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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
[Table view] |
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I.. e .e QPS~
- .Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038
~alem Generating Station
{\,
June 111 1992
- u. s. Nuclear Regulatory Commission Document Control Desk Washington, tic- *_ .20555
Dear Sir:
SALEM GENERATING STATION LICENSE NO~ DPR-70 DOCKET NO. 50-272 UNIT .NO. 1 *
. SUPPLEMENTAL LICENSEE EVENT REPORT 91-009-02 This Supplemental Licensee Event Report is being submitted pursuant to 10CFR50.73. This supplement clarifies the assessment of the event significance based upon completed engineering investigations and corrects editorial mistakes contained in the prior supplement.
It is also being submitted as per NRC Inspection Report 272/92-03.
Sincere y yours,
~~.
. A. Vondra Gener.al Manager -
Salem Operations MJP:pc Distribution.
T !'1P r=n:.:>rov Penr1ic 920624001'0 9206!'1'*'
PDR ADOCK 05000272 95-2189 (10M) 12-89 S PDR
NRC FORM366 U.S. NUCLEAR REGULATORY COMMISSION (6-89) APPROVED OMB NO. 3150-0104 EXPIRES: 4/30/92 ESTIMATED BURDEN PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REQUEST: 50.0 HAS. FORWARD LICENSEE EVENT REPORT (LER) COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS.
AND REPORTS MANAGEMENT BRANCH (P-530). U.S. NUCLEAR REGULATORY COMMISSION. WASHINGTON. DC 20555. AND TO THE PAPERWORK REDUCTION PROJECT (3150-0104). OFFICE OF MANAGEMENT AND BUDGET. WASHINGTON. DC 20503.
FACILITY NAME (1) DOCKET NUMBER (2) I PAGE 131 Salem Generating Station - Unit 1 0 I 5 I 0*1 0 I 0 I 21 7 12 1 OFI 0I 7 TITLE (4) 1High*Ene£gy Line Break Concern Between Mechanical Pene. Area & Chiller Room EVENT DATE (5) LEA NUMBER (61 REPORT DATE (71 OTHER FACILITIES INVQLVE_I;> (8)
MONTH DAY YEAR YEAR rm SE~~~~~~L {\ ~~~'l/i~ MONTH DAY YEAR FACILITY*NAMES DOCKET NUMBER(Sl Salem Unit i OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE Rl:.QUIREMENTS OF 10 CFR §: (Cht1Ck on* or moro of th* following) 111)
MODE 'Ill : J. _:20.402lb).. **20.4051ci 50.73(i)f2lfiv) 73.71lbl 1--
POWER *1 . . 20.40li(o)f1)(il *-150.3111clf1 I x
......_ &0.73l*H211¥i 73.71lcl L~~~L 110 I 0 ,..._ 20.4051o)f1)(1il 50.3111clf2) ......_ 50.73l*ll2)fvii) OTHER (Specify in Abstr*ct below end in Tttxr, NRC Form llillllllll=
20.40lllo)f1 )(Ill). 60.7310)(2)(1) &0.73loll2HviillfAI 366AI 1--- ......_
20.405(0)(1 )(lvl 50,731*1f2)fiil 50.73(ol(2)(viiilfBI
......_ 1--
20.4051*Jf1lM 60.73l*lf21 fiiil 60.73lolf2ll*I LICENSEE CONTACT FOR THIS LER 1121 NAME TELEPHONE NUMBER AREA CODE
- M.. *J. *Pollack LER Coordinator 0
6 D i9 . 31 3 19. I ~I 2 IO *r 21 2:
COMPLETE ONE LINE FOR EACH COMPONENT FAILUR E DESCRIBED IN THIS *REPORT 1131 CAUSE SYSTEM COMPONENT MANUFAC- .MANUFAC*
TURER TUR ER I I I I I I I .. I I I I.
I I I I I I I I I l I I I I SUPPLEMENTAL REPORT EXPECTED 114) MONTH DAY YEAR EXPECTED n YES (If Y*S. compl*t* EXPECTED SUBMISSION DATE/ -Fxl ABSTRACT (Limit to 1400 spaces, i.e., approximately fifttHJn single-space typewritten lintJs) (16)
NO SUBMISSION DATE (151 l I I On 2/15/91, a Probabilistic Risk Assessment of a mi~sing portion of the Unit*1 seismic gap seal, between the Inboard Mechanical Penetration Area and the Chiller. Room, showed a calculated change in core damage frequency for Salem Unit 1 from 5.BE-5/Yr to 8.5E-5/Yr (assuming a worst case Main Steamline break in the Inboard* Mechanical Penetration Area). Assessment shows that the health and safety of the public was not affected due to available mitigating capabilities. A similar Unit 2 seismic gap section had been found unsealed prior to discovery of the Unit 1 concern. The root cause of both Units' seismic gap seal(s) not being fully installed is "Design, Manufacturing, Construction/Installation" error (per NUREG 1022). The subject Unit 2 seismic gap section was sealed on 2/22/91.
