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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML20046C3131993-07-28028 July 1993 LER 93-015-00:on 930630,HPCI Sys Declared Inoperable Due to Indicated Flow During Surveillance.Caused by Foreign Matl That Plugged Portion of Restricting Orifice.Restricting Orifice Removed,Cleaned & reinstalled.W/930728 Ltr ML20046B5241993-07-26026 July 1993 LER 93-007-01:on 930317,automatic Closing of RCIC Sys Turbine Steam Supply Isolation Valves Occurred Due to High Steam Flow Signal.Increased Frequency of Valve Testing from Monthly to weekly.W/930726 Ltr ML20045F8601993-06-30030 June 1993 LER 93-014-00:on 930531,automatic Scram Occurred,Resulting from Operation of Auxiliary Transformer Differential Relay During Power Ascension.Uat Phase B & C Differential Relays Left Interchanged as Investigative aid.W/930630 Ltr ML20045E2301993-06-25025 June 1993 LER 93-013-00:on 930530,RCIC Sys Declared Inoperable & 7 Day TS 3.5.D.2 LCO Entered Due to Speed Oscillations Which Occurred After Several Minutes of steady-state Operation. Caused by Actuator Failure.Actuator replaced.W/930625 Ltr ML20045E2251993-06-25025 June 1993 LER 93-012-00:on 930529,unplanned PCIS Group I Isolation Signal Occurred While Opening MSIV During Startup,Resulting in Automatic Closing of Related Valves.Caused by Licensed Operator Error.Group 1 Isolation reset.W/930625 Ltr ML20045D6941993-06-23023 June 1993 LER 93-011-00:on 930525,determined That Initial as-found Popping Pressures of Pilot Valves for Three Target Rock Main Steam Relief Valves Out of TS Tolerance.Caused by Setpoint Drift.Valves Reworked & Reassembled by Target Rock Corp ML20045D1861993-06-18018 June 1993 LER 93-010-00:on 930519,SUT Became de-energized During Planned Calibr of Turbine/Generator Relays Lockout Test While Shut Down.Caused by Personnel Error.Discussion Conducted W/Personnel Re Attention to detail.W/930618 Ltr ML20044H0441993-06-0202 June 1993 LER 93-009-00:on 930504,circuit Breaker Did Not Close During Planned Bus Transfer Due to Loose Control Circuit Wire.Lug Replaced & Reterminated on 930505 & Post Work Testing Completed W/Satisfactory results.W/930602 Ltr ML20024G7451991-04-24024 April 1991 LER 91-005-00:on 910325,diesel Generator Inoperable,Causing Loss of Ac Power to Train B Components of Safety Sys & Actuating Portions of Primary/Secondary Containment Sys. Caused by Voltage Regulator failure.W/910424 Ltr ML20029A6721991-02-25025 February 1991 LER 91-001-00:on 910125,automatic Primary Containment Isolation Control Sys Group 5 Actuation Occurred,Resulting in Closing of RCIC Turbine Steam Supply Isolation Valves. Caused by High Flow conditions.W/910225 Ltr ML20028G9731990-09-20020 September 1990 LER 89-036-01:on 891122,determined That HPCI Sys Inoperable Due to Inoperable Gland Seal Condenser Blower Motor.Caused by age-related Wear of Motor.Blower Motor Replaced & Blower Tested W/Satisfactory results.W/900920 Ltr ML20028G9121990-09-18018 September 1990 LER 89-037-01:on 891130,primary Containment/Traversing in-core Probe Ball Valve Discovered to Be Almost Full Open. Caused by Damage to Valve Stem Due to Manual Manipulation of Stem.Ball Valve & Solenoid Actuator replaced.W/900918 Ltr ML20043G3541990-06-12012 June 1990 LER 90-008-00:on 900513,automatic Scram Resulting from Load Rejection Occurred While at Full Power,Resulting in Trip of Generator Field Breakers.Caused by Fault on Offsite 