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

  • Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station 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 January 16, 1991 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 lOCFR 50.73. MJP:pc Distribution 9101280149 910116 PDR ADOCK 05000272 S PDR The Energy People Sincerely yours, S. LaBruna General Manager -Salem Operations 95-2189 (10M) 12-89 r L i L * [

  • INltC For111-li-ll3J U.S. NUCUAll llEOULATOllY CO...llSION Al'l'f'IOVED OMe NO.

LICENSEE EVENT REPORT (LER) EXPllUI: 1/lllllli fACILITY NAME 111 Salem Generating Station -Unit 1 !DOCKET 121 I r"u" loll 0. I 5 I 0 I 0 I 0 I 217 I 2 1 I OF I 1 2 TITLE I .. ASME Code Class 2 & 3 Piping Leakage Caused By Equipment Failure IVENT DATE Ill LER NUMaER Ill llEPOllT DATE 171 OTHEll FACILITIES INVOLVED Ill MONTH QAY YEAR YEAR ll MONTH DAY YEAR FACILITY NAMU DOCKET NUMllER(lll Salem -Unit 2 o I & I o I o I o 13 u. 11 i I 1 3 I o 9 o 9 I o -ol 216 -o 14 ol 1 i I E 911 Ol'EllATINQ THll llEPORT II IU9MITTED PURSUANT TO THE REQUIREMENTS OF 10 CFll §: (Clrd OM or,,_.. of rtt. fol/owlnf}

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--I0.7'1all2111UI LICENSEE CONTACT FOR THll LEll (Ill NAME AREA CODE M. J. Pollack -LER Coordinator COMPLETE ONE LINE FOR EACH COMPONENT FAILUllE DEICRllED IN THll llEPOllT (1'1 CAUSE SYSTEM COMPONENT I I I I I I I I TURER I I I I I I SYSTEM I I COMPONENT MANUFAC-TUR ER I I I I I I I I I I I I Voluntary TELEPHONE NUMIER IUl"PLEMENTAL REPORT EXPECTED 1141 EXPECTED MONTH DAY SUllM1$SION DATE 1161 n YES (If ya, complor. EXPECTED SUBMISSION DATE/ I I ANTRACT (Limit ID 1400 -* l.o., oppro1tlmoNly flffffn rlngl*-IPICO rypowritr.n lina} 1111 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 lOCFR 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 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 I

  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 PLANT AND SYSTEM IDENTIFICATION:

Westinghouse

-Pressurized Water Reactor LER NUMBER 90-026-04 PAGE 2 of 12 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, 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 lOCFR 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 Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 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 Containment Service Water (SW) System {Bii minor leakage 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 side) of approximately 15 gpm Component 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 minor pipe leak Auxiliary 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.

  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 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:

LER NUMBER 90-026-04 PAGE *4 of 12 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 Pump 7/28/90 SW Casing leak (leakage drains to the sump 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 valve (12 CFCU Flow Tap Valve) Thru wall minor SW leak at P-3 connection Valve was tagged out at time of discovery 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 Charging Pump Room Cooler 9/06/90 The outlet SW pipe developed a through wall pipe leak *

  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station* Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 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 Vent Valve, which is located on the vent line coming off the 6" SW inlet line to the Jacket Water Cooler; the leak was discovered after removal of insulation Diesel Generator (D/G) {EKI SW piping 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: Unit 2 2B "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 />." 10/08/90 D/G SW Piping Thru wall Leakage below the 22SW39 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 Heat Exchanger 14" SW Header Small pipe leak (pin hole) next to 12SW383 (Outlet Valve) pipe weld Technical Specification Applicability:

None

  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station* Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 6 of 12 DESCRIPTION OF OCCURRENCE: (cont'd) COMPONENT Unit 2 21 RHR 10/19/90 Pump Room Cooler CONCERN Pinhole leak in the instrument supply 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 valve (#12 CFCU Header Drain Valve) Weld SW leakage Technical Specification Applicability:

None (other than 3.4.10.1)

Unit 2 Piping 10/24/90 Between the 2SW27 and the 2SW28 Valves SW leakage; two (2) pinhole leaks between valves Technical Specification Applicability:

None (other than 3.4.10.1)

Unit 1 Piping 11/19/90 Downstream of the 14SW405 Valve SW thru wall leakage (pinhole size) The 1R13D Radiation Monitoring System (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 SW Bay 11/19/90 SW leak between the 15 SW Pump 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."

  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station* Unit 1 DOC.KET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 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 CFCU 3/4" pressure tap line Thru wall SW leak (pinhole size) 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 SW Nuclear Header 14" Nuclear Header SW Leak 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 D/G 21SW39 valve thru wall leak (pinhole 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.