The missing portion of the Unit 1 seismic gap seal was installed on 4/12/91. The remaining seismic gap areas (both Units) have been
.. _in.spected and. those seals requiring ..repaiZ'. have bee11 repaired.
--~dmi:riistrative controls for.Appendix R penetrati9ns haye been e}!':tended to*
include. HEBA barrier impairments.
NRC Form 366 .(6-891
LICENSEE EVENT REPORT {LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-009-02 2 of 7 PLANT AND SYSTEM IDENTIFICATION:
Westinghouse -. Pressurized*water Reaq1:9r
- _ ,c- .: Energy .Industry. :;;rgentificat+/-on-~system * (EifS}:-.~codes *.are . -identified.;.in the text as {xx}
IDENTIFICATION OF OCCURRENCE:
- Concern for effects of- a High---Energy Line Break *with a missing barrier between the mechanical and Chiller Room Event Date: 12/20/90 Discovery Date: 2/15/91*
Report Date: 6/11/92 Thi_s .report was .initiated by Incident Report No.91-101.
CONDITIONS PRIOR TO OCCURRENCE:
December 20, 1990: Mode 1 - Reactor Power 100%
February a, 1991: Mode 1 - Unit shutdown in progress in support of ninth refueling outage preparation
- DESCRIPTION OF OCCURRENCE:
on December 20, 1990, during normal power operation of Unit 1, a Penetration Seal Review Group {PSRG) walkdown of Appendix R fire barriers identified an unsealed portion of a HEBA barrier between the
- Inboard Mechanical Penetration Area and the Chiller Room, _at e'ievation-120'. The 6" by 5.5' opening was located where the*concrete slab above the Chiller Room approaches the outside wall of the Containment. The slab -is a nominal distance of 6" from the Containment wall providing a seismic gap. The Chiller Room {Air-Handling Area) is atmospherically open to the Electrical Penetration Area {el .. 100') . The seismic gap seal at this location would prevent the steam environment from a postulated Main Steamline Break {MSLB) in the Inboard Mechanical Penetration Area from entering the mild environment of .the Chiller Room and Electrical Penetration Area. The PSRG initiated a work order to seal the opening. _ I A similar condition was identified previously on Unit No. 2 in May,_
1990. Deficiency Report (DR) NFP~90-002 identified 104 penetrations
. witb i_mpa.j.red seals in .f fre *__barriers that are also HEBA barrier~.
This number included one missing portion of the Unit 2 seismic-gap .
..seal- similar-to the Unit -1 opening described-above. These impairments were not adequately evaluated against HEBA considerations.
On November 1, 1990, during the.SORC review of Design Change Package (DCP) No. 1SC-2183, which included two of the penetration seals identified in DR NFP-90-002, a concern was raised as to the adequacy of evaluations for openings in HEBA barriers. Investigation resulted I.
-- ...... ~,...,,_., ....... ~"'h1&** --.;;-*' ..r*~. "' r' **.;:-; .*;;,----*- *- ..... ~~~---""'-"-*- ---* ._. I
\
. LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER *PAGE Unit 1 5000272 .91-009-02 3 of 7
... DESCRIPTION OF OCCURRENCE: Ccont'dl in the issuance of six ( 6) _Discrepancy .*~EValuation. For.ms (.DEFs) ., one of
- - . * -. --which addressed: the .*unit.. 2***seislliic ~gap openinCJ ~- .:This DEF.,,.
- - -DES--9o--;0:1573, :erroneously. concluded .that no equipment -was aj: *risk whose failure would result in increased C-ore damage_f.requency *. This occurred because it was not.recognized by the engineer making the
- assessment .that. the "Air Handling Area" contained vital motor control I
centers (MCCs). '
Following the Unit 1 finding in December 1990, DEF No. DES 91-00066 was initiated (on February 8, 1991} requesting. an .evaluation of the safety significance of the finding and a Probabilistic Risk Assessment (PRA) analysis. on February 15, 1991, the PRA assessment was completed. This assessment sh.owed a calculated change in core damage frequency for Salem Unit 1 of 2.67E-5/Yr. This raises the core damage fr.equency from s.:sE--5/Yr to 8*.5E~5/Yr.