345 Kv Transmission sys.Loss-of-field Relay replaced.W/900612 Ltr ML20043F8291990-06-0606 June 1990 LER 90-007-00:on 900507,discovered That Drywell to Suppression Chamber Vacuum Breaker Surveillance Not Performed Prior to Startup in 1988.Caused by Misunderstanding of requirements.W/900606 Ltr ML20042F5911990-04-30030 April 1990 LER 90-006-00:on 900330,determined That Position of Primary Containment Sys Isolation Valve Not Recorded Daily,Per Tech Specs.Review Performed to Determine If Other Problems Existed.Plant Shut Down & Review performed.W/900430 Ltr ML20012F5751990-04-0606 April 1990 LER 90-003-00:on 900311,automatic Actuation of Main Steam Sys Group 1 Portion of Primary Containment Isolation Control Sys Occurred.Caused by False High Reactor Vessel Water Level Signal.Procedure Developed Re backfill.W/900406 Ltr ML20012E9831990-03-30030 March 1990 LER 90-002-00:on 900228,determined That Max Fraction of Limiting Power Density Not Checked Daily During Reactor Power Operation,Per Tech Spec 4.1.B.On 900323,addl Tech Spec Issue Discovered.Tech Specs changed.W/900330 Ltr ML20012C4871990-03-12012 March 1990 LER 90-001-00:on 900209,24 H Limiting Condition for Operation Entered When Two RCS Instrumentation Excess Flow Check Valves Inappropriately Verified Operable During Testing.Cause Undetermined.Two Valves replaced.W/900312 Ltr ML20005G0981990-01-0808 January 1990 LER 89-038-00:on 891208,unplanned Automatic Reactor Protection Sys Scram Signal & Reactor Scram Occurred.Caused by False Low Reactor Vessel Water Level Signal.Local Level Indicators Satisfactorily calibr.W/900108 Ltr ML20005F8481990-01-0808 January 1990 LER 89-039-00:on 891209,automatic Actuation of RHR Sys Portion of Primary Containment Isolation Control Sys Occurred.Caused by Hydrodynamic Transient That Actuated Protective High Pressure switches.W/900108 Ltr ML20005E8551989-12-30030 December 1989 LER 89-037-00:on 891130,discovered That Traversing in-core Probe Ball Valve,Mfg by Consolidated Controls,Inc,Closed,In Violation of Tech Specs.Caused by Damage to Valve Stem.Ball Valve & Actuator replaced.W/891230 Ltr ML20011D1361989-12-11011 December 1989 LER 89-035-00:on 891111,inadvertent Actuation of Portion of Secondary Containment Sys During Surveillance Testing Occurred.Caused by Location of Radiation Isolation Control Sys Channel a Logic Relay.Procedure revised.W/891211 Ltr ML20005D7421989-12-0606 December 1989 LER 89-033-00:on 891106,automatic Actuation of Group 1 Portion of Primary Containment Isolation Control Sys (PCIS) Occurred.Caused by High Reactor Vessel Water Level.Manual Valve Closed & PCIS Logic Circuitry reset.W/891206 Ltr ML19351A4581989-12-0606 December 1989 LER 89-034-00:on 891108,determined That Reactor Pressure Exceeded 150 Psig on 891107 W/O Performing Surveillance Procedure 8.5.4.4, HPCI Valve Operability Test. Caused by Personnel Error.Procedure initiated.W/891206 Ltr ML19332D1421989-11-22022 November 1989 LER 89-031-00:on 891024,closing Times for Two in-series Primary Containment Isolation Valves Exceeded Acceptance Criteria During Shutdown Testing.Cause Undetermined.Closing Time Retested W/Satisfactory results.W/891122 Ltr ML19332D6231989-11-20020 November 1989 LER 89-032-00:on 891020,pneumatic Pressure Drop for Two of Four Automatic Depressurization Sys Accumulators Discovered Greater than Max Acceptable Value.Caused by Leakage from Seat of Supply Check Valves.Seat replaced.W/891120 Ltr