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| : c. A Vondra General Manager - | | : c. A Vondra General Manager - |
| Salem Operations MJP:pc Distribution | | Salem Operations MJP:pc Distribution |
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| .* ~. ,. t ' : '* ~- .. j 9207200055 920709 95-2189 (lOMJ 12-89 PDR ADOCK 05000272 S PDR | | .* ~. ,. t ' : '* ~- .. j 9207200055 920709 95-2189 (lOMJ 12-89 PDR ADOCK 05000272 S PDR |
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| EVENT DATE 151 LER NUMBER 16) REPORT DATE (7) OTHER FACILITIES INVOLVED (8) | | EVENT DATE 151 LER NUMBER 16) REPORT DATE (7) OTHER FACILITIES INVOLVED (8) |
| MONTH DAY YEAR YEAR !':::::::::: SEQUENTIAL!::;::::::: REVISION MONTH DAY YEAR FACILITY NAMES DOCKET NUMBERISI 1::::::::::: NUMBER ::;:;:::;:;NUMBER Salem Unit 2 o 1s101010131111 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR §:(Check one or more of the following) (111 OPERATING MODE (91 l 20.402(bl | | MONTH DAY YEAR YEAR !':::::::::: SEQUENTIAL!::;::::::: REVISION MONTH DAY YEAR FACILITY NAMES DOCKET NUMBERISI 1::::::::::: NUMBER ::;:;:::;:;NUMBER Salem Unit 2 o 1s101010131111 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR §:(Check one or more of the following) (111 OPERATING MODE (91 l 20.402(bl |
| ,____ 20.405(cl | | ,____ 20.405(cl 50.73(1)(2llivl |
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| ,__ 73.71lbl POWER LEVEL | | ,__ 73.71lbl POWER LEVEL |
| ,__ 20.406(*111llil | | ,__ 20.406(*111llil |
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| relay setpoints (90%) would have on Vital Bus motors and loads. For all scenarios, the undervoltage relays would perform their design function and provide adequate protection to Vital Bus motors and loads. The analysis consi~ered several .scenarios that could result in.low voltage at the 4KV Vital Busses; however, those situations were highly improbable during this* period since the 500 KV grid voltage was 108% of 500 KV and all step down transformers equipped with load tap changers were operable. | | relay setpoints (90%) would have on Vital Bus motors and loads. For all scenarios, the undervoltage relays would perform their design function and provide adequate protection to Vital Bus motors and loads. The analysis consi~ered several .scenarios that could result in.low voltage at the 4KV Vital Busses; however, those situations were highly improbable during this* period since the 500 KV grid voltage was 108% of 500 KV and all step down transformers equipped with load tap changers were operable. |
| Therefore, based on the above analysis, tnis event did not affect the health or safety of the public. However, since the Technical Specification requirement for the undervoltage relay setpoint was not met, this event is reportable to the commission in accordance with | | Therefore, based on the above analysis, tnis event did not affect the health or safety of the public. However, since the Technical Specification requirement for the undervoltage relay setpoint was not met, this event is reportable to the commission in accordance with |
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| LICENSEE. EVENT REPORT (LER) TEXT CONTINUATION_ | | LICENSEE. EVENT REPORT (LER) TEXT CONTINUATION_ |
| Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-017-01 _5 of 5 ANALYSIS OF OCCURRENCE: (cont'd) | | Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-017-01 _5 of 5 ANALYSIS OF OCCURRENCE: (cont'd) |
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| For specific details as to the corrective actions taken which address the relay's design inadequacy, refer to LER 311/91-008-01. I As indicated previously, the new relay test procedures are unit and bus specific. The new test procedures: 1} include a test equipmen_t connection diagram for each type of relay test; 2) use a variable resistor network to provide 0.01 VAC input voltage increments; 3} | | For specific details as to the corrective actions taken which address the relay's design inadequacy, refer to LER 311/91-008-01. I As indicated previously, the new relay test procedures are unit and bus specific. The new test procedures: 1} include a test equipmen_t connection diagram for each type of relay test; 2) use a variable resistor network to provide 0.01 VAC input voltage increments; 3} |
| increase the minimum administrative trip setpoint from 108.75 VAC to 108.90 VAC; and 4) measure relay input voltage at the relay terminals. Additional procedure enhancements have been made to address other human factor and test methodology concerns found during System Engineering's inyestigation. | | increase the minimum administrative trip setpoint from 108.75 VAC to 108.90 VAC; and 4) measure relay input voltage at the relay terminals. Additional procedure enhancements have been made to address other human factor and test methodology concerns found during System Engineering's inyestigation. |
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| - General Manager - | | - General Manager - |
| Salem Operations MJP:pc SORC Mtg. 92-076}} | | Salem Operations MJP:pc SORC Mtg. 92-076}} |
Similar Documents at Salem |
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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] |
Text
PS~G Public Service Electric and Gas Company P.O. Box 236 Hancocks Bridge, New Jersey 08038 Salem Generating Station July 9, 1992
- 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 91-017-01 This Licensee Event Report supplement is being submitted pursuant to the requirements of the Code of Federal Regulations 10CFR 50.73. The Apparent Cause of Occurrence and Corrective Action sections have been modified based upon completed Engineering investigations.
