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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0081998-12-24024 December 1998 LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr ML18106B0021998-12-17017 December 1998 LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr ML18106A9551998-11-0303 November 1998 LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr ML18106A9451998-10-30030 October 1998 LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr ML18106A9491998-10-22022 October 1998 LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr ML18106A9301998-10-21021 October 1998 LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr ML18106A9071998-10-0101 October 1998 LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr ML18106A8951998-09-28028 September 1998 LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr ML18106A8821998-09-21021 September 1998 LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr ML18106A8791998-09-16016 September 1998 LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr ML18106A8801998-09-0808 September 1998 LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr ML18106A8531998-08-27027 August 1998 LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr ML18106A8521998-08-27027 August 1998 LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr ML18106A8421998-08-24024 August 1998 LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr ML18106A8431998-08-24024 August 1998 LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr ML18106A8141998-08-13013 August 1998 LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr ML18106A8201998-08-13013 August 1998 LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr ML18106A6931998-06-29029 June 1998 LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged ML18106A6471998-06-0404 June 1998 LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr ML18106A6421998-06-0101 June 1998 LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr ML18106A6431998-05-29029 May 1998 LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr ML18106A6141998-05-18018 May 1998 LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr ML18106A5901998-05-0101 May 1998 LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr ML18106A5611998-04-20020 April 1998 LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected ML18106A6061998-04-0101 April 1998 Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences ML18106A4451998-04-0101 April 1998 LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr ML18106A4351998-03-30030 March 1998 LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr ML18106A3961998-03-20020 March 1998 LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr ML18106A5781998-03-20020 March 1998 Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs ML18106A4021998-03-20020 March 1998 LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr ML18106A4031998-03-20020 March 1998 LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr 1999-08-26
[Table view] Category:RO)
MONTHYEARML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0081998-12-24024 December 1998 LER 97-001-01:on 970215,failure to Perform TS Surveillance of Component Cooling Water Sys Check Valves Occurred.Caused by Inadequate Communication Between EOP Group & IST Reviewers.Procedure Revised.With 981224 Ltr ML18106B0021998-12-17017 December 1998 LER 98-015-01:on 980924,improper Installation of Test Equipment to RPS Occurred.Caused by Inadequate 10CFR50.59 Applicability Reviews During Past Revs.Revised Procedures. with 981217 Ltr ML18106A9551998-11-0303 November 1998 LER 96-013-01:on 960711,concluded That Current Gain & Bias Settings Had Rendered Overtemperature Delta Temp Protection Channels Inoperable.Caused by Scaling Error.Licensee Will Revise Scaling Calculations.With 981105 Ltr ML18106A9451998-10-30030 October 1998 LER 97-004-01:on 970408,failure to Comply with TS Action Statement,Dg Start & Inadequate Surveillance Testing,Was