ML19324C3181989-11-0909 November 1989 LER 88-002-01:on 880117,full Reactor Protection Sys Scram Trip Signal Occurred During Surveillance Test,Resulting in Incomplete Actuations.Caused by Procedure Inadequacy.Logic Relay Replaced & Procedure revised.W/891109 Ltr ML19324B1131989-10-21021 October 1989 LER 89-030-00:on 890926,control Room High Efficiency Air Filtration Sys Flowrate non-conservative Due to Procedure Error.Caused by Transcription Error.Procedure Revised & Test Reperformed Using Corrected procedure.W/891021 Ltr ML19325D4681989-10-16016 October 1989 LER 89-029-00:on 890914,locked High Radiation Area Door Found to Have Been Unsecured Contrary to Tech Spec 6.13.2. Caused by Failure to Adhere to Approved Procedures. Training on Access Requirements initiated.W/891016 Ltr ML19325D1861989-10-10010 October 1989 LER 89-028-00:on 890907,HPCI Sys Declared Inoperable Because Mechanical Overspeed Trip Occurred During Surveillance Test. Caused by Failure of Ramp Generator Signal Converter Module. Module Removed & Sent to Mfg for exam.W/891010 Ltr ML17277B8221984-07-20020 July 1984 LER 82-049/01X-1:on 821102,main Steam Line Safety Valve a Set W/Nitrogen at Steam Relief Setting.Caused by Personnel Error.Valve Removed & Replaced W/Properly Set Spare Valve. Procedure revised.W/840720 Ltr ML20024C3231983-06-24024 June 1983 Updated LER 82-038/03X-1:on 820817,RCIC Steam Line High Differential Pressure Alarm Received.Caused by Air in Sensing Lines to Pressure Switches.Cross Threaded Cap Found on in-line Snubber.Snubber replaced.W/830624 Ltr ML20024C2211983-06-24024 June 1983 Updated LER 80-053/03X-1:on 800814,0907 & 14,HPCI Turbine Exhaust Line Snubber 23-3-36 Determined Inoperable.Caused by Transient Hydrodynamic Shock During Startup & Shutdown. Snubbers upgraded.W/830624 Ltr ML20024B8451983-06-24024 June 1983 LER 83-031/03L-0:on 830528,HPCI Sys Made Inoperable to Repair Steam Leak on AO 2301-31.Caused by Leaking Stem Packing.Packing Replaced.Valve Tested Satisfactorily.Sys Returned to svc.W/830624 Ltr ML20024B8321983-06-24024 June 1983 LER 83-030/03L-0:on 830527,both HPCI Area Smoke Detection Sys Alarmed in Main Control Room.Caused by Valve A02301-31 Steam Leak Causing False Indications.Valve repaired.W/830624 Ltr ML20024C3101983-06-21021 June 1983 Updated LER 79-007/03X-1:on 790212,while Performing Test 8.7.4.3,valves AO-5033A,CV-5065-10,15,16 & 17 Failed to Give Proper Position Indication When Cycled & to Close within Specified Tolerance.Cause Not stated.W/830621 Ltr ML20024A8861983-06-16016 June 1983 LER 83-027/03L-0:on 830518,during Routine Insp,Folding Fire Door Found Inoperable.Caused by Operating Cable Becoming Detached from Pulley Due to Slack.Cable Reattached & Operating Mechanism adjusted.W/830616 Ltr ML20023D1691983-05-0909 May 1983 Updated LER 82-008/01X-1:on 820331,HPCI Injection Valve MO-2301-8 Failed to Open in Required Manner.Caused by Missing Wire Jumper Intended to Bypass Motor Operator Torque Switch.Jumper Installed & Valve Tested Satisfactorily ML20023D0671983-05-0909 May 1983 LER 83-021/03L-0:on 830411,during Surveillance Test 8.7.4.3, Primary Containment Isolation Valve AO-5033B Failed to Meet 10-s Closing Time Requirements.Caused by Lubricant Infiltrating Solenoid Valve Components.Components Replaced ML20023D0181983-05-0404 May 1983 LER 83-022/03L-0:on 830413,overload on Valve Motor 1301-17 Resulted in Loss of High Pressure Core Cooling Backup Capability.Caused