Sincerely yours, c/~I t:J~.!/~ffi J,(J_
- c. A Vondra General Manager -
Salem Operations MJP:pc Distribution
.* ~. ,. t ' : '* ~- .. j 9207200055 920709 95-2189 (lOMJ 12-89 PDR ADOCK 05000272 S PDR
NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION 16-89) APPROVED OMB NO. 3150*0104 EXPIRES: 4/30/92 ESTIMATED BURDEN PER RESPONSE TO COMPLY WTH THIS INFORMATION COLLECTION REOUEST: 50.0 HRS. FORWARD LICENSEE EVENT REPORT (LERI COMMENTS REGARDING BURDEN ESTIMATE TO THE RECORDS AND REPORTS MANAGEMENT BRANCH IP*530). U.S. NUCLEAR REGULATORY COMMISSION. WASHINGTON.DC 20555. AND TO THE PAPERWORK REDUCTION PROJECT (31~-0104). OFFICE OF MANAGEMENT AND BUDGET. WASHINGTON. DC 20503.
FACILITY NAME (11 DOCKET NUMBER (2) I *PAGE 131 TITLE (41 -
n,..,; +- i Io I 5 Io Io I O I 21 7 12 1 OF O 15 4~V Vital Bµs UV Relay Setpo~nts Found Below Minimum Tech. Spec. A~lowable V~lu~
EVENT DATE 151 LER NUMBER 16) REPORT DATE (7) OTHER FACILITIES INVOLVED (8)
MONTH DAY YEAR YEAR !':::::::::: SEQUENTIAL!::;::::::: REVISION MONTH DAY YEAR FACILITY NAMES DOCKET NUMBERISI 1::::::::::: NUMBER ::;:;:::;:;NUMBER Salem Unit 2 o 1s101010131111 THIS REPORT IS SUBMITTED PURSUANT TO THE R~QUIREMENTS OF 10 CFR §:(Check one or more of the following) (111 OPERATING MODE (91 l 20.402(bl
,____ 20.405(cl 50.73(1)(2llivl
,__ 73.71lbl POWER LEVEL
,__ 20.406(*111llil
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- 50.73(1112llvl
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-- 50,731oll2ll~iiillAI 50.7311112llviiil (Bl 50.73(1)(211*1 366A)
LICENSEE CONTACT FOR THIS LER (121 NAME TELEPHONE NUMBER AREA CODE M. J. Pollack - LER Coordinator COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT 113)
- \<::::::::::::::::: '.*'**'. .. ***;*.*;;*:**:-:-:*: *'.*:
MANUFAC* REPORT AB LE :::.;:;:;:;:::;: ::::::::: MANUFAC* REPORTABLE .*.- .-.-*.* .. -.* -.*:
CAUSE SYSTEM COMPONENT TURER TO NPRDS -:-:-:*:::-::::::::::::::: CAUSE SYSTEM COMPONENT TURER TO NPRDS *.-.
.:-::::::::::::::::::::::::::: f:*::::;:;::;:; *.*; *.*. .;.. ;.
(:::: : : : :)})( -r-------t---r--------t+/-+/-+/-ettf:@1 .... .... *:*
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SUPPLEMENTAL REPORT EXPECTED 1141 MONTH DAY YEAR EXPECTED n YES (If yes. complete EXPECTED SUBMISSION DATE!
SUBMISSION DATE 1151
,. I I ABSTRACT (Limir to 1400 sceces, i.e .. accroximsrely fifteen single-scace typewritten lines) (16)
On 4/13/91, the 91.6% sustained undervoltage relay's minimum drop out voltage, for all 3 Vital Busses, ~ere found to be below the Technical Specification minimum allowable value of 91%. This was discovered during Technical Specification Surveillance 4.3.2.1.1 testing which requires monthly testing of undervoltage relay setpoints. New procedures
{Sl. MD-FT. 4KV-0001 (Q) ( 0002 or 0003) , "ESFAS Instrumentation Monthly Functional Test-lA {lB or lC) 4KV Vital Bus Under Voltage") were being used (first use) to support the surveillance testing. The surveillance test was last performed on 1/9/91 using procedure M3T, "Undervoltage and Underfrequency Trip and Time Response Surveillance Test". It had not been performed since 1/9/91 due to ninth refueling outage activities (operability required only in Modes 1, 2, and 3). The causal factors of the setpoint variance are relay design inadequacy and procedure inadequacy. Special relay tests show that the relay circuitry is influenced by the amount/type of harmonics present in the external test signal; the relay trip/reset setpoints change on subsequent checks when the test signal contains a different range of harmonics/noise plus the relay's allowable design setpoint drift. For additional root cause and corrective action details refer to LER 311/91-008-01. *Contributing factors to the cause of this event are test equipment inaccuracies and test methodology. Procedure enhancements have been made to address human factor and test methodology concerns found during System Engineering's investigation.
