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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML20029E1891994-05-13013 May 1994 LER 94-007-00:on 940418,meter Lead Inadvertently Touched Adjacent Terminal Resulting in RCIC Inboard Steam Valve Closure.Caused by Personnel Error.Corrective Action:Meetings Were Held & self-assessments in progress.W/940513 Ltr ML20029D6171994-04-29029 April 1994 LER 94-005-01:on 940330,potential Use of Less Conservative pressure-temp Limit Curves Identified.Caused by Inadequate Procedural Guidance.Corrective Actions:Adverse Condition Rept initiated.W/940429 Ltr ML20029D0051994-04-28028 April 1994 LER 94-005-00:on 940404,two PCIS Group 6 RIP Valves Had Dual Open/Closed (Red/Green) Indications.Cause Was Personnel Error.Corrective Action:Individuals Involved Counseled on event.W/940428 Ltr ML20029C8491994-04-25025 April 1994 LER 94-004-00:on 940329,penetration Leakage in Excess of TS Allowable Limit During Local Leak Rate Testing Identified. Troubleshooting & Analysis of Failure Mechanism in Progress. Suppl to Rept Will Be submitted.W/940425 Ltr ML20046B5601993-07-30030 July 1993 LER 92-004-01:on 920730,RWCU Sys Isolated During Substation E7 de-energization Due to Personnel Error.Preparation of Project Plan for Development of Electrical Load List Using Plant Staff Resources underway.W/930730 Ltr ML20045G5821993-07-0808 July 1993 LER 93-003-00:on 930608,RPS MG a Tripped,Resulting in Successful ESF Actuations & Isolations Due to Defective Procedure.Voltage Adjust Potentiometer for MG a Voltage Regulator Replaced on 930617.W/930708 Ltr ML20045F5201993-07-0202 July 1993 LER 93-010-00:on 930604,hourly Fire Watch TS Surveillance Missed During Radiography Due to HP & Operations Failed to Establish Other Means of Communication W/Radiographers. W/930702 Ltr ML20045D6371993-06-30030 June 1993 LER 93-005-01:on 930214,testing of SBGT Showed That Unthrottled Flow of Single Train Would Exceed TS Rated Flow Limit of 3,330 Cfm.Caused by Design Deficiency.Existing SBGT Heaters Upgraded & Rewired ML20045D7601993-06-30030 June 1993 LER 93-008-01:on 930313,spurious ESF Actuations Occurred Due to on-site Electrical Distribution Sys Voltage Depressions. Design of cross-over Points of Transmission Lines Emanating from Plant Being reviewed.W/930624 Ltr ML20045D1531993-06-21021 June 1993 LER-93-007-00:on 930522,discovered That MSL D High Flow Trip Unit Failed Downscale Due to Personnel Error.Appropriate Operations Personnel counselled.W/930617 Ltr ML20045D5881993-06-17017 June 1993 LER 93-006-00:on 930521,HCU 06-31 Declared Inoperable When CRD Accumulator Low Pressure/High Level Alarm Received in Cr.Hcu 02-23 Inoperable at Time.Hcu 02-23 Restored to Svc & Excess Water Drained from HCU 06-31.W/930617 Ltr ML20044E5241993-05-24024 May 1993 LER 93-007-00:on 930424,discovered That Sampling of Rv Coolant Conductivity Not Performed Due to Misinterpretation of RCS Chemistry Ts.Chemistry Sampling of Rv Coolant re-established.W/930521 Ltr ML20044E5411993-05-20020 May 1993 LER 93-009-00:on 930421,found That Design of SBGTS Would Allow Operation That Would Result in Sys Damage If Containment Venting in Progress & Experience Loca.Operating Procedures 1-OP-10 & 1-OP-24 revised.W/930520 Ltr ML20044B6761993-02-22022 February 1993 LER 93-001-00:on 930121,determined That Containment Atmospheric Control Airborne Particulate & Gaseous Radioactivity Monitors Not Seismically Qualified.Suppl to Rept Will Be submitted.W/930227 Ltr ML20029A9111991-02-25025 February 1991 LER 91-001-00:on 910125,reactor Scram Occurred During Calibr of Feedwater Computer Point.Caused by Incorrect Procedure in Summary Sheet.Maint Procedures Reviewed & revised.W/910225 Ltr ML20028H7141991-01-24024 January 1991 LER 90-019-00:on 901226,isolation Signal Caused Reactor Water Cleanup Inlet Inboard Isolation Valve to Automatically Close.Caused by de-energized HPCI Isolation Relay.Riley Scam Temp Switch Units Will Be replaced.W/910124 Ltr ML20024F7461990-12-13013 December 1990 LER 90-020-00:on 901117,primary & Secondary Containment Isolation Signals Received & Standby Gas Treatment Sys auto- Started.Caused by Scan Overload on Microprocessor.Updated Microprocessor Will Be obtained.W/901213 Ltr ML20028H0421990-09-28028 September 1990 LER 90-012-00:on 900830,Unit 2 Reactor Scram Occurred During Reactor Startup.Investigation Continuing.Level Recovered W/O Need for Safety Sys Injection & Unit Designed for Level Transient from Full power.W/900928 Ltr ML20028H0431990-09-28028 September 1990 LER 90-011-00:on 900830,RWCU Sys G31 Received Leak Hi & RWCU Leak Hi Hi Annunciators Although Actual Leak Had Not Occurred.Caused by Air in Instrument 2-G31-FT-N012 Sensing Lines.Investigation to Be conducted.W/900928 Ltr ML20043G0981990-06-15015 June 1990 LER 88-001-06:on 880102,manual Reactor Protection Sys Trip Initiated Due to Decreasing Condenser Vacuum.Cause Still Undetermined.Vendor Insp Revealed Presence of Oil Base Film in Solenoid Valves.Determination Due by 900801.W/900615 Ltr ML20043G0711990-06-13013 June 1990 LER 90-005-00:on 900514,unplanned Closure of HPCI Isolation Valve Occurred During Maint Surveillance Test.Caused by Technician Placing RCIC Instead of HPCI Test Switch to Test Position.Personnel Counseled & trained.W/900613 Ltr ML20043F6291990-06-11011 June 1990 LER 90-008-00:on 900514,HPCI Sys Rendered Inoperable When Control Power Lost to Min Flow Bypass Valve to Suppression Pool.Probably Caused by Design Problem W/Ge Model CR2940 Sockets.Light Bulb & Fuse replaced.W/900611 Ltr ML20043F6181990-06-0808 June 1990 LER 90-007-00:on 900511,identified That Damper Would Fail to Close on Loss of Power to Solenoid Valve & on 900526,damper Found Approx 30 Degrees Open.Caused by Failure of Design to Include Fail Safe Damper.Damper modified.W/900608 Ltr ML20043C9001990-06-0101 June 1990 LER 90-009-00:on 900507,determined That Tech Spec 4.6.1.1 Requirements Not Met After Performing Monthly Periodic Test 2.2.4a.Caused by Inadequate Procedure.Recommended Procedure Revs to Prevent Recurrence Being evaluated.W/900601 Ltr ML20043B7971990-05-25025 May 1990 LER 90-006-00:on 900426,hydraulic Perturbation Occurred on Variable Leg of Instrumentation Used to Sense Reactor Water Level,Causing Isolation of RWCU Sys & Initiation of Standby Gas Treatment Sys.Diaphragm Assembly recalibr.W/900525 Ltr