by Oxidation in Motor End Bell & Motor Brushes,Due to Humidity Caused by Leaking Valve Packing ML20028G1591983-01-28028 January 1983 LER 83-002/01T-0:on 830116,flow Ref off-normal Alarm Received.Average Power Range Monitor Flux Scram Trip Settings Affected.Cause Under Investigation.Flow Inputs Monitored & Amplifier B Recalibr ML20028F4121983-01-17017 January 1983 LER 83-002/01X-0:on 830116,while Clearing off-normal Alarm for Flow Comparators,Average Power Range Monitor Flux Scram Trip Settings Found in Nonconservative Direction.Caused by Drifting Proportional Amplifiers.Settings Checked Daily ML20028B0421982-11-16016 November 1982 LER 82-049/01T-0:on 821102,main Steam Line Safety Valve a Set W/Nitrogen at Steam Relief Setting of 1240 Psig, Exceeding Tech Specs.Caused by Personnel Error.Set Valve Removed,Procedure Adherence Stressed & Procedure Revised ML20027C9801982-10-20020 October 1982 LER 82-039/03L-0:on 820920,timing Tests of Three Reactor Water Cleanup Isolation Valves 1201-2,-5 & -80 Not Completed within Allowed Time.Caused by Operational Constraints Requiring Testing at Reduced Power ML20027C9941982-10-20020 October 1982 LER 82-040/03L-0:on 820920,found Reactor Protection Sys Initiation Function of Turbine Stop Valve Completed 1 Day Late.Caused by Decision to Defer Test Due to MSIV D Line Isolation.Tracking Sys Implemented to Prevent Recurrences ML20052B9141982-04-23023 April 1982 LER 82-010/03L-0:on 820326,during Review of Testing Requirements,Surveillance Test 8.I.4 Standby Liquid Control Sys Found Not Verified.Caused by Breakdown in Multidiscipline Review of Results ML20052F2071982-04-14014 April 1982 Updated LER 81-060/03X-1:on 811020,determined Potential Exists to Reduce Number of Operable APRM & IRM Instrument Channels in Rod Block Trip Sys to Below Tech Spec Min ML20050A6321982-03-19019 March 1982 Updated LER 82-055/01T-1:on 810926,during Shutdown,Yarway Level Indicators Started Oscillating.Drywell Temp Was 240 F at 81-ft W/Elevation Coolant Temp 220 F.Caused by Ineffective Drywell Cooling.Ventilation Returned to Svc ML20050A4521982-03-19019 March 1982 LER 82-006/01T-0:on 820304,while Performing Maint Re SIL 352 on Pressure Adjustment Mechanism HPCI Stop Valve,Three Broken cap-screws Found.No Cause Determined.Screws Examined, Replaced & Sys Returned to Svc ML20050A4331982-03-19019 March 1982 Updated LER 81-062/01X-1:on 811116,Wyle Labs Informed Util That Two Target Rock Safety Relief Valves Had Not Passed Setpoint Tests.Caused by Setpoint Shift Due to Changes to Designed Differential Forces from Excessive Pilot Leakage 1993-07-28
[Table view] Category:RO)
MONTHYEARML20046C3131993-07-28028 July 1993 LER 93-015-00:on 930630,HPCI Sys Declared Inoperable Due to Indicated Flow During Surveillance.Caused by Foreign Matl That Plugged Portion of Restricting Orifice.Restricting Orifice Removed,Cleaned & reinstalled.W/930728 Ltr ML20046B5241993-07-26026 July 1993 LER 93-007-01:on 930317,automatic Closing of RCIC Sys Turbine Steam Supply Isolation Valves Occurred Due to High Steam Flow Signal.Increased Frequency of Valve Testing from Monthly to weekly.W/930726 Ltr ML20045F8601993-06-30030 June 1993 LER 93-014-00:on 930531,automatic Scram Occurred,Resulting from Operation of Auxiliary Transformer Differential Relay During Power Ascension.Uat Phase B & C Differential Relays Left Interchanged as Investigative aid.W/930630 Ltr ML20045E2301993-06-25025 June 1993 LER 