NRC Form 366 (6-891
LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-017-01 2 of 5 PLANT AND SYSTEM IDENTIFICATION:
Westinghouse - Pressurized Water Reactor Energy Industry Identification System (EIIS) codes are identified in
. the text as {xx}.
IDENTIFICAT.ION OF OCCURRENCE:
The Vital Bus 91.6%*undervoltage relay setpoints (all three busses) were found below the minimum Technical Specification allowable value Event Date: 1/9/91 Discovery Date: 4/13/91 Report Date: 7/9/92 This report was initiated by Incident Report Nos.91-265, 91-266, and 91-267.
CONDITIONS PRIOR TO OCCURRENCE:
M~ge 4 (Hot Standby)
- 9. Refueling/Maintenance Outage - Plant heat up in progress (outage drawing to a close)
DESCRIPTION OF OCCURRENCE:
On April 13, 1991, at 1430, 1700 and 1950 hours0.0226 days <br />0.542 hours <br />0.00322 weeks <br />7.41975e-4 months <br /> (respectively for each Vital Bus), the 91.6% sustained undervoltage relay's minimum drop out trip setp6int voltage, for all three (3) Vital Busses, was found to be below the Technical Spe.cif ication minimum allowable value of 91%. The average trip setpoint was 107.69 VAC (90.3%) and the average reset setpoint was 108.68 VAC (91.4%). This was discovered during monthly Technical Specification Surveillance 4.3.2.1.1 testing of undervoltage relay setpoints. This testing was not performed during the ninth refueling outage due to system constraints (also, mod~ applicability is modes 1, 2, and 3). New procedures Sl.MD-FT.4KV-OOOl(Q) (0002 or 0003), "ESFAS Instrumentation Monthly Functional Test-lA (lB or lC) 4KV Vital Bus Under Voltage") were being used (first use) for the testing.
The surveillance test was last performed on January 9, 1991, using procedure M3T, "Undervoltage and Underfrequency Trip and Time Response Surveillance Test".
- The as-found condition of the Vit~l Bus relays potentially placed the Unit outside its design basis. To be conservative, the Nuclear Regulatory Commission was notified of this event on April 14, 1991, at 1800 hours0.0208 days <br />0.5 hours <br />0.00298 weeks <br />6.849e-4 months <br /> in accordance with Code of Federal Regulations 10CFR 5 0. 7 2 ( b) ( 1) (ii') ( B) .
LICENSEE EVENT REPORT (LER) .* TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER. PAGE Unit 1 5000272 91-017-01 3 of 5 APPARENT CAUSE OF OCCURRENCE:
The causal factors of the setpoint variance are relay design inadequacy and procedure inadequacy. Special relay tests show that the relay circuitry is influenced by the amount/type of harmonics present in the external test signal; the relay trip/reset setpoints change on subsequent checks when the test signal contains a different amount/type of harmonics/noise plus the relay's allowable design setpoint drift. For additional details refer to LER 311/91-008-01~
Contributing factors, to the cause of this event, include test equipment inaccuracies and test methodology. Procedure M3T did not define the different test equipment setups or specify*the test equipment required to support each type of undervoltage or underfrequency relay test. As explained below, personnel error did not contribute to this.event as.was the case for a similar Unit 2 event (reference LER 311/91-005-01). The Unit 1 calibration (January 9, 1991) had taken place prior to the Unit 2 event.
When the relay's trip/reset setpoints were checked on January 9, 1991, the variable power supply's output voltage was varied using thumb-wheel switches. These switches have increments of 0.1 VAC.
Although the procedure required verification of settings using a DVM (good to 0.01 VAC), the recorded data indicated that the as~found trip/reset setpoints were determined by reading the thumb-wheel switch settings.
When the relay's trip/reset setpoints were checked on April 13, 1991*
in accordance with new procedures, the thumb-wheel switches were set to 115 VAC and relay input voltage was adjusted using a variable resistor network. The variable resistor network provided 0.01 VAC increments instead of the previous thumb-whee*1 method of O. 1 VAC.
Since the trip/reset setpoints indicated. on the DVM were more accurate, this method verified that additional variable power supply calibration and thumb-wheel switch tolerances contributed to the error.