ML20043A6121990-05-11011 May 1990 LER 90-003-01:on 900312,full Group 1 Isolation Signal Received,Resulting in Automatic Closure of Msivs.Caused by Personnel Failing to Follow Procedures.Personnel Counseled & Procedure Separated Into Two tests.W/900511 Ltr ML20012E0581990-03-23023 March 1990 LER 90-002-00:on 900224,Group I Isolation Occurred When Undervoltage Relay Replaced.Caused by Lack of Recognition of Significance of Having Turbine Reset While Performing Electro Hydraulic Control evolutions.W/900323 Ltr ML20012B8071990-03-0909 March 1990 LER 90-001-00:on 900210,determined That Core Spray Loops a & B Inoperable Due to Missed Surveillance.Cause Not Stated. Investigation continuing.W/900309 Ltr ML20012A1671990-03-0202 March 1990 LER 89-013-01:on 890909,HPCI Turbine Auxiliary Oil Pump Developed Shaft Seal Leak of Approx 1 Gpm.Caused by Failure of Shaft Seal.Root Cause of Seal Failure Initiated.Pump Seal replaced.W/900302 Ltr ML20011F5541990-02-22022 February 1990 LER 90-002-00:on 900127,common Control Bldg HVAC Sys Isolated & Transferred to Recirculation Mode as Result of Spurious Actuation of Chlorine Detector.Sensor Connection checked.W/900222 Ltr ML20006E7751990-02-19019 February 1990 LER 88-001-05:on 880102,manual Reactor Protection Sys Trip Initiated Due to Decreasing Condenser Vacuum.Caused by Numerous Leaks on Main Turbine & Main Steam Reheat Interconnecting Piping.Seating Matl installed.W/900219 Ltr ML20011F5311990-02-16016 February 1990 LER 89-026-01:on 891210,common Emergency Bus E3 Unexpectedly Deenergized,Causing Standby Gas Treatment Sys Isolation & Reactor Scram Signal.Caused by Procedural Inadequacy.Isolation Reset & Power restored.W/900216 Ltr ML20006E3681990-02-0909 February 1990 LER 88-006-02:on 880219,numerous Bolt Head Failures of 5/16- Inch X 1/2-inch Silicon Bronze Carriage Bolts Noted in Bus/ Bar Connections of Electrical Switchboards.Caused by Igscc. Bolts Replaced.Reportable Per Part 21.W/900209 Ltr ML20011E1601990-02-0101 February 1990 LER 90-001-00:on 900102,RCIC Removed from Svc & HPCI Rendered Inoperable,Placing Unit in Tech Spec 3.0.3.Caused by Personnel Error.Individual Counseled & Standing Instruction 90-003 issued.W/900201 Ltr ML19354E5651990-01-24024 January 1990 LER 89-021-00:on 891225,electrical Protection Assembly Output Breakers Associated W/Bus a of Reactor Protection Sys Tripped Open.Cause of Trip Unknown.Voltage & Frequency Output of Motor Generator a monitored.W/900124 Ltr ML19354E5611990-01-19019 January 1990 LER 89-025-00:on 891223,sample Lines for Stack Radiation Monitor Froze,Resulting in Samples Not Indicative of Ongoing Releases.Caused by Lack of Insulation on Lines Exiting Stack.Sample Lines insulated.W/900119 Ltr ML19354D8951990-01-16016 January 1990 LER 89-020-00:on 891217,relay in Reactor Protection Sys B Motor Generator Set Control Panel Burned Out,Resulting in Logic Trip of Bus B & Isolation of Standby Gas Treatment Sys.Caused by Circuit malfunction.W/900116 Ltr ML20005F0501990-01-0404 January 1990 LER 89-026-00:on 891210,loss of E3 Bus While Deenergizing Bus 2D for Scheduled Maint Occurred.Caused by Procedural Inadequacy of Plant Electric Sys Operating Procedures.Unit Reset & Sys Returned to normal.W/900104 Ltr ML20042D3551990-01-0202 January 1990 LER 89-019-00:on 891208,Group 6 Isolation Occurred W/Standby Gas Treatment Sys Auto Start During Performance of MST-SCIS21R.Caused by Inadequate Work Practices.Work Crew Counseled.Calibr Procedures May Be revised.W/900102 Ltr ML20005E3461989-12-27027 December 1989 LER 89-024-00:on 891127,17 Primary Containment Isolation Valves Not Tested Per Tech Spec Surveillance Requirement 4.6.1.1.a.Caused by Failure to Recognize Applicability of Testing.Test Rev completed.W/891227 Ltr ML20011D8411989-12-15015 December 1989 LER 89-009-01:on 890617,manual Reactor Scram Initiated Per NRC Bulletin 88-007 Due to Loss of Recirculation Pumps, Causing Loss of Offsite Power & Containment Isolation. Caused by Personnel Error.Hpci Sys secured.W/891215 Ltr ML20011D2251989-12-14014 December 1989 LER 89-023-00:on 891116,reactor Shutdown When Drywell to Suppression Chamber Vacuum Breaker Opened.Caused by Excessive Vibration & Lack of Proper Space Between Actuator Arm & Piston.Procedures Will Be revised.W/891214 Ltr ML19332E9001989-12-0707 December 1989 LER 89-022-00:on 891110,automatic Isolation of Units 1 & 2 Common Control Bldg HVAC & Emergency Air Filtration Sys Occurred.Cause Not Determined.Detectors auto-reset & Sys Returned to Normal svc.W/891207 Ltr ML19332D5791989-11-27027 November 1989 LER 89-018-00:on 891101,determined That Safety Relief Valves Did Not Actuate within Required +/- 1.0% of Setpoints.Cause Not Determined.Setpoints recertified.W/891127 Ltr ML19332C3861989-11-21021 November 1989 LER 89-021-00:on 891022,inadvertent LOCA Initiation Signal Occurred During Monthly Channel Calibr & Functional Test. Caused by Technician Miscommunication.Involved Technicians counseled.W/891121 Ltr ML19327C2021989-11-14014 November 1989 LER 89-019-01:on 890914,determined That Svc Water Sys May Not Have Met Design Requirements Under worst-case Conditions.Caused by Inadequate Component design.Cross-tie Valves Installed.Also Reported Per Part 21.W/891114 Ltr ML19324C3171989-11-0707 November 1989 LER 89-020-00:on 891011,HPCI F006 Valve Motor Control Ctr Indicating Light Socket Shorted & Blew Control Power Fuse for Valve.Caused by Inward Force Applied to Bulb During Removal.Lamp,Socket & Fuse replaced.W/891107 Ltr ML19324C1041989-11-0606 November 1989 LER 89-017-00:on 891010,low Level Signals Occurred,Causing Group 1 Isolation,Core Spray Initiation Signal & auto-start of Common Emergency Diesel Generators.Caused by Perturbation of Ref Leg.Procedures revised.W/891106 Ltr ML19327B9861989-11-0606 November 1989 LER 89-017-01:on 890624,HPCI Sys,Steam Line Break Delta Pressure High Signal,Channel A,Isolation Occurred.Root Cause Investigation Underway.Work Request/Job Order Initiated Requesting Verification of readings.W/891106 Ltr ML19354D4401989-11-0101 November 1989 LER 89-016-01:on 890614,determined That Some Valves Listed in Table 1 of LER Not Tested Per Tech Specs.Caused by Failure to Establish Proper Procedural Controls.Valve Acceptance Criteria Basis Sheets updated.W/891101 Ltr 1994-05-13
[Table view] Category:RO)