93-013-00:on 930530,RCIC Sys Declared Inoperable & 7 Day TS 3.5.D.2 LCO Entered Due to Speed Oscillations Which Occurred After Several Minutes of steady-state Operation. Caused by Actuator Failure.Actuator replaced.W/930625 Ltr ML20045E2251993-06-25025 June 1993 LER 93-012-00:on 930529,unplanned PCIS Group I Isolation Signal Occurred While Opening MSIV During Startup,Resulting in Automatic Closing of Related Valves.Caused by Licensed Operator Error.Group 1 Isolation reset.W/930625 Ltr ML20045D6941993-06-23023 June 1993 LER 93-011-00:on 930525,determined That Initial as-found Popping Pressures of Pilot Valves for Three Target Rock Main Steam Relief Valves Out of TS Tolerance.Caused by Setpoint Drift.Valves Reworked & Reassembled by Target Rock Corp ML20045D1861993-06-18018 June 1993 LER 93-010-00:on 930519,SUT Became de-energized During Planned Calibr of Turbine/Generator Relays Lockout Test While Shut Down.Caused by Personnel Error.Discussion Conducted W/Personnel Re Attention to detail.W/930618 Ltr ML20044H0441993-06-0202 June 1993 LER 93-009-00:on 930504,circuit Breaker Did Not Close During Planned Bus Transfer Due to Loose Control Circuit Wire.Lug Replaced & Reterminated on 930505 & Post Work Testing Completed W/Satisfactory results.W/930602 Ltr ML20024G7451991-04-24024 April 1991 LER 91-005-00:on 910325,diesel Generator Inoperable,Causing Loss of Ac Power to Train B Components of Safety Sys & Actuating Portions of Primary/Secondary Containment Sys. Caused by Voltage Regulator failure.W/910424 Ltr ML20029A6721991-02-25025 February 1991 LER 91-001-00:on 910125,automatic Primary Containment Isolation Control Sys Group 5 Actuation Occurred,Resulting in Closing of RCIC Turbine Steam Supply Isolation Valves. Caused by High Flow conditions.W/910225 Ltr ML20028G9731990-09-20020 September 1990 LER 89-036-01:on 891122,determined That HPCI Sys Inoperable Due to Inoperable Gland Seal Condenser Blower Motor.Caused by age-related Wear of Motor.Blower Motor Replaced & Blower Tested W/Satisfactory results.W/900920 Ltr ML20028G9121990-09-18018 September 1990 LER 89-037-01:on 891130,primary Containment/Traversing in-core Probe Ball Valve Discovered to Be Almost Full Open. Caused by Damage to Valve Stem Due to Manual Manipulation of Stem.Ball Valve & Solenoid Actuator replaced.W/900918 Ltr ML20043G3541990-06-12012 June 1990 LER 90-008-00:on 900513,automatic Scram Resulting from Load Rejection Occurred While at Full Power,Resulting in Trip of Generator Field Breakers.Caused by Fault on Offsite 345 Kv Transmission sys.Loss-of-field Relay replaced.W/900612 Ltr ML20043F8291990-06-0606 June 1990 LER 90-007-00:on 900507,discovered That Drywell to Suppression Chamber Vacuum Breaker Surveillance Not Performed Prior to Startup in 1988.Caused by Misunderstanding of requirements.W/900606 Ltr ML20042F5911990-04-30030 April 1990 LER 90-006-00:on 900330,determined That Position of Primary Containment Sys Isolation Valve Not Recorded Daily,Per Tech Specs.Review Performed to Determine If Other Problems Existed.Plant Shut Down & Review performed.W/900430 Ltr ML20012F5751990-04-0606 April 1990 LER 90-003-00:on 900311,automatic Actuation of Main Steam Sys Group 1 Portion of Primary Containment Isolation Control Sys Occurred.Caused by False High Reactor Vessel Water Level Signal.Procedure Developed Re backfill.W/900406 Ltr ML20012E9831990-03-30030 March 1990 LER 90-002-00:on 900228,determined That Max