Noted.Caused by Inadequate Tracking of Inoperable Equipment. Discussed Event & Lessons Learned.With 981022 Ltr ML18106A9491998-10-22022 October 1998 LER 98-015-00:on 980924,identified Improper Installation of Test Equipment to Rps.Cause Indeterminate.Procedures for Installation of Test Equipment for Collection of State Point Data Were Placed on Administrative Hold.With 981022 Ltr ML18106A9301998-10-21021 October 1998 LER 98-014-00:on 980725,noted Improper Calibr of Liquid Radwaste Effluent Line Radiation Monitor.Caused by Inattention to Detail by Maint Personnel.Channel Calibr Was Successfully Performed on 1R18 on 980821.With 981019 Ltr ML18106A9071998-10-0101 October 1998 LER 98-014-00:on 980918,discovered That Fire Barrier Matl for HVAC Ducts Does Not Meet Required Level of Fire Resistance.Cause Indeterminate.Established Appropriate Compensatory Actions for Fire Barriers.With 981001 Ltr ML18106A8951998-09-28028 September 1998 LER 98-012-01:on 980725,noted That Afs Was Operated with Less than Required Number of Operable AFW Pumps.Caused by Improper Procedure Implementation.Runout Protection Pressure Device for 22 AFW Pumps Was Returned to Svc.With 980928 Ltr ML18106A8821998-09-21021 September 1998 LER 98-013-00:on 980820,noted Surveillance of Containment Penetration Overcurrent Protection Devices Missed.Caused by Human Error.Satisfactorily Tested Apprpriate Breakers & Disciplined Involved Personnel.With 980921 Ltr ML18106A8791998-09-16016 September 1998 LER 96-006-01:on 960717,determined That non-radioactive Liquid Basin Radwaste Monitor Inoperable During Low Head Conditions.Caused by Inadequate Design Change Package.Design Change 1EC3663-01 Has Been Installed.With 980916 Ltr ML18106A8801998-09-0808 September 1998 LER 98-013-00:on 980806,operation with TS Required Equipment OOS Was Noted.Caused by Human Error.Reviewed Processes & Practices Re Safety Sys Status Control,Procedure Rev & Extra Training.With 980908 Ltr ML18106A8531998-08-27027 August 1998 LER 98-007-00:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Cause of Event Has Not Yet Been Determined.Assembled Root Cause Team & Replaced Affected tubing.W/980827 Ltr ML18106A8521998-08-27027 August 1998 LER 98-011-00:on 980803,ESFA During a 4KV Automatic Transfer Test Was Noted.Caused by Premature Release of Control Console Pushbutton Due to Inadequate Procedural Step.Revised procedure.W/980827 Ltr ML18106A8421998-08-24024 August 1998 LER 98-012-00:on 980725,discovered That Plant Had Operated in Modes 1 & 2 w/twenty-two AFW Pumps Inoperable.Caused by Failure to Restore Pump Runout Protection Pressure Device to Svc.Returned Subject Device to svc.W/980824 Ltr ML18106A8431998-08-24024 August 1998 LER 98-009-00:on 980810,failure to Post Continuous Firewatch as Required by Fire Protection Plan Noted.Caused by Failure to Recognize Concurrent Conditions.Continuous Firewatch Was Posted Immediately & Repaired Smoke detectors.W/980824 Ltr ML18106A8141998-08-13013 August 1998 LER 98-010-00:on 980714,determined That Leakage from Boron Injection Tank Exceeded Max Allowable ECCS Leakage from Sources Outside Containment.Caused by Leaking 2SJ404 Manual Sample valve.2SJ404 Valve repaired.W/980813 Ltr ML18106A8201998-08-13013 August 1998 LER 98-012-00:on 980715,potential to Exceed Rating of Piping Due to Isolation of Overpressure Protection Line Was Noted. Caused by Inadequate Procedural Guidance.Appropriate Operations Dept Procedures Have Been revised.W/980813 Ltr ML18106A6931998-06-29029 June 1998 LER 98-003-00:on 980122,inappropriate Plugging of Tubes R9C60 & R10C60 in Salem Unit 2 Sg,Was Performed.Caused by Failure of Qualification,Verification & Validation Process. Tubes Reviewed to Verify No Others Inappropriately Plugged ML18106A6471998-06-0404 June 1998 LER 98-011-00:on 980505,improper Isolation of Single Cell Battery Charger from 125 Vdc Battery Was Noted.Caused by Inadequate 10CFR50.59 Applicability Review.Placed Procedure SC.MD-CM.ZZ-0024(Q) on