MONTHYEARML20029E1891994-05-13013 May 1994 LER 94-007-00:on 940418,meter Lead Inadvertently Touched Adjacent Terminal Resulting in RCIC Inboard Steam Valve Closure.Caused by Personnel Error.Corrective Action:Meetings Were Held & self-assessments in progress.W/940513 Ltr ML20029D6171994-04-29029 April 1994 LER 94-005-01:on 940330,potential Use of Less Conservative pressure-temp Limit Curves Identified.Caused by Inadequate Procedural Guidance.Corrective Actions:Adverse Condition Rept initiated.W/940429 Ltr ML20029D0051994-04-28028 April 1994 LER 94-005-00:on 940404,two PCIS Group 6 RIP Valves Had Dual Open/Closed (Red/Green) Indications.Cause Was Personnel Error.Corrective Action:Individuals Involved Counseled on event.W/940428 Ltr ML20029C8491994-04-25025 April 1994 LER 94-004-00:on 940329,penetration Leakage in Excess of TS Allowable Limit During Local Leak Rate Testing Identified. Troubleshooting & Analysis of Failure Mechanism in Progress. Suppl to Rept Will Be submitted.W/940425 Ltr ML20046B5601993-07-30030 July 1993 LER 92-004-01:on 920730,RWCU Sys Isolated During Substation E7 de-energization Due to Personnel Error.Preparation of Project Plan for Development of Electrical Load List Using Plant Staff Resources underway.W/930730 Ltr ML20045G5821993-07-0808 July 1993 LER 93-003-00:on 930608,RPS MG a Tripped,Resulting in Successful ESF Actuations & Isolations Due to Defective Procedure.Voltage Adjust Potentiometer for MG a Voltage Regulator Replaced on 930617.W/930708 Ltr ML20045F5201993-07-0202 July 1993 LER 93-010-00:on 930604,hourly Fire Watch TS Surveillance Missed During Radiography Due to HP & Operations Failed to Establish Other Means of Communication W/Radiographers. W/930702 Ltr ML20045D6371993-06-30030 June 1993 LER 93-005-01:on 930214,testing of SBGT Showed That Unthrottled Flow of Single Train Would Exceed TS Rated Flow Limit of 3,330 Cfm.Caused by Design Deficiency.Existing SBGT Heaters Upgraded & Rewired ML20045D7601993-06-30030 June 1993 LER 93-008-01:on 930313,spurious ESF Actuations Occurred Due to on-site Electrical Distribution Sys Voltage Depressions. Design of cross-over Points of Transmission Lines Emanating from Plant Being reviewed.W/930624 Ltr ML20045D1531993-06-21021 June 1993 LER-93-007-00:on 930522,discovered That MSL D High Flow Trip Unit Failed Downscale Due to Personnel Error.Appropriate Operations Personnel counselled.W/930617 Ltr ML20045D5881993-06-17017 June 1993 LER 93-006-00:on 930521,HCU 06-31 Declared Inoperable When CRD Accumulator Low Pressure/High Level Alarm Received in Cr.Hcu 02-23 Inoperable at Time.Hcu 02-23 Restored to Svc & Excess Water Drained from HCU 06-31.W/930617 Ltr ML20044E5241993-05-24024 May 1993 LER 93-007-00:on 930424,discovered That Sampling of Rv Coolant Conductivity Not Performed Due to Misinterpretation of RCS Chemistry Ts.Chemistry Sampling of Rv Coolant re-established.W/930521 Ltr ML20044E5411993-05-20020 May 1993 LER 93-009-00:on 930421,found That Design of SBGTS Would Allow Operation That Would Result in Sys Damage If Containment Venting in Progress & Experience Loca.Operating Procedures 1-OP-10 & 1-OP-24 revised.W/930520 Ltr ML20044B6761993-02-22022 February 1993 LER 93-001-00:on 930121,determined That Containment Atmospheric Control Airborne Particulate & Gaseous Radioactivity Monitors Not Seismically Qualified.Suppl to Rept Will Be submitted.W/930227 Ltr ML20029A9111991-02-25025 February 1991 LER 91-001-00:on 910125,reactor Scram Occurred During Calibr of Feedwater Computer Point.Caused by Incorrect Procedure in Summary Sheet.Maint Procedures Reviewed & revised.W/910225 Ltr ML20028H7141991-01-24024 January 1991 LER 90-019-00:on 901226,isolation Signal Caused Reactor Water Cleanup Inlet Inboard Isolation Valve to Automatically Close.Caused by de-energized HPCI Isolation Relay.Riley Scam Temp Switch Units Will Be replaced.W/910124 Ltr ML20024F7461990-12-13013 December 1990 LER 90-020-00:on 901117,primary & Secondary Containment Isolation Signals Received & Standby Gas Treatment Sys auto- Started.Caused by Scan Overload on Microprocessor.Updated Microprocessor Will Be obtained.W/901213 Ltr ML20028H0421990-09-28028 September 1990 LER 90-012-00:on 900830,Unit 2 Reactor Scram Occurred During Reactor Startup.Investigation Continuing.Level Recovered W/O Need for Safety Sys Injection & Unit Designed for Level Transient from Full power.W/900928 Ltr ML20028H0431990-09-28028 September 1990 LER 90-011-00:on 900830,RWCU Sys G31 Received Leak Hi & RWCU Leak Hi Hi Annunciators Although Actual Leak Had Not Occurred.Caused by Air in Instrument 2-G31-FT-N012 Sensing Lines.Investigation to Be conducted.W/900928 Ltr ML20043G0981990-06-15015 June 1990 LER 88-001-06:on 880102,manual Reactor Protection Sys Trip Initiated Due to Decreasing Condenser Vacuum.Cause Still Undetermined.Vendor Insp Revealed Presence of Oil Base Film in Solenoid Valves.Determination Due by 900801.W/900615 Ltr ML20043G0711990-06-13013 June 1990 LER 90-005-00:on 900514,unplanned Closure of HPCI Isolation Valve Occurred During Maint Surveillance Test.Caused by Technician Placing RCIC Instead of HPCI Test Switch to Test Position.Personnel Counseled & trained.W/900613 Ltr ML20043F6291990-06-11011 June 1990 LER 90-008-00:on 900514,HPCI Sys Rendered Inoperable When Control Power Lost to Min Flow Bypass Valve to Suppression Pool.Probably Caused by Design Problem W/Ge Model CR2940 Sockets.Light Bulb & Fuse replaced.W/900611 Ltr ML20043F6181990-06-0808 June 1990 LER 90-007-00:on 900511,identified That Damper Would Fail to Close on Loss of Power to Solenoid Valve & on 900526,damper Found Approx 30 Degrees Open.Caused by Failure of Design to Include Fail Safe Damper.Damper modified.W/900608 Ltr ML20043C9001990-06-0101 June 1990 LER 90-009-00:on 900507,determined That Tech Spec 4.6.1.1 Requirements Not Met After Performing Monthly Periodic Test 2.2.4a.Caused by Inadequate Procedure.Recommended Procedure Revs to Prevent Recurrence Being evaluated.W/900601 Ltr ML20043B7971990-05-25025 May 1990 LER 90-006-00:on 900426,hydraulic Perturbation Occurred on Variable Leg of Instrumentation Used to Sense Reactor Water Level,Causing Isolation of RWCU Sys & Initiation of Standby Gas Treatment Sys.Diaphragm Assembly recalibr.W/900525 Ltr ML20043A6121990-05-11011 May 1990 LER 90-003-01:on 900312,full Group 1 Isolation Signal Received,Resulting in Automatic Closure of Msivs.Caused by Personnel