Fraction of Limiting Power Density Not Checked Daily During Reactor Power Operation,Per Tech Spec 4.1.B.On 900323,addl Tech Spec Issue Discovered.Tech Specs changed.W/900330 Ltr ML20012C4871990-03-12012 March 1990 LER 90-001-00:on 900209,24 H Limiting Condition for Operation Entered When Two RCS Instrumentation Excess Flow Check Valves Inappropriately Verified Operable During Testing.Cause Undetermined.Two Valves replaced.W/900312 Ltr ML20005G0981990-01-0808 January 1990 LER 89-038-00:on 891208,unplanned Automatic Reactor Protection Sys Scram Signal & Reactor Scram Occurred.Caused by False Low Reactor Vessel Water Level Signal.Local Level Indicators Satisfactorily calibr.W/900108 Ltr ML20005F8481990-01-0808 January 1990 LER 89-039-00:on 891209,automatic Actuation of RHR Sys Portion of Primary Containment Isolation Control Sys Occurred.Caused by Hydrodynamic Transient That Actuated Protective High Pressure switches.W/900108 Ltr ML20005E8551989-12-30030 December 1989 LER 89-037-00:on 891130,discovered That Traversing in-core Probe Ball Valve,Mfg by Consolidated Controls,Inc,Closed,In Violation of Tech Specs.Caused by Damage to Valve Stem.Ball Valve & Actuator replaced.W/891230 Ltr ML20011D1361989-12-11011 December 1989 LER 89-035-00:on 891111,inadvertent Actuation of Portion of Secondary Containment Sys During Surveillance Testing Occurred.Caused by Location of Radiation Isolation Control Sys Channel a Logic Relay.Procedure revised.W/891211 Ltr ML20005D7421989-12-0606 December 1989 LER 89-033-00:on 891106,automatic Actuation of Group 1 Portion of Primary Containment Isolation Control Sys (PCIS) Occurred.Caused by High Reactor Vessel Water Level.Manual Valve Closed & PCIS Logic Circuitry reset.W/891206 Ltr ML19351A4581989-12-0606 December 1989 LER 89-034-00:on 891108,determined That Reactor Pressure Exceeded 150 Psig on 891107 W/O Performing Surveillance Procedure 8.5.4.4, HPCI Valve Operability Test. Caused by Personnel Error.Procedure initiated.W/891206 Ltr ML19332D1421989-11-22022 November 1989 LER 89-031-00:on 891024,closing Times for Two in-series Primary Containment Isolation Valves Exceeded Acceptance Criteria During Shutdown Testing.Cause Undetermined.Closing Time Retested W/Satisfactory results.W/891122 Ltr ML19332D6231989-11-20020 November 1989 LER 89-032-00:on 891020,pneumatic Pressure Drop for Two of Four Automatic Depressurization Sys Accumulators Discovered Greater than Max Acceptable Value.Caused by Leakage from Seat of Supply Check Valves.Seat replaced.W/891120 Ltr ML19324C3181989-11-0909 November 1989 LER 88-002-01:on 880117,full Reactor Protection Sys Scram Trip Signal Occurred During Surveillance Test,Resulting in Incomplete Actuations.Caused by Procedure Inadequacy.Logic Relay Replaced & Procedure revised.W/891109 Ltr ML19324B1131989-10-21021 October 1989 LER 89-030-00:on 890926,control Room High Efficiency Air Filtration Sys Flowrate non-conservative Due to Procedure Error.Caused by Transcription Error.Procedure Revised & Test Reperformed Using Corrected procedure.W/891021 Ltr ML19325D4681989-10-16016 October 1989 LER 89-029-00:on 890914,locked High Radiation Area Door Found to Have Been Unsecured Contrary to Tech Spec 6.13.2. Caused by Failure to Adhere to Approved Procedures. Training on Access Requirements initiated.W/891016 Ltr ML19325D1861989-10-10010 October 1989 LER 89-028-00:on 890907,HPCI Sys Declared Inoperable Because Mechanical Overspeed Trip