Pump 8/17/90 Damaged discharge head replaced per Code 12SW74 valve 8/16/90 Piping repa1red per Code (reference DR No.

SMD 90-236) 2MS57 Check 8/17/90 Replaced valve as per Code (reference DR No.

SMD 90-247)

  1. 12 Charging 9/12/90 Piping repaired per Code (reference DR No.

Pmnp Room SMD 90-258)

Cooler Unit 1 lA 10/06/90 Piping repaired per Code (reference DR No.

D/G SW Piping SMD 90-268)

Unit 2 2B 10/11/90 Piping repaired per Code (reference DR No.

D/G SW Piping SMD 90-276)

Unit 1 12A CC 10/13/90 Piping repaired per Code (reference DR No.

Heat Exchanger SMD 90-277) 14" SW Header Unit 2 21 RHR 10/21/90 Piping repaired per Code (reference DR No.

Pump Room Cooler SMD 90-280)

Unit 1 12SW268 10/25/90 Piping repaired per Code (reference DR No.

valve (#12 CFCU SMD 90-282)

Header Drain Valve)

Unit 2 Piping 11/20/90 Piping repaired per Code (reference DR No.

Between the 2SW27 SMD 90-286) and the 2SW28 Valves Unit 1 Piping 11/26/90 Piping repaired per Code (reference DR No.

Downstream of SMD 90-297) the 14SW405 Valve Unit 1 No. 3 11/22/90 Piping repaired per Code (reference DR No.

SW Bay SMD 90-296)

Unit 1 No. 15 11/25/90 Piping repaired per Code (reference DR No.

CFCU 3/4" pressure SMD 90-300) tap line Unit 1 No. 12 11/25/90 Piping repaired per Code (reference DR No.

SW Nuclear Header SMD 90-301)

Unit 2 No. 2A 11/26/90 Piping repaired per Code (reference Work D/G Order #901026070)

Unit 1 No. 14 11/30/90 Piping repaired per Code (reference DR No.

CFCU SMD 90-302)

LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 90-026-04 12 of 12 CORRECTIVE ACTION: (cont'd)

Unit 1 No. 14 12/01/90 Piping repaired per Code (reference DR No.

CFCU Instrument SMD 90-306)

Line Unit 1 14 SW 12/01/90 Gland Injection Line Replaned in kind Pump (reference WO 901130269)

Unit 1 No. 12 12/05/90 Piping repaired per Code (reference DR No.

CFCU SMD 90-309)

Unit 1 11SW6 12/08/90 Piping repaired per Code (reference DR No.

Valve SMD 90-314)

Unit 1 12/11/90 Piping repaired per Code (reference DR No.

12SW157 Valve SMD 90-315)

Unit 1 11 RHR 12/14/90 The tubing was weld repaired in accordance Pump Suction the ASME code.

The 11 RHR Pump suction pressure gage equipment arrangement is being investigated by System Engineering. Upon completion of the investigation, design modifications will be considered and implemented as appropriate.

An ongoing program, at Salem Generating Station, for the upgrade of Service Water System piping is continuing. The scope and prioritization of pipe replacement is reviewed and modified, as applicable, based upon routine inspection activities and the leaks identified in this report.

General Manager -

Salem Operations MJP:pc SORC Mtg.91-003

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