Failing to Follow Procedures.Personnel Counseled & Procedure Separated Into Two tests.W/900511 Ltr ML20012E0581990-03-23023 March 1990 LER 90-002-00:on 900224,Group I Isolation Occurred When Undervoltage Relay Replaced.Caused by Lack of Recognition of Significance of Having Turbine Reset While Performing Electro Hydraulic Control evolutions.W/900323 Ltr ML20012B8071990-03-0909 March 1990 LER 90-001-00:on 900210,determined That Core Spray Loops a & B Inoperable Due to Missed Surveillance.Cause Not Stated. Investigation continuing.W/900309 Ltr ML20012A1671990-03-0202 March 1990 LER 89-013-01:on 890909,HPCI Turbine Auxiliary Oil Pump Developed Shaft Seal Leak of Approx 1 Gpm.Caused by Failure of Shaft Seal.Root Cause of Seal Failure Initiated.Pump Seal replaced.W/900302 Ltr ML20011F5541990-02-22022 February 1990 LER 90-002-00:on 900127,common Control Bldg HVAC Sys Isolated & Transferred to Recirculation Mode as Result of Spurious Actuation of Chlorine Detector.Sensor Connection checked.W/900222 Ltr ML20006E7751990-02-19019 February 1990 LER 88-001-05:on 880102,manual Reactor Protection Sys Trip Initiated Due to Decreasing Condenser Vacuum.Caused by Numerous Leaks on Main Turbine & Main Steam Reheat Interconnecting Piping.Seating Matl installed.W/900219 Ltr ML20011F5311990-02-16016 February 1990 LER 89-026-01:on 891210,common Emergency Bus E3 Unexpectedly Deenergized,Causing Standby Gas Treatment Sys Isolation & Reactor Scram Signal.Caused by Procedural Inadequacy.Isolation Reset & Power restored.W/900216 Ltr ML20006E3681990-02-0909 February 1990 LER 88-006-02:on 880219,numerous Bolt Head Failures of 5/16- Inch X 1/2-inch Silicon Bronze Carriage Bolts Noted in Bus/ Bar Connections of Electrical Switchboards.Caused by Igscc. Bolts Replaced.Reportable Per Part 21.W/900209 Ltr ML20011E1601990-02-0101 February 1990 LER 90-001-00:on 900102,RCIC Removed from Svc & HPCI Rendered Inoperable,Placing Unit in Tech Spec 3.0.3.Caused by Personnel Error.Individual Counseled & Standing Instruction 90-003 issued.W/900201 Ltr ML19354E5651990-01-24024 January 1990 LER 89-021-00:on 891225,electrical Protection Assembly Output Breakers Associated W/Bus a of Reactor Protection Sys Tripped Open.Cause of Trip Unknown.Voltage & Frequency Output of Motor Generator a monitored.W/900124 Ltr ML19354E5611990-01-19019 January 1990 LER 89-025-00:on 891223,sample Lines for Stack Radiation Monitor Froze,Resulting in Samples Not Indicative of Ongoing Releases.Caused by Lack of Insulation on Lines Exiting Stack.Sample Lines insulated.W/900119 Ltr ML19354D8951990-01-16016 January 1990 LER 89-020-00:on 891217,relay in Reactor Protection Sys B Motor Generator Set Control Panel Burned Out,Resulting in Logic Trip of Bus B & Isolation of Standby Gas Treatment Sys.Caused by Circuit malfunction.W/900116 Ltr ML20005F0501990-01-0404 January 1990 LER 89-026-00:on 891210,loss of E3 Bus While Deenergizing Bus 2D for Scheduled Maint Occurred.Caused by Procedural Inadequacy of Plant Electric Sys Operating Procedures.Unit Reset & Sys Returned to normal.W/900104 Ltr ML20042D3551990-01-0202 January 1990 LER 89-019-00:on 891208,Group 6 Isolation Occurred W/Standby Gas Treatment Sys Auto Start During Performance of MST-SCIS21R.Caused by Inadequate Work Practices.Work Crew Counseled.Calibr Procedures May Be revised.W/900102 Ltr ML20005E3461989-12-27027 December 1989 LER 89-024-00:on 891127,17 Primary Containment Isolation Valves Not Tested Per Tech Spec Surveillance Requirement 4.6.1.1.a.Caused by Failure to Recognize Applicability of Testing.Test Rev completed.W/891227 Ltr ML20011D8411989-12-15015 December 1989 LER 89-009-01:on 890617,manual Reactor Scram Initiated Per NRC Bulletin 88-007 Due to Loss of Recirculation Pumps, Causing Loss of Offsite Power & Containment Isolation. Caused by Personnel Error.Hpci Sys secured.W/891215 Ltr ML20011D2251989-12-14014 December 1989 LER 89-023-00:on 891116,reactor Shutdown When Drywell to Suppression Chamber Vacuum Breaker Opened.Caused by Excessive Vibration & Lack of Proper Space Between Actuator Arm & Piston.Procedures Will Be revised.W/891214 Ltr ML19332E9001989-12-0707 December 1989 LER 89-022-00:on 891110,automatic Isolation of Units 1 & 2 Common Control Bldg HVAC & Emergency Air Filtration Sys Occurred.Cause Not Determined.Detectors auto-reset & Sys Returned to Normal svc.W/891207 Ltr ML19332D5791989-11-27027 November 1989 LER 89-018-00:on 891101,determined That Safety Relief Valves Did Not Actuate within Required +/- 1.0% of Setpoints.Cause Not Determined.Setpoints recertified.W/891127 Ltr ML19332C3861989-11-21021 November 1989 LER 89-021-00:on 891022,inadvertent LOCA Initiation Signal Occurred During Monthly Channel Calibr & Functional Test. Caused by Technician Miscommunication.Involved Technicians counseled.W/891121 Ltr ML19327C2021989-11-14014 November 1989 LER 89-019-01:on 890914,determined That Svc Water Sys May Not Have Met Design Requirements Under worst-case Conditions.Caused by Inadequate Component design.Cross-tie Valves Installed.Also Reported Per Part 21.W/891114 Ltr ML19324C3171989-11-0707 November 1989 LER 89-020-00:on 891011,HPCI F006 Valve Motor Control Ctr Indicating Light Socket Shorted & Blew Control Power Fuse for Valve.Caused by Inward Force Applied to Bulb During Removal.Lamp,Socket & Fuse replaced.W/891107 Ltr ML19324C1041989-11-0606 November 1989 LER 89-017-00:on 891010,low Level Signals Occurred,Causing Group 1 Isolation,Core Spray Initiation Signal & auto-start of Common Emergency Diesel Generators.Caused by Perturbation of Ref Leg.Procedures revised.W/891106 Ltr ML19327B9861989-11-0606 November 1989 LER 89-017-01:on 890624,HPCI Sys,Steam Line Break Delta Pressure High Signal,Channel A,Isolation Occurred.Root Cause Investigation Underway.Work Request/Job Order Initiated Requesting Verification of readings.W/891106 Ltr ML19354D4401989-11-0101 November 1989 LER 89-016-01:on 890614,determined That Some Valves Listed in Table 1 of LER Not Tested Per Tech Specs.Caused by Failure to Establish Proper Procedural Controls.Valve Acceptance Criteria Basis Sheets updated.W/891101 Ltr 1994-05-13