Administrative hold.W/980604 Ltr ML18106A6421998-06-0101 June 1998 LER 98-010-00:on 931019,reactor Pressure Vessel Insp Plugs Were Out of Configuration,Was Noted.Caused by Personnel Error.Proper Configuration Was Restored Shortly After Discovery Prior to Entering Mode 2.W/980601 Ltr ML18106A6431998-05-29029 May 1998 LER 98-006-01:on 980227,determined Incorrect Scaling Error of First Stage Pressure Transmitter Existed.Caused by Human Error.Revised Setpoint Calculation SC-MS002-01 & Revised Associated Instrument Calibr Database info.W/980529 Ltr ML18106A6141998-05-18018 May 1998 LER 98-008-00:on 970814,failure to Test 21 & 22 AF 40 Valves in Closed Direction as Required by TS 4.0.5 Was Noted.Caused by Inadequate Design Mod Process.Motor Driven 21/22 AF 40 Valves Were Tested IAW Revised procedure.W/980518 Ltr ML18106A5901998-05-0101 May 1998 LER 98-009-00:on 980405,epoxy Missing from Terminals of H Analyzer Was Noted.Caused by Inadequate Development of Procedure.H Analyzers Were Repaired & Review of Other Safety Related Equipment in Containment Was performed.W/980501 Ltr ML18106A5611998-04-20020 April 1998 LER 98-008-00:on 980323,inadequate Testing of Salem Unit 1 Containment Air Locks Resulted in Entering TS 3.0.3.Caused by less-than-adequate Work Practices During Replacement of Equalizing Valve.Salem Unit 2 Airlocks Were Inspected ML18106A6061998-04-0101 April 1998 Corrected LER 98-004-00:on 980302,failure to Comply W/Tss 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Have Been Taken to Correctly Document Safety Factors.Corrects Prior Similar Occurrences ML18106A4451998-04-0101 April 1998 LER 98-004-00:on 980302,failure to Perform TS 4.11.1.1.2 & 3.3.3.8 Was Noted.Caused by Organizational Deficiency.Steps Were Taken to Correctly Document Safety factors.W/980401 Ltr ML18106A4351998-03-30030 March 1998 LER 98-006-00:on 980227,incorrect Scaling of First Stage Turbine Impulse Pressure Transmitters Noted.Cause Indeterminate.Implemented Procedure Changes & re-scaled Affected Turbine Impulse Pressure transmitters.W/980330 Ltr ML18106A3961998-03-20020 March 1998 LER 98-005-00:on 980219,inoperability of Twelve EDG Fuel Oil Transfer Pump (FOTP) Noted.Caused by Installation of Incorrect Control Switch.Installed Correct off-auto-manual Switch & Verified Operability of Twelve FOTP.W/980320 Ltr ML18106A5781998-03-20020 March 1998 Corrected LER 98-005-00:on 980219,inoperability of 12 Fuel Oil Transfer Pump (Fotp),Noted.Caused by Installation of Incorrect Control Switch.Field Insp Performed to Verify Configuration of Switches for 11,21 & 22 FOTPs ML18106A4021998-03-20020 March 1998 LER 98-007-00:on 980218,failure to Establish Containment Integrity (Closure) Prior to Fuel Movement Was Noted.Caused by Failure to Identify & Include Condensate Pot Vent in Appropriate Valve Lineup.Valves identified.W/980320 Ltr ML18106A4031998-03-20020 March 1998 LER 98-006-00:on 980221,ESF Actuation of 11 & 12 Auxiliary Feedwater Pumps Occurred.Caused by Human Error.Operators Promptly Established Feedwater to All SG & Restored Proper Water levels.W/980320 Ltr 1999-08-26
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217A9931999-09-30030 September 1999 NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data ML18107A5581999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Salem,Unit 2.With 991014 Ltr ML18107A5571999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Salem,Unit 1.With 991014 Ltr ML18107A5301999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Salem,Unit 2.With 990913 Ltr ML18107A5311999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Salem,Unit 1.With 990913 ML18107A5031999-08-26026 August 1999 LER 99-006-00:on 990729,determined That SG Blowdown RMs Setpoint Was non-conservative.Caused by Inadequate ACs for Incorporating Original Plant Licensing Data Into Plant Procedures.Blowdown Will Be Restricted.With 990826 Ltr ML18107A5201999-08-12012 August 1999 Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#9) Second