Due to the potential for the identified condition to challenge the
....operability ....of. ~saf.ety .related .. equipment, the Nuclear. Regulatory Commission (NRC) was notified on February 15, 1991, at 1743 hours0.0202 days <br />0.484 hours <br />0.00288 weeks <br />6.632115e-4 months <br /> as required by Code of Federal Regulations 10CFR 50.72{b) (2) (iii).
APPARENT CAUSE OF OCCURRENCE:
The root cause of the seismic gap seal(s) (both Units) not being installed is "Design, Manufacturing, Construction/Installation" error (as per NUREG 1022). The required seal(s) were not installed during plant construction (per design* prints).
ANALYSIS OF.OCCURRENCE:
The leak-tightness design basis for the seismic gap seal between the Chiller Room and the Inboard Mechanical Penetration Area is to ensure that the Chiller Room (and Electrical Penetration Area) temperature remains < 120°F. Without the seal, a postulated 1 ft 2 MSLB in the Inboard Mechanical Penetration Area (allowing steam to enter through the deficient seal) could cause (i.e., worst case sce*nario) the three
- (3) vital motor control centers (MCCs) in the Chiller Room to become inoperable.
Engineering Evaluation S-C-ZZ-MEE-0622 analyzed the effects of a MSLB*
on the MCCs in the Chiller Room. The evaluation required extensive
- .. thermal calcul_ationf:f for _modelipg the MSLB in the Inboard_ Mechanical- *
- -Penetration Area (seismic gap). Assumptions for the seismic gap
. analysis include: 1) A _pressurized Inboard Mechanical :penetration Area I
--with steam temperature reaching 375°F when blowdown ends at 10 minutes; and 2) Inlet ventilation flow to the Chiller Room as I permitted by the pressure therein.
The Salem Unit 2 seismic gap was reinspected on February 19, 1991. A portion of the seal was found to be *improperly installe.d; however,
. *e.,.., ,.
'.' ~
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER *PAGE Unit 1 5000272 91-009-02 4 of 7 ANALYSIS OF OCCURRENCE: (cont'd}
. anchored fiashing *was. in_P,iabe *.:~ 'T~ee (3). cases.of the -.seismic gap .
.. ....... --*.--..:.,_ *model~were*.:simu1ated~.,* c::a57 No.: i *cunit.:__*2) ~k!s no,credit* .. for*th7
.. ,.. ,. f.lashµig (.1.e., .cross~.secq.onal- ar.ea -of 680 in )
- 2) models partial blockage of the steam flow by the flashing- (280 in 2 ). Case No~-~-3 (Unit 1) *models the December. 20, 1990, as-found condition (400 in 2 ). .Case No. 1 yielded an internal MCC temperature of 230°F-- (worst ..case).:': -.-"!'he**MCcs.~~e*qualified 'for 96. hours.at * ** .
131°F and 90% relative humidity. The evaluation concluded that operability of the targeted safety related lE electrical equipment could riot be conclusiv~ly demonstrated due to a lack of supporting test data.
The MCCs control various ventilation and cooling equipment . including:
- 1) . Room Cc;>olers for: a) .Nos *. 11, 12 & 13 Auxiliary. Feedw'ater Pump Rooms;' b) Nos. 11 & 12 Safety.Injection Pump Rooms; .c)
Nos. 11, 12 &.13 Component Cooling Pump Rooms; d) Nos. 11 &
.. _12 ..Residual .Heat .RemovaLP.ump ~Rooms; . e) * .Nos *. 11 ,.& .12 Containment Spray Pump Room; and, f) Nos. 11, 12 & 13 Charging Pump Rooms
- 2) Fans for the: a) Nos. 11, 12 & 13-Switchgear Room Exhaust, el. 64'; b) Nos. 14, 15 & 16 SWGR Room Exhaust, el. 84'; and c) Nos. 11 and 12 Electrical Penetration Exhaust
- 3) No. 13 Chiller Condenser Water Recirculation Pump
- An engineering review of the "loss" of the.above equipment shows the most critical equipment to be the room coolers for the:
Charging Pumps - Nos. 11 and 12 charging pumps are required for high head safety injection in the mitigation of a design base accident. They are 100%*redundant of each other.