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217N3271999-10-21021 October 1999 Part 21 Rept Re non-linear Oxygen Readings with Two (2) Model 225 CMA-X Containment Monitoring Sys at Bsep.Caused by High Gain Produced by 10K Resistor Across Second Stage Amplifier.Engineering Drawings Will Be Revised BSEP-99-0168, Monthly Operating Repts for Sept 1999 for Bsep,Units 1 & 2. with1999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for Bsep,Units 1 & 2. with ML20212D0431999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Brunswick Steam Electric Plant,Units 1 & 2 ML20210P9441999-08-10010 August 1999 Safety Evaluation Accepting Licensee Assessment of Impact on Operation of Plant,Unit 1,with Crack Indications of 2.11, 6.36 & 1.74 Inches in Three Separate Jet Pump Risers ML20210P9181999-08-10010 August 1999 Safety Evaluation Authorizing Request for Reliefs CIP-01,02, 06,07,08,09,10 & 11 (with Certain Exceptions) & 12-18,for Second 10-year ISI Interval.Request CIP-04 & 05 Would Result in hardship,CIP-03 Not Required & CIP-11 Denied in Part ML20210N2341999-08-0505 August 1999 SER Accepting Response to NRC GL 87-02, Verification of Seismic Adequacy of Mechanical & Electrical Equipment in Operating Reactors,Unresolved Safety Issues (USI) A-46 ML20210R1191999-07-31031 July 1999 Monthly Operating Repts for July 1999 for Bsep,Units 1 & 2 ML20210R1311999-06-30030 June 1999 Revised Monthly Operating Rept for June 1999 for Bsep,Unit 2 BSEP-99-0118, Monthly Operating Repts for June 1999 for Bsep,Units 1 & 2. with1999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Bsep,Units 1 & 2. with BSEP-99-0095, Monthly Operating Repts for May 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With1999-05-31031 May 1999 Monthly Operating Repts for May 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With ML20210M8581999-05-14014 May 1999 B214R1 RPV Hydrotest Bolted Connection Corrective Action Evaluation, Rev 0 ML20211L3711999-05-10010 May 1999 Rev 0 to ESR 98-00333, Unit 2 Invessel Feedwater Sparger Evaluation ML20206G1871999-05-0404 May 1999 Safety Evaluation Approving Third 10-year ISI Program Requests for Relief (RR) RR-08,RR-15 & RR-17 BSEP-99-0075, Monthly Operating Repts for Apr 1999 for Brunswick Steam Electric Plant,Unit 1 & 2.With1999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Brunswick Steam Electric Plant,Unit 1 & 2.With ML20206N1791999-04-23023 April 1999 Rev 0 to 2B21-0554, Brunswick Unit 2,Cycle 14 Colr BSEP-99-0059, Monthly Operating Repts for Mar 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With1999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With ML20205F9031999-03-30030 March 1999 Safety Evaluation Supporting Proposed Rev to BSEP RERP to Licenses DPR-62 & DPR-71,respectively ML20206N1831999-02-28028 February 1999 Rev 0 to Suppl Reload Licensing Rept for Bsep,Unit 2 Reload 13 Cycle 14 BSEP-99-0043, Monthly Operating Repts for Feb 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With1999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Brunswick Steam Electric Plant,Units 1 & 2.With ML20203D7061999-02-0909 February 1999 SER Accepting Proposed Alternatives Contained in Relief Requests PRR-04,VRR-04,VRR-13,PRR-01,PRR-03,VRR-01.VRR-07, VRR-08 & VRR-09 Denied BSEP-99-0005, Monthly Operating Repts for Dec 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With1998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With BSEP-98-0231, Monthly Operating Repts for Nov 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With1998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With BSEP-98-0218, Monthly Operating Repts for Oct 1998 for Bsep,Units 1 & 2. with1998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for Bsep,Units 1 & 2. with BSEP-98-0210, Special Rept:On 980824,temp Element 2-CAC-TE-1258-22 Failed. Cause of Failed Temp Element Cannot Be Conclusively Determined.Temp Element Will Be Replaced & Cable Connections Repaired1998-10-30030 October 1998 Special Rept:On 980824,temp Element 2-CAC-TE-1258-22 Failed. Cause of Failed Temp Element Cannot Be Conclusively Determined.Temp Element Will Be Replaced & Cable Connections Repaired ML20154P8151998-10-16016 October 1998 SER Accepting Revised Safety Analysis of Operational Transient of 920117,for Plant,Unit 1 ML20154P8591998-10-16016 October 1998 SER Accepting Equivalent Margins Analysis for N-16A/B Instrument Nozzles for Plant,Units 1 & 2 BSEP-98-0202, Monthly Operating Repts for Sept 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With1998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With ML20151Y6211998-09-14014 September 1998 BSEP Rept Describing Changes,Tests & Experiments, for Bsep,Units 1 & 2 ML20151Y6371998-09-14014 September 1998 Changes to QA Program, for Bsep,Units 1 & 2 BSEP-98-0185, Monthly Operating Repts for Aug 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With1998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for Brunswick Steam Electric Plant,Units 1 & 2.With ML20151T5021998-08-0505 August 1998 Project Implementation Plan, Ngg Yr 2000 Readiness Program, Rev 2 BSEP-98-0164, Monthly Operating Repts for July 1998 for BSEP Units 1 & 21998-07-31031 July 1998 Monthly Operating Repts for July 1998 for BSEP Units 1 & 2 ML20236T1961998-07-0101 July 1998 Rev 1 to 2B21-0088, Brunswick Unit 2,Cycle 13 Colr ML20236T1921998-07-0101 July 1998 Rev 1 to 1B21-0537, Brunswick Unit 1,Cycle 12 Colr BSEP-98-0142, Monthly Operating Repts for June 1998 for BSEP Units 1 & 21998-06-30030 June 1998 Monthly Operating Repts for June 1998 for BSEP Units 1 & 2 ML20236T1971998-06-30030 June 1998 Rev 2 to 24A5412, Supplemental Reload Licensing Rept for Brunswick Steam Electric Plant Unit 2 Reload 12 Cycle 13 ML20249B9691998-06-11011 June 1998 Rev 1 to VC44.F02, Brunswick Steam Electric Plant,Units 1 & 2,ECCS Suction Strainers Replacement Project,Nrc Bulletin 96-003 Final Rept BSEP-98-0129, Monthly Operating Repts for May 1998 for Bsep,Units 1 & 21998-05-31031 May 1998 Monthly Operating Repts for May 1998 for Bsep,Units 1 & 2 ML20151S9041998-05-31031 May 1998 Revised Pages to Monthly Operating Rept for May 1998 for Brunswick Steam Electric Plant,Unit 1 BSEP-98-0104, Monthly Operating Repts for Apr 1998 for Brunswick Steam Electric Plant,Units 1 & 21998-04-30030 April 1998 Monthly Operating Repts for Apr 1998 for Brunswick Steam Electric Plant,Units 1 & 2 ML20151S8991998-04-30030 April 1998 Revised Pages to Monthly Operating Rept for Apr 1998 for Brunswick Steam Electric Plant,Unit 1 ML20247N7501998-04-30030 April 1998 Rev 0 to BSEP Unit 1,Cycle 12 Colr ML20247N7721998-04-30030 