Interval,Second Period, First Outage (96RF). ML18107A4811999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Salem,Unit 1.With 990813 Ltr ML18107A4821999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Salem,Unit 2.With 990813 Ltr ML18107A4691999-07-28028 July 1999 LER 99-008-00:on 990714,determined That Limit Switch Cables Were Subject to Multiple Hot Shorts in Same Fire Area.Caused by Inadequate Original Post Fire Safe Shutdown Analysis.All Limit Switch Cables for MOVs Were Reviewed.With 990728 Ltr ML18107A4441999-07-0606 July 1999 LER 99-007-00:on 990605,surveillance for Quadrant Power Tilt Ratio (QPTR) Was Missed.Caused by Human Error.Qptr Calculation Was Performed & Personnel Involved Have Been Held Accountable IAW Pse&G Policies.With 990706 Ltr ML18107A4211999-07-0202 July 1999 LER 99-005-00:on 990605,11 Containment Declared Inoperable. Caused by Valves 11SW72 & 11SW223 Both Leaking.Procedure S1.OP-ST.SW-0010(Q) Was Enhanced to Provide Specific Instructions to Ensure Proper Sequencing.With 990702 Ltr ML18107A4331999-07-0101 July 1999 LER 99-002-01:on 990405,determined That 2SA118 Failed as Found Leakrate Test.Caused by Foreign Matl Found in 2SA118 valve.2SA118 Valve Was Cycled Several Times & Seat Area Was Air Blown in Order to Displace Foreign Matl.With 990701 Ltr ML18107A4321999-07-0101 July 1999 LER 99-006-01:on 990501,determined That There Was No Flow in One of Four Injection Legs.Caused by Sticking of Valve in Safety Injection Discharge Line to 21 Cold Leg.Valve Was Cut Out of Sys & Replaced.With 990701 Ltr ML18107A5211999-07-0101 July 1999 Rev 0 to Sgs Unit 2 ISI RFO Exam Results (S2RFO#10) Second Interval,Second Period,Second Outage (99RF). ML18107A4351999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Salem,Unit 1.With 990713 Ltr ML18107A4341999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Salem,Unit 2.With 990713 Ltr ML20196H8621999-06-30030 June 1999 NRC Regulatory Assessment & Oversight Pilot Program, Performance Indicator Data, June 1999 Rept ML18107A3951999-06-17017 June 1999 LER 99-004-00:on 990520,reactor Tripped from 100% Power,Due to Negative Flux Trip Signal from Nuclear Instrumentation. Cause Has Not Been Determined.Discoloration Was Identified on One of Penetrations.With 990617 Ltr ML18107A3661999-06-0909 June 1999 LER 99-003-00:on 990513,unplanned Entry Into TS 3.0.3 Was Made.Caused by Human error.Re-positioned Creacs Supply Fan Selector Switches & Revised Procedures S1 & S2.OP-ST.SSP-0001(Q).With 990609 Ltr ML18107A3551999-06-0202 June 1999 LER 99-005-00:on 990504,failure to Meet TS Action Statement Requirements for High Oxygen Concentration in Waste Gas Holdup Sys Occurred.Caused by Inability of Operators. Existing Procedures Will Be Evaluated.With 990602 Ltr ML18107A3441999-06-0101 June 1999 Interim Part 21 Rept Re Premature Over Voltage Protection Actuation in Circuit Specific Application in Dc Power Supply.Testing & Evaluation Activities Will Be Completed on 990716 ML18107A3541999-06-0101 June 1999 LER 99-006-00:on 990501,HHSI Flow Balance Discrepancy Was Noted During Surveillance.Caused by Sticking of Check Valve in SI Discharge Line to 21 Cold Leg.Valve 21SJ17,was Cut Out of Sys & Replaced.With 990601 Ltr ML18107A3681999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 1.With 990611 Ltr ML18107A3721999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Salem Generating Station,Unit 2.With 990611 Ltr ML18107A2931999-05-12012 May 1999 LER 99-002-00:on 990413,determined That Number 12 Auxiliary Bldg Exhaust Fan Was Rotating Backwards.Caused by mis-wiring of Motor Due to Human Error by Maint technician.Mis-wiring Was Corrected & Fan Was Returned to Svc.With 990512 Ltr ML18107A2781999-05-10010 May 1999 LER 99-004-00:on 990411,automatic Actuation of ESF Occurred During Reactor Vessel Head Removal in Support of Refueling Operations.Caused by High Radiation Condition.Containment Atmosphere Was Monitored.With 990505 