Safety Injection Pumps - both pumps (100% redundant to each other) would be affected; they would be used to mitigate the consequences of a design.base accident by providing intermediate head safety injection.*
.RHR Pumps - there are 2 pumps (100% redundant to each other) which are used :to remove residual core heat during shutdown conditions .and to* mitigate the consequences of a . de~.ign base
- accident-by providing low head safety injection.
The room coolers, .in conjunction with the once th~ough ventilation system, are designed to limit ambient temperature at vital pumping equipment. This *helps assure* long-term reliable operation of the vital equipment. Based upon PSE&G Engineering Evaluation S-C-ABV-NEE-0504E, "Engineering Evaluation on the Effect An Inoperable*
LICENSEE EVENT .REPORT (LER) TEXT CONTINUATION.
Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit*l 5000272 91-009-02. 5 of 7
.ANALYSIS OF OCCURRENCE: (cont'd)
. Room Cooler.Has on the Operability'.of. *vital';'"Pumps'1:, .. operabi1it,y of .the
.;.'. vita:l .pymps. is .affected cby-the* availcibilitj of**:associated*room
"**-*,:,coolers. : Therefor~; with :an inoperable .room -cooler, and without an*
-analysis to show otherwise, the vital pumps ... in that room are considered inoperable *
....~The .. above **Engineering . Evaluation,. among _.other conservatisms, .:assumed* -a.
heat load generated by the protracted operation of the ECCS*pumps and other electrical equipment in the Auxiliary Building. In the scenario for the HEBA in the Inboard Mechanical Penetration Area that impacts the Chiller Room through the missing seismic gap seal, the Steam Generator .(S/G) blowdown through* the break is completed and auxiliary feedwater flow to the affected S/G isolated, by Control Room operator action, in approximately ten (.10) minutes (reference UFSAR Section
... 15. 4. a .2. 2 and '!'ables 15. 4-29_ and 15. 4-30) *. The Control_ Room .* .
operators, using Emergency Operating.Procedures (EOPs),would shortly thereafter reset the safety injection signal, terminate operation of.
the -ECCS.pumps --and stabi-li-ze **Reactor Coolant. System -operating parameters. Operator action times have been adequately demonstrated.*
on.the Sa:lem simulator during training and EOP validation.
Should the above scenario include a loss of offsite power, the ECCS pumps, by design,. would run for the first twenty (20) minutes without room coolers. The room coolers are locked out (on a loss of power event) by the Safeguards Equipment Control Cabinets.
Termination of sa~ety injection provides the ability to only operate pumps necessary for normal* plant cooldown/shutdown and maintenance
- thereof. - These actions would significantly lower the heat load on .the*
Auxiliary Building Ventilation Syst.em (ABVS) *
- The ABVS operates during all postulated ac6ident scenarios (i~cluding loss of offsite
- power). Conservative calculations, which assume no room cooler operable, no condensation losses, no structural heat. sink losses, ABVS availability and all ECCS pumps running show that affected pump room temperatures stabilize at less than 180 6 F. Based on NUMARC 87-00 projections, a pump can be reasonably expected to .operate for at least four (4) hours under ambient temperature conditions of < 180°F.
Within thirty (30) minutes of the postulated steam line break, the plant would be stable and actions could be initiated to bring the p],ant to Modes (Cold Shutdown) in a controlled fashion. As
- identified above,.*the available* time for continued ECCS. pump availability is .at least four .(4) hours everi .with the pump rooms* heat rise calculation. Within the first thirty- (30} minutes,. Operations would be aware of Room Cooler failures because of Control Room indications. Operator action can be taken to mitigate a loss of the Room Coolers prior to four (4)- hours having elapsed. Therefore, had this event occurred, the health and safety of the public would not have been affected. However, this event is reportable per Code of Federal Regulations 10CFR 50.73(a) (2) (v).