April 1998 Rev 0 to J1103244SRLR, Supplemental Reload Licensing Rept for BSEP Unit 1,Reload 11,Cycle 12 ML20217K8461998-04-24024 April 1998 Safety Evaluation Approving Proposed Use of Code Case N-535 at Brunswick Unit 1 During Second 10-yr Interval,Pursuant to 10CFR50.55a(a)(3)(i).Authorizes Use of Code Case N-535 Until Code Case Included in Future Rev of RG 1.147 ML20217K3941998-04-24024 April 1998 SER Approving Relief Request for Pump Vibration Monitoring, Brunswick Steam Electric Plant,Units 1 & 2 ML20217E6841998-04-23023 April 1998 Safety Evaluation Accepting Code Case N-547, Alternative Exam Requirements for Pressure Retaining Bolting of CRD Housings ML20217E7471998-04-21021 April 1998 Safety Evaluation Accepting Alternative to Insp of Reactor Pressure Vessel Circumferential Welds ML20217B5241998-04-20020 April 1998 SE Accepting Licensee Request for Approval to Use Alternative Exam Requirement for Brunswick,Unit 1,reactor Vessel Stud & Bushing During Second 10-yr ISI Interval Per 10CFR50.55a(a)(3)(ii) BSEP-98-0080, Monthly Operating Repts for Mar 1998 for Bsep,Units 1 & 21998-03-31031 March 1998 Monthly Operating Repts for Mar 1998 for Bsep,Units 1 & 2 ML20216B1041998-03-0404 March 1998 SER Approving Alternative to Insp of Reactor Pressure Vessel Circumferential Welds for Brunswick Steam Electric Plant, Unit 1 1999-09-30
[Table view] |
Text
p gpgg, Carolina Power & Light Company Brunswick Nuclear Project P. O. Box 10429 Southport, NC 28461-0429 August 1, 1990 FILE: B09 135100 10CFR50.73 SERIAL: BSEP/90 053,6 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 BRUNSWICK STEAM ELECTRIC PLANT UNIT 2 DOCKET NO. 50 324 LICENSE NO. DPR 62 SUPPLEMENT TO LICENSEE EVENT REPORT 2 88 001 Centlemen:
In accordance with Title 10 to the Code of Federal Regulations, the enclosed Supplemental Licensee Event Report is submitted. The original report fulfilled the requirement for a written report within thirty (30) days of a reportable occurrence and was submitted in accordance with the format set forth in NUREC 1022, September 1983.
Very truly yours, eg,hvvww J. L. Harness, Ceneral Manager Brunswick Nuclear Project TMJ/mcg.LTR2 Enclosure cc: Mr. S. D. Ebneter Mr. E. C. Tourigny BSEP NRC Resident Office
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,..c, - . . . . . - ,, - ,nei While performing a routine reactor shutdc,.m in preparation for the Unit 21988 refueling / maintenance outage, a manual reactor protection system trip (scram) was initiated at 0017 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br /> on 1/2/88, due to a decreasing condenser vacuum.
Reactor power was approximately 55% and vacu'.un had decreased to
, approximately 22 inches mercury. During the expected vessel level shrink
following the scram, vessel level decreased to approximately 153 inches, thus initiating primary containment isolation valve groups 2, 6, and 8 at low level 1 (> 162.5*). Operator verification of these valve closures determined that the group 2 valves 2 016 F003. -F004, F019, and F020 failed to close. These are the inboard and outboard isolation valves for the drywell floor drain sump (F003, F004) and the drywell equipment drain sump (F019, F020). The remaining
- safety systems operated as designed during this event.
I Investigation of the decreasing vacuum condition determined it resulted from l
numerous leaks on the main turbine and main steam reheat interconnecting piping to the main turbine, which were repaired during the unit outage. The -
, failure of the group 2 PCIVs to close was caused by the failure of the associated solenoid valves to open due to adherence between the lower brass '
l disc and EPDM elastomer seat.
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0 l7 0l3 of I l0 femu smeea mawnn Initial Conditions At approximately 2015 hours0.0233 days <br />0.56 hours <br />0.00333 weeks <br />7.667075e-4 months <br /> on 1/1/88, a power reduction was commenced from 69% power to commence a scheduled 16 week refueling and maintenance outage.
This initial condition tapresented the maximum attainable reactor power due to operating cycle fuel depletion. After approximately two hours, at a power level of approximately 50%, problems were encountered maintaining condenser vacuum. At 0017 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br /> on 1/2/88, a manual reactor protection system (EIIS/JC) trip (scram) was initiated with main condenser (EIIS/SG) vacuum at approximately 22 inches mercury (lig) and decreasing in anticipation of an automatic scram due to the main turbine (EIIS/TA) trip on low vacuum at greater than 304 power. At the initiation of the scram, plant emergency core coolin6 systems and other safety systems were operable.
Event Descriction Ar 2015 hours0.0233 days <br />0.56 hours <br />0.00333 weeks <br />7.667075e-4 months <br /> on 1/1/88, reactor power reduction was cominenced in preparation for the scheduled refueling / maintenance outage. As power was decreased, condenser off gas flow slowly began to increase such that, at 2125 hours0.0246 days <br />0.59 hours <br />0.00351 weeks <br />8.085625e-4 months <br />, the augmented off-gas system bypass valve (EIIS/WE/FCV) automatically opened due to high flow (setpoint; 150 scfm). This increase in off gas flow was not unexpected in that it had been noted that off gas flow had increassd during previous power reductions. This off gas power relation is believed to be caused by minor steam leaks at high p wer levels which become vacuum leaks at lower power levels. Although off-gas flow was increasing, condenser vacuum was showing slight improvement. Power was reduced to 48% at 2215 hours0.0256 days <br />0.615 hours <br />0.00366 weeks <br />8.428075e-4 months <br /> and 28 steam jet air ejector (SJAE) (EIIS/Sil/EJR) was secured with 2A SJAE remaining in half load per the plant shutdown procedure. After securing 2B SJAE, condenser vacuum began to decrease and the 2A SJAE was placed in. full load at 2245 hours0.026 days <br />0.624 hours <br />0.00371 weeks <br />8.542225e-4 months <br />, and reactor power was increased to 51%. These actions caused-vacuum to reverse the downward trend and start improving. With vacuum improving, efforts were initiated to identify vacuum leaks for repair / isolation to allow the recommencement of the scheduled power reduction.