.. *

  • LICENSEE EVENT REPORT (LER} TEXT CONTINUATION Salem Generating Station Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 . PAGE 8 of 12 DESCRIPTION OF OCCURRENCE: (cont'd) COMPONENT DATE Unit 1 No. 14 11/28/90 CFCU CONCERN Weld leakage on SW outlet pipe 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 CFCU Instrument Line Leak in instrument tubing located in the No. 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 SW Pump 11/30/90 Thru wall leak in the gland injection line flex hose Technical Specification Applicability:

None (other than 3.4.10.1);

The Room Cooler remained operable during repairs Unit 1 No. 12 CFCU Piping 12/03/90 SW Thru wall leak in piping in the 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 Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 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 Pump Suction Tubing fracture located where the 3/8" tubing connects to the 11RH30 valve (11 RHR Pump Suction Pressure Tap Valve) (on pressure indication side) Pressure Indication Tubing Additional Information:

This tubing is ASME Code Class 2 The tubing crack was discovered by a 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 Unit 1 DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 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 24 CFCU 12B CC Heat Exchanger

  1. 2 AFW Room Cooler 14 CFCU (14SW223) 21 & 22 lers 4" Supply Line DATE OF REPAIR 6/11/90 7/05/90 7/10/90 8/04/90 REPAIR Affected tube was plugged Piping repaired per Code (reference DR No. SMD 90-213) Piping repaired per Code (reference DR No. SMD 90-214) Piping repaired per Code (reference DR No. SMD 90-228) Piping will be repaired per Code (reference DR No. SMD 90-233)
  • *
  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 CORRECTIVE ACTION: (cont'd) 11 SW Pump 8/17/90 12SW74 valve 8/16/90 2MS57 Check 8/17/90 #12 Charging 9/12/90 Pmnp Room Cooler Unit 1 lA 10/06/90 D/G SW Piping Unit 2 2B 10/11/90 D/G SW Piping Unit 1 12A CC 10/13/90 Heat Exchanger 14" SW Header Unit 2 21 RHR 10/21/90 Pump Room Cooler Unit 1 12SW268 10/25/90 valve (#12 CFCU Header Drain Valve) Unit 2 Piping 11/20/90 Between the 2SW27 and the 2SW28 Valves Unit 1 Piping 11/26/90 Downstream of the 14SW405 Valve DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 11 of 12 Damaged discharge head replaced per Code Piping repa1red per Code (reference DR No. SMD 90-236) Replaced valve as per Code (reference DR No. SMD 90-247) Piping repaired per Code (reference DR No. SMD 90-258) Piping repaired per Code (reference DR No. SMD 90-268) Piping repaired per Code (reference DR No. SMD 90-276) Piping repaired per Code (reference DR No. SMD 90-277) Piping repaired per Code (reference DR No. SMD 90-280) Piping repaired per Code (reference DR No. SMD 90-282) Piping repaired per Code (reference DR No. SMD 90-286) Piping repaired per Code (reference DR No. SMD 90-297) Unit 1 No. 3 SW Bay 11/22/90 Piping repaired per Code (reference DR No. Unit 1 No. 15 11/25/90 CFCU 3/4" pressure tap line Unit 1 No. 12 11/25/90 SW Nuclear Header Unit 2 No. 2A 11/26/90 D/G SMD 90-296) Piping repaired per Code (reference DR No. SMD 90-300) Piping repaired per Code (reference DR No. SMD 90-301) Piping repaired per Code (reference Work Order #901026070)

Unit 1 No. 14 11/30/90 Piping repaired per Code (reference DR No. CFCU SMD 90-302)

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  • LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station Unit 1 CORRECTIVE ACTION: (cont'd) Unit 1 No. 14 12/01/90 CFCU Instrument Line Unit 1 14 SW 12/01/90 Pump Unit 1 No. 12 12/05/90 CFCU Unit 1 11SW6 12/08/90 Valve Unit 1 12/11/90 12SW157 Valve Unit 1 11 RHR 12/14/90 Pump Suction DOCKET NUMBER 5000272 LER NUMBER 90-026-04 PAGE 12 of 12 Piping repaired per Code (reference DR No. SMD 90-306) Gland Injection Line Replaned in kind (reference WO 901130269)

Piping repaired per Code (reference DR No. SMD 90-309) Piping repaired per Code (reference DR No. SMD 90-314) Piping repaired per Code (reference DR No. SMD 90-315) The tubing was weld repaired in accordance 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. MJP:pc SORC Mtg.91-003 General Manager -Salem Operations

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