Occurred During Surveillance Test. Caused by Failure of Ramp Generator Signal Converter Module. Module Removed & Sent to Mfg for exam.W/891010 Ltr ML17277B8221984-07-20020 July 1984 LER 82-049/01X-1:on 821102,main Steam Line Safety Valve a Set W/Nitrogen at Steam Relief Setting.Caused by Personnel Error.Valve Removed & Replaced W/Properly Set Spare Valve. Procedure revised.W/840720 Ltr ML20024C3231983-06-24024 June 1983 Updated LER 82-038/03X-1:on 820817,RCIC Steam Line High Differential Pressure Alarm Received.Caused by Air in Sensing Lines to Pressure Switches.Cross Threaded Cap Found on in-line Snubber.Snubber replaced.W/830624 Ltr ML20024C2211983-06-24024 June 1983 Updated LER 80-053/03X-1:on 800814,0907 & 14,HPCI Turbine Exhaust Line Snubber 23-3-36 Determined Inoperable.Caused by Transient Hydrodynamic Shock During Startup & Shutdown. Snubbers upgraded.W/830624 Ltr ML20024B8451983-06-24024 June 1983 LER 83-031/03L-0:on 830528,HPCI Sys Made Inoperable to Repair Steam Leak on AO 2301-31.Caused by Leaking Stem Packing.Packing Replaced.Valve Tested Satisfactorily.Sys Returned to svc.W/830624 Ltr ML20024B8321983-06-24024 June 1983 LER 83-030/03L-0:on 830527,both HPCI Area Smoke Detection Sys Alarmed in Main Control Room.Caused by Valve A02301-31 Steam Leak Causing False Indications.Valve repaired.W/830624 Ltr ML20024C3101983-06-21021 June 1983 Updated LER 79-007/03X-1:on 790212,while Performing Test 8.7.4.3,valves AO-5033A,CV-5065-10,15,16 & 17 Failed to Give Proper Position Indication When Cycled & to Close within Specified Tolerance.Cause Not stated.W/830621 Ltr ML20024A8861983-06-16016 June 1983 LER 83-027/03L-0:on 830518,during Routine Insp,Folding Fire Door Found Inoperable.Caused by Operating Cable Becoming Detached from Pulley Due to Slack.Cable Reattached & Operating Mechanism adjusted.W/830616 Ltr ML20023D1691983-05-0909 May 1983 Updated LER 82-008/01X-1:on 820331,HPCI Injection Valve MO-2301-8 Failed to Open in Required Manner.Caused by Missing Wire Jumper Intended to Bypass Motor Operator Torque Switch.Jumper Installed & Valve Tested Satisfactorily ML20023D0671983-05-0909 May 1983 LER 83-021/03L-0:on 830411,during Surveillance Test 8.7.4.3, Primary Containment Isolation Valve AO-5033B Failed to Meet 10-s Closing Time Requirements.Caused by Lubricant Infiltrating Solenoid Valve Components.Components Replaced ML20023D0181983-05-0404 May 1983 LER 83-022/03L-0:on 830413,overload on Valve Motor 1301-17 Resulted in Loss of High Pressure Core Cooling Backup Capability.Caused by Oxidation in Motor End Bell & Motor Brushes,Due to Humidity Caused by Leaking Valve Packing ML20028G1591983-01-28028 January 1983 LER 83-002/01T-0:on 830116,flow Ref off-normal Alarm Received.Average Power Range Monitor Flux Scram Trip Settings Affected.Cause Under Investigation.Flow Inputs Monitored & Amplifier B Recalibr ML20028F4121983-01-17017 January 1983 LER 83-002/01X-0:on 830116,while Clearing off-normal Alarm for Flow Comparators,Average Power Range Monitor Flux Scram Trip Settings Found in Nonconservative Direction.Caused by Drifting Proportional Amplifiers.Settings Checked Daily ML20028B0421982-11-16016 November 1982 LER 82-049/01T-0:on 821102,main Steam Line Safety Valve a Set W/Nitrogen at Steam Relief Setting of 1240 Psig, Exceeding Tech Specs.Caused by Personnel Error.Set Valve Removed,Procedure Adherence Stressed & Procedure Revised ML20027C9801982-10-20020 October 1982 LER 