At 2345 hours0.0271 days <br />0.651 hours <br />0.00388 weeks <br />8.922725e-4 months <br />, vacuum again began to decrease with the decreasing trend being at a higher rate than had been observed during the initial decrease following the securing of 2B SJAE. No evolution had taken place during the previous hour which would have caused this change. Attempts to place the 2B SJAE in service were unsuccesr N due to a low output from the startup permissive temperature instrumem 't;S/JA/TC). Power was increased to approximately 554 by increasing recircule: Da flow and control rod withdrawal in an effort to terminate the decreasing vacuum trend. These efforts appeared to have no effect. With the vacuum continuing to decrease, the decision was made to manually scram the reactor prior to receiving the automatic scram due to the turbine trip on low condenser vacuum at greater than 304 power.
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At 0017 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br /> on 1/2/88, a manual scram was initiated at a condenser vacuu:s of approximately 22 inches Hg and decreasing. A normal scram recovery was initiated using the emergency operating procedures. Immediately following the ,
scram, reactor vessel level decreased to approximately 153 inches due to expected void collapse and returned to the normal operating level. As a result of decreasing below a reactor vessel level of 162.5 inches (low level 1), an automatic scram signc1 was initiated along with an automatic primary containment isolation system (PCIS) (EIIS/JM) signal for groups 2, 6, and 8.
- A verification that these automatic functions, per the emergency operating -
procedures, occurred at 0020 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> determined that the PCIS group 2 valves (EIIS/JM/ISV), 2 016 F003, F004 -F019, and F020, failed to close. These valves are the inboard and outboard isolation valves (both located outside the primary containment) for the drywell floor drain sump (EIIS/IJ/SNK)
(F003, F004) and the drywell equipment drain sump (EIIS/IF/SNK) (F019, F020).
Failure of these valves to shut represented a failure of both redundant safety divisions as PCIS valves F004 and F020 are associated with one logic division, and PCIS valves F003 and F019 are ascociated with the other logic division.
Following identification of the failure of these valves to close, each valve was given a manual close signal from the Control Roon reactor turbine gauge l board (EIIS/NA/CBD), at which time the F003 and F004 valves went shut. No change in position status was noted for the F019 and F020 valves. At >
approximately 0023 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br />, the F020 was observed to be in the closed position.
No evolution could be identified which would have caused the F020 to close during this three minute time frame. Another manual close signal was given to ,
the F019 valve at approximately 0023 hours2.662037e-4 days <br />0.00639 hours <br />3.80291e-5 weeks <br />8.7515e-6 months <br /> and again, no change in position i noted; however, the F019 valve was observed to be in the closed position at 0025 hours2.893519e-4 days <br />0.00694 hours <br />4.133598e-5 weeks <br />9.5125e-6 months <br />. Again, no evolution could be identified which would have closed the F019 valve following manual operation.
l Further review of the plant responsrv to this scram indicated that the remaining, plant safety systems operated per design. Five control rods (EIIS/AA/ ROD) were identified to be at the 02 position following the scram and they were fully inserted by 0030 hours3.472222e-4 days <br />0.00833 hours <br />4.960317e-5 weeks <br />1.1415e-5 months <br /> using plant procedures.
Investination sn===ry Decreasing Condenser Vacuum j At approximately 2220 hours0.0257 days <br />0.617 hours <br />0.00367 weeks <br />8.4471e-4 months <br /> on 1/1/88, vacuum began to decrease following the l
removal of the 2B SJAE from service per procedure. Following an increase in i power and the placing of 2A SJAE in full load, vacuum began an improving <
trend. One hour later at 2345 hours0.0271 days <br />0.651 hours <br />0.00388 weeks <br />8.922725e-4 months <br />, vacuum again began to decrease due to no apparent cause, as no plant evolutions had been undertaken within that hour I
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017 0 l5 0F ll0 which would have affected vacuum. Vacuum continued to decrease until the manual scram was initiated at 0017 hours1.967593e-4 days <br />0.00472 hours <br />2.810847e-5 weeks <br />6.4685e-6 months <br />, at which time vacuum recovered quickly, decreased for a short period of time, and then gradually increased until leveling out at 28 inches of Hg.
A review of the vacuum trend durin6 this event and previous plant vacuum operating history indicated that, although higher than normal air inleakage did contribute to the decrease in condenser vacuum, the high air inleakage '
flow rate would not alone cause the high SJAE discharge pressures observed during the event. It is unlikely that a larBe air inleakage source initiating at 2345 hours0.0271 days <br />0.651 hours <br />0.00388 weeks <br />8.922725e-4 months <br /> would have allowed the vacuum to recover and trend as noted following the scram.
As previously noted, air inleakage had been an identified problem prior to this event during power reductions. Investigations were initiated on 9/25/87 to identify and correct suspected air inleakage problems. The investigation consisted of a complete valve lineup and helium leak testing. These investigations had identified several air inleakage sources during the latter part of 1987 and were att11 in progress at the time of the event. Repairs had been made where system operation and safety would allow, with the remaining known air inleakage problems to be corrected during the outage. Additional air inleakage sources were still being sought at the time of this c. vent.
In addition to the known and suspected air inleakage, the decreasin6 trend in condenser vacuum is b.lieved to have been caused by SJAE back pressure. It is believed that excessive moisture in the downstream piping (r:IIS/SH/PSX) of the SJAEs was partially the cause for the decreasing vacuum. Indications of this probable cause included a high differential pressure alarm (possible cause; high moisture in the off gas effluent) received for the off gas system main stack filter (EIISW F/FLT) which cleared when the standby filter (EIISW F/FLT) was placed in service as well as a noted decrease in the off gas system recombiner (EIISWF/RCB) temperature. Moisture carryover into the discharge line (EIIS W F/PSX) may have occurred from the high level noted in the 2A SJAE intercondenser (EIIS/SH/COND), whi c was operating at a level of 82 inches (normal level is 55 inches).
During the Unit 2 1988 refueling / maintenance outage, extensive leak testing involving use of helium was performed on the main turbine and condenser and the interconnecting piping to the Condensate System (EIIS/SD) and the Main Steam Reheat System (EIIS/SB) as well as the main turbine structure to I determine the root cause of the incurred decreasing main condenser vacuum. On 4 February 2,1988, while the main condenser was intentionally flooded up, water was observed flowing from a discovered 3/4 inch hole in Miscellaneous Vents and Drains (MVD) System line 2.MVD 267 4 E 3 (EIIS/SM/PSX). This 4" line
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is the shell pocket drain line from the main turbine moisture separator reheater (MSR) to the main condenser, which collects the MSR shell drains from four 1 1/2" lines (EIIS/SM/PSX), each containing a 1/4" orifice strainer (EIIS/SM/PSX). When the main turbine is online., line pressure upstream of the strainers is that of the main turbine 7th stage extraction steam pressure, which varies with reactor power (80 psi 6 at $6% power to 170 psig at 100%
power. Likewise, line pressure downstream of the strainers varies with
- reactor power, such that as power is decreased, the resulting reduced pressure in the line will cause greater main condenser air inleakage. The hole size was determined to have allowed an air inleakage of approximately 96 standard cubic feet per minute (scim) at a main condenser vacuum of 28 inches of mercury. Following discovery of the subject hole, the affected line was replaced. In addition to the hole in the MVD line, several other leaks were identified through helium testing. Repairs to these components were performed during the unit outage.