When the as-found setpoint (on January 9, 1991) was not within M3T's administra.tive setpoint span, the relay was recalibrated as follows:
the thumb-wheel switches were set to 108.9 VAC and the relay's "Low Trip" potentiometer was adjusted until the red LED illuminated. Then the thumb-wheel switches were set to 110.0 VAC and the relay's "Low Trip Deadband" potentiometer was adjusted until the red LED extinguished. The thumb-wheel switches were changed between the required trip and reset voltage to verify proper setpoint actuation.
Since M3T's test methodology added the variable power supply's calibration tolerance to the relay's normal monthly setpoint drift, the relay setpoint was set at a lower voltage than M3T's
- administrative setpoint spans of 108.75 VAC - 109.05 VAC and 109.85 VAC - 110.15 VAC, respectively.
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LICENSEE EVENT REPORT (LER) TEXT CONTINUATION Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-017-01 4 of 5 APPARENT CAUSE OF OCCURRENCE: (cont'd)
On April 22, 1991, a special test was performed using the January 9,*
1991 variable power supply, the other variable power supply used on April 13, 1991, and a spare 91.6% relay. Test results showed that when the relay trip/reset setpoints were set using the thumb-wheel switches, the as-found setpoints using the DVM and variable resistor network were 0.53 VAC and 0.62 VAC lower respectively. When either va.riable power supply was used to set relay setpoints using the new procedure method, the as-found setpoints were within 0.01 VAC and 0.02 VAC. Based on the worst case.relay drift found during three (3) weekly tests performed on Unit 2 relays (0-.56 VAC), DVM calibration error (0.21), and the special test results above (0.53 VAC), the total trip setpoint drift on April 13, 1991 col,lld have been as much as 1.30 VAC lower compared to the April 13, 1991 average Unit 1 as-found trip setpoint of 1.21 VAC.
ANALYSIS OF OCCURRENCE:
The Vital Bus (lE) 70% Loss of Voltage, 91.6% Sustained Degraded Voltage, and 35% Vital Bus Undervoltage Bus Transfer relays monitor the Vital Bus voltage via 35:1 ratio potential transformers (PTs).
Each Vital Bus contains one 70% IAV relay three 91.6% Rochester Instrument Systems model PR-2035.Pl-Tl-O relays, and one 35% ITE-27H relay. The 70% and 91.6% relays provide input to the Safeguard Equipment Control (SEC) Systems so the SEC can determine Vital Bus emergency loading requirements.
On Aprii 13, 1991, all nine (9) 91.6% relays' as-found trip setpoints were less than the minimum Technical Specification allowable value (91%). The relays were then recalibrated to the 91.6% value specified in the applicable Surveillance Test Procedure Sl. MD-FT. 4KV-0001 (Q) ( 0002 or 0003) . *Recalibration was completed for each relay of each Vital Bus, at the time the out of specification reading was found. All three (3) Vital Busses relays (total of nine relays) were recalibrated on April 13, 1991.
An engineering analysis (conducted in support of Salem Unit 2 LER 311/91-005-00) previously determined the impact low as-found 91.6%
relay setpoints (90%) would have on Vital Bus motors and loads. For all scenarios, the undervoltage relays would perform their design function and provide adequate protection to Vital Bus motors and loads. The analysis consi~ered several .scenarios that could result in.low voltage at the 4KV Vital Busses; however, those situations were highly improbable during this* period since the 500 KV grid voltage was 108% of 500 KV and all step down transformers equipped with load tap changers were operable.
Therefore, based on the above analysis, tnis event did not affect the health or safety of the public. However, since the Technical Specification requirement for the undervoltage relay setpoint was not met, this event is reportable to the commission in accordance with
LICENSEE. EVENT REPORT (LER) TEXT CONTINUATION_
Salem Generating Station DOCKET NUMBER LER NUMBER PAGE Unit 1 5000272 91-017-01 _5 of 5 ANALYSIS OF OCCURRENCE: (cont'd)
Code of Federal Regulations 10CFR 50.73(a) (2) (i} (B).
CORRECTIVE ACTION:
For specific details as to the corrective actions taken which address the relay's design inadequacy, refer to LER 311/91-008-01. I As indicated previously, the new relay test procedures are unit and bus specific. The new test procedures: 1} include a test equipmen_t connection diagram for each type of relay test; 2) use a variable resistor network to provide 0.01 VAC input voltage increments; 3}
increase the minimum administrative trip setpoint from 108.75 VAC to 108.90 VAC; and 4) measure relay input voltage at the relay terminals. Additional procedure enhancements have been made to address other human factor and test methodology concerns found during System Engineering's inyestigation.
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- General Manager -
Salem Operations MJP:pc SORC Mtg.92-076