.9 LICENSEE EVENT.REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-009-02 .. 6 of 7 ANALYSTS OF SUBSEQUENT HEBA BARRIER PENETRATION INSPECTIONS
--seals
- common to bo;th Appendix R and High_. Energy- Line. Break Accident - *.::: _--
-,.,- < (HEBA) barriers .(734:*:sea.1S). were inspected as .part_ of.:the -Program
- - - .Ana-lys-is Group (PAG) program. *Approximately 10% (74) -of the inspected *
- _:__-*- -- oseals were discovered to have openings_ requiring repair .* - Of these 74 seals, it was determined that 24 have no safety significance and an additional 14 have negligible .affect on-the environmental parameters
-- , , ** 0 -0f-' the *-targeted -areas. -Erigirieer.ing EValuation s-c-zz-MEE-0622
- assessed the environmental conseque~ces for some 221 penetrations including the remaining 36 impaired seals.
j As committed to in the original LER (272/91-009-00), PAG was tasked to*
inspect HEBA penetration barriers (which are not Appendix R penetration barriers) to ensure adequacy. of seals~ Results show that
'lI 113 Unit 1 penetration seals and 54 Unit 2 penetration seals required repair *. The nature of the impairments ranged from minor seal .damage to missing seals * . A DEF, DES-91-0086-,-was issued and the resulting PRA analysis showed no significant increase in core damage frequency.
Therefore, the ___ health,.and-safety .of .-the ..public was _not affected as a result of these impaired penetration seals. These penetration seals have been included in Engineering_ Evaluation S-C-ZZ-NEE-0622.
PRIOR EVENT ASSESSMENT:
The Updated Final Safety Evaluation Report (UFSAR), Section 3.6.5.10,, j_
discusses leak tight areas of the contiguous zone; however, it does not detail specific requirements for the Inboard Mechanical Penetration Area *. Engineering Field Directive No. S-C-VAR-MFD-0508'-1 (issued in 1988) addressed this area and other areas of similar concern. The Field Directive was originally* issued.in *response.to LER.
272/87-017-02 which identified a concern pertaining to leakage paths in the steam Driven Auxiliary Feedwater Pump encl9sures (for Units t
& 2). The design basis break.in the Mechanical Penetration Areas, at 78'.and 100 1 elevations and* the Pipe Alley, is in a 6 11 main steam line to the Auxiliary Feedwater Turbine Driven Pump.
Another corrective action inthe above LER was walkdown of accessible penetrations in other pipe rupture enclosures. Although this .
inspection was performed, the seismic gap penetration areas were not specifically identified in the scope of that inspection. The visual walkdown found no Unit 1 unsealed penetrations. Two (2) unsealed areas in the Unit 2 Letdown Heat Exchanger Room were identified. The
.design. break is iil a 2 11 --CVCS line and the break locatib!lS -are .. sleeved and restrained. _ .Also, Section 3. 6. 5. 10 of the UFSAR
- indicates that all steam generated by this_- assumed break .can -be. carried :away by ' the norinal ventilation exhaust. Based ori the above.discussion, it is judged that a postulated HELB will have no significant effect on equipment ?perability in the targ~t areas.
e *
.* LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER .. LER NUMBER PAGE Unit 1 5000272 91-009-02 7 of 7 CORRECTIVE ACTION:
The unsealed portion of the vertical ~'.section of the Unit 2 ~.eis~c. _gap .* * *1
- was **sealed on* November* 7, 1990. .Following the* February, 1991 ** .
- re'.""'insPection, the remainder .o'f .the Unit 2 seismic qap was* sealed on .
February 22, 19.91. **
- The missing portion of the Unit 1. se,ismic gap seal was. installeci. on
Engineering Evaluation S-C-ZZ-MEE-0622 has been completed which assessed. the operability of the Electrical Penetration Area MCCs with the*seismic gap not sealed. This evaluation concluded that operability of thermally sensitive electrical component designs such as relays, switchgear, motor control centers and control instrumentation could not be assured. However, as discussed in*the
. Analysis of occurrence Section, .this would not . have arf ected the l
.: health or safety of the public.
All Unit 1 and Unit .2 HEBA penetration .seals. have,been visually inspected and deficient seals have been repaired.
The .inspection and analysis of HEBA barrier penetrations not associated with Appendix R has been assigned to the Program Analysis Group as part of the Penetration Seal Program.
This event has been reviewed by Engineering management . . The PRA assessment engineer was counseled. The need to maintain attention. to detail and to challenge assumptions used in performing calculations was stressed.
- A 10% random sampling of DEFs (61 from a population of 605) was*
reviewed to ensure that the PRA analyses were correctly performed.
Added to this sample were an additional six (6) DEFs associated with the HEBA barrier concerns first.identified in May.1990. Results of the random sampling assessment indicate a confidence level in excess of 95%.
have General Manager -
Salem Operations MJP:pc SORC Mtg ..92-065