Valve Failures While performing a scram recovery in c.ccordance with plant procedures, it was determined that the group 2 PCIS valves 2 016.F003, F004, F019, and F020 failed to close on an automatic isolation signal (Iow level 1). Subsequent operator action caused the valves to close as previously stated. The following actions were performed in an effort to determine the cause of the PCIS valves' failure to close.
January 2,1988
- 1. Following the scram recovery, the four group 2 valves were successfully cycled during normal sump pumping operations with no problems noted with valve operation. The Unit 1 (U/1) valves were also stroked to verify operability.
- 2. A visual inspection was performed on the wiring (EIIS/JM/CBL1) and relays (EIIS/JM/RLY) associated with the group 2 isolation logic on Unit 2 (U/2).
- 3. A maintenance history search was initiated to develop the operatins history of the failed PCIS valves. This history review determined that the F003 valvc had experienced three failures and the F004 valve had experienced one failure since the solenoids (EIIS/IJ/*) were replaced in the spring of 1986 as part of environmental qualification modific.r~.ons.
The remaining two valves on U/2 and the four valves on U/1 did not have a failure histnry.
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- 4. Applicable sections of the logic system functional test procedures were performed, with no logic problems identified.
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- January 3, 1988
- 1. The F019 solenoid valve (ASCO) (E1IS/JM/PSV) was removed and disassembled. A minor oil film was identified on internal parts and minor debris was found in the solenoid valve. However , no cause for , or-evidence of, failure was identified.
- 2. The group 2 PCIS valve monthly functional test was performed on U/2. No problems were identified.
January 4, 1988
- 1. A special test procedure was performed to verify the group 2 PCIS valve system logic on U/1. No problems were noted.
January 6, 1"88
- 1. A spect test was performed to simulate the conditions present during the U/2 scram. The operation of the valves was observed locally and strip chart recording of electrical circuit operation was obtained. No problems were identified with valve operation.
- 2. The U/1 valves were shut (normally open), only to be opened for testing and sump pumping operations pending resolution of the failure of the U/2 valves.
January 7, 1988
- 1. Removed and disassembled the solenoid on the F003 valve with no problems idantified.
- 2. Performed an air cleanliness test of the air supply to the F003 valve and a test of the pressure regulator supplying the F003 valve. No problems were identified.
January 8, 1988
- 1. Removed the F020 valve solenoid for on-site vendor inspection and performed a pressure regulator test for its air supply. No problems were identified.
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- 1. Performed a visual inspection of the logic relays A71-K17 and A71 K18 1j (EIIS/JM/RLY), An are strike was identified on terminal 4 of the K18 relay and visual evidence indicates that contact-3-4 had been welded L closed as a result of the are strike, o
- 2. Initiated activities to remove one valve actuator (Miller air motor)- *
(EIIS/JM/84) for inspection. -
!l 3. The F020 valve solenoid, removed on 1/8/88, was inspectad on site by the l vendor with no. operability problems identified.
January 13, 1988
- 1. Removed and inspected the in line air filter (EIIS/JM/FLT) supplying the l F003 valve. No problems were idenH.fied (filter was very clean with approximately three years operating history). t January 14, 1988.
- 1. Replaced the A71-K17 and K18 relays, Ceneral Electric Part No.
CR120A06002AA, on U/2. s
.i January 19 and 20, 1988 '
- 1. Removed and inspected the valve actuator for the F020 valve. The i internals of the-actuator had a liberal coating of grease in accordance with vendor recommendations. 1
. Vendor inspection and analysis of the valves' solenoid valves did not identify evidence which explained.the failure of the valves to open. The inspection 3
'did reveal the presence of an oil bass film in the solenoid valves' internals; however analysis of the oil film deteimined it was oil used by the manufacturer for component assembly. Laboratory work at the. Carolina Power 6 i Light (CP&L) Company metallurgical and failure analysis ft.cility indicated the ;
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. incurred failure of the subject solenoids may have been the result of a higher '
than previously expected rate of degradation (oxidation) of the solenoids' 1 valve seat material, ethylene propylene diene monomer (EPDM), believed to occur when higher than anticipated ambient temperatures due to the solenoids' being normally energized, combine with the presence of copper in the brass solenoid valve bodies. In order to further identify the root cause(s) and required correction actions, the services of a contractor were retained.
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Brunswick Steam Electric Plant Unit 2 o p jo jo lo l 3j2 l4 8l8 0l0l 1 0 l7 0; 9 or 1 l0 inn m . wes maavim The results of the contractor's review were received during the first week of-June 1990. On July 15,1990, C.'6L Metallurgical Services Section issued Technical Report 13 23: Brunswick 2 Failure Analysis of Primary Containment, Isolation System (PCIS) Solenoid Valves. Based on the physical evidence, the report concluded that the solenoid valves failed to open due to adherence between the lower brass disc and EPDM seat with the most likely cause being copper-induced catalytic oxidation of the EPDM elastomer inserts. The report recommended that the Brutu. wick Plant use ASCO Model 206 832 solenoid valves . {
with Viton ciastomers for this application. It was also recommended that I I
additional characterization of EPDM materials he conducted through a utility funded organization such as the Electric Power Research Institute (EPRI) or the Boiling Water Reactor (BWR) Owners Group and that CP&L provide input to j the Nuclear Utility Group on Equipment Qualification (NUGEQ) allowing suggestions to be made to ASCO to pursue the investigation of the use_ of copper deactivators in their EPDM formulations if EPDM materials are continued to be used.
Corrective Actions f i
As.a result of this event, the on site Quality Assurance group performed a l surveillance activity (QASR 88-007) on the failure of the valves to close.
The solenoid valves for Unit 1 and Unit 2 PCIS valves C16-F003, F004, F019, and F020 have been replaced with the type solenoid recommended. In addition, ASCO solenoids with EPDM seats and normally energized coils'aro also being l replaced with solenoids having Viton seat material in accordance with !
Engineering Evaluation Request (EER) 88 076, Rev. 1. To date, twenty two i solenoids valves have been replaced and two remain. As an interim measure, the EER has directed that the two remaining solenoids be cycled on a weekly
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basis to ensure their operability. The cycling is accomplished in accordance
. with Special Procedure 88-023.
In regard to actions recommended ir.volving EPRI, the BWR Owners Group, and NUGEQ CP&L corporate representatives for the associated' groups were contacted and are being provided a copy of Technical Report 13 23. They will review the report and initiate any additional actions.
Event Assessment This event was assessed to determine if the event would have been more severe under reasonable and credible alternative conditions as defined in NUREG 1022 (and supplements). This assessment determined that the first event (scram) would not have been more severe as this is an analyzed event in the safety analysis and the plant systems are designed for adequate mitigation. The second event (valve failures) would also not be more severe in that neither a reasonable nor a credible alternative conditidn could have provided a source term within the drywell. Without the source term, there is no increase in the quantity on material which would be released through these nonisolated penetrations.
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A review of our records indicates that the failure of the valves to close-is an isolated event for IIR reporting criteria (redundant system failure);
- however, a condenser vacuum problem did initiate a scram in 1985 on U/1 and was reported in LER 1-85 008,
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