Ltr ML18107A2791999-05-0404 May 1999 LER 99-003-00:on 990406,all Salem Unit 2 Chillers Rendered Inoperable.Caused by Human Error.Lessons Learned from Event Were Communicated to All Operators by Including Them in Night Orders.With 990504 Ltr ML18107A2741999-05-0303 May 1999 LER 99-002-00:on 990405,determined That Containment Isolation Valve Failed as Found Leakrate Test.Caused by Foreign Matl Blocking Valves from Closing.Check Valve Mechanically Agitated.With 990504 Ltr ML18107A3711999-04-30030 April 1999 Corrected Monthly Operating Rept for Apr 1999 for Salem Generating Station,Unit 1 ML18107A3151999-04-30030 April 1999 Submittal-Only Screening Review of Salem Generating Station Individual Plant Exam for External Events (Seismic Portion), Rev 1 ML18107A2991999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Salem Unit 1.With 990514 Ltr ML18107A2971999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Salem Unit 2.With 990514 Ltr ML18107A2351999-04-23023 April 1999 LER 99-001-00:on 990330,MSSV Failed Lift Set Test.Caused by Setpoint Variance Which Is Result of Aging.Valves Were Adjusted & Retested to Ensure TS Tolerance.With 990423 Ltr ML18107A2881999-04-0707 April 1999 Rev 0 to NFS-0174, COLR for Salem Unit 2 Cycle 11. ML18107A1821999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Salem,Unit 1.With 990414 Ltr ML18107A1831999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Salem,Unit 2.With 990414 Ltr ML18106B1471999-03-29029 March 1999 LER 99-001-00:on 990228,reactor Scram Was Noted as Result of Turbine Trip.Caused by Operator Error.Lesson Plans Revised to Explicitly Demonstrate Manner in Which Valve Functions. with 990329 Ltr ML18106B1021999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Salem Unit 2.With 990315 Ltr ML18106B1011999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Salem Unit 1.With 990315 Ltr ML18106B0931999-02-25025 February 1999 Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Caused by Crack Due to Improper Location of Heated Bar.Only One Part Out of 7396 Pieces in Forging Lot Was Found to Be Cracked.Affected Util,Notified ML18106B0701999-02-16016 February 1999 LER 98-015-00:on 981208,inadvertent Discharge Through RHR Relief Valve During Startup Was Noted.Caused by Operator Performing Too Many Tasks Simultaneously.Appropriate Actions Have Been Taken IAW Policies & Procedures.With 990216 Ltr ML18106B0551999-02-0101 February 1999 Part 21 Rept Re Possible Matl Defect in Swagelok Pipe Fitting Tee,Part Number SS-6-T.Defect Is Crack in Center of Forging.Analysis of Part Is Continuing & Further Details Will Be Provided IAW Ncr Timetables.Drawing of Part,Encl ML18106B0561999-01-31031 January 1999 Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 2.With 990212 Ltr ML18106B0571999-01-31031 January 1999 Monthly Operating Rept for Jan 1999 for Salem Generating Station,Unit 1.With 990212 Ltr ML20205P1671999-01-31031 January 1999 a POST-PLUME Phase, Federal Participation Exercise ML18106B0441999-01-29029 January 1999 Part 21 Rept Re Possible Defect in Swagelok Pipe Fitting Tee Part Number SS-6-T.Caused by Crack in Center of Forging. Continuing Analysis of Part & Will Provide Details in Acoordance with NRC Timetables ML18106B0491999-01-28028 January 1999 LER 98-007-01:on 980730,reactor Coolant Instrument Line through-wall Leak Was Noted.Caused by Transgranular Stress Corrosion Cracking.Replaced Affected Tubing.With 990128 Ltr ML18106B0401999-01-18018 January 1999 LER 98-016-00:on 981219,ECCS Leakage Was Outside of Design Value.Caused by Leakage Past Seat of 21RH34 Manual Drain. Valve 21RH34 Was Reseated.With 990118 Ltr ML18106B0251998-12-31031 December 1998 Monthly Operating Rept for Dec 1998 for Salem Unit 2.With 990115 Ltr 1999-09-30
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- 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
- 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)
- 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