82-039/03L-0:on 820920,timing Tests of Three Reactor Water Cleanup Isolation Valves 1201-2,-5 & -80 Not Completed within Allowed Time.Caused by Operational Constraints Requiring Testing at Reduced Power ML20027C9941982-10-20020 October 1982 LER 82-040/03L-0:on 820920,found Reactor Protection Sys Initiation Function of Turbine Stop Valve Completed 1 Day Late.Caused by Decision to Defer Test Due to MSIV D Line Isolation.Tracking Sys Implemented to Prevent Recurrences ML20052B9141982-04-23023 April 1982 LER 82-010/03L-0:on 820326,during Review of Testing Requirements,Surveillance Test 8.I.4 Standby Liquid Control Sys Found Not Verified.Caused by Breakdown in Multidiscipline Review of Results ML20052F2071982-04-14014 April 1982 Updated LER 81-060/03X-1:on 811020,determined Potential Exists to Reduce Number of Operable APRM & IRM Instrument Channels in Rod Block Trip Sys to Below Tech Spec Min ML20050A6321982-03-19019 March 1982 Updated LER 82-055/01T-1:on 810926,during Shutdown,Yarway Level Indicators Started Oscillating.Drywell Temp Was 240 F at 81-ft W/Elevation Coolant Temp 220 F.Caused by Ineffective Drywell Cooling.Ventilation Returned to Svc ML20050A4521982-03-19019 March 1982 LER 82-006/01T-0:on 820304,while Performing Maint Re SIL 352 on Pressure Adjustment Mechanism HPCI Stop Valve,Three Broken cap-screws Found.No Cause Determined.Screws Examined, Replaced & Sys Returned to Svc ML20050A4331982-03-19019 March 1982 Updated LER 81-062/01X-1:on 811116,Wyle Labs Informed Util That Two Target Rock Safety Relief Valves Had Not Passed Setpoint Tests.Caused by Setpoint Shift Due to Changes to Designed Differential Forces from Excessive Pilot Leakage 1993-07-28
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217E3021999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Pilgrim Nuclear Station.With ML20212C2921999-09-16016 September 1999 SER Accepting Licensee Request for Relief from ASME Code Section XI Requirements as Endorsed by 10CFR50.55a for Containment Insp for Pilgrim Nuclear Power Station ML20216F3511999-09-0808 September 1999 ISI Summary Rept for Refuel Outage 12 at Pnps ML20216E6881999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Pilgrim Nuclear Power Station.With ML20210R3401999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Pilgrim Nuclear Power Station.With ML20209C4731999-07-0707 July 1999 Addendum to SE on Proposed Transfer of Operating License & Matls License from Boston Edison Co to Entergy Nuclear Generation Co ML20209H8251999-07-0101 July 1999 Provides Commission with Evaluation of & Recommendations for Improvement in Processes Used in Staff Review & Approval of Applications for Transfer of Operating Licenses of TMI-1 & Pilgrim Station ML20209E6191999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Pilgrim Nuclear Power Station.With ML20196H2451999-06-29029 June 1999 SER Denying Licensee Proposed Alternative in Relief Request PRR-13,rev 2.Staff Determined That Proposed Alternative Provides Insufficient Info to Determine Adequacy of Scope of Implementation ML20209A8901999-06-28028 June 1999 SER Accepting Licensee Proposed Alternative to Use Code Case N-573 for Remainder of 10-year Interval Pursuant to 10CFR50.55a(a)(3)(i) ML20209B9861999-06-23023 June 1999 Rev 13A to Pilgrim Nuclear Power Station COLR for Cycle 13 ML20217N9061999-06-21021 June 1999 Rept of Changes,Tests & Experiments for Period of 970422-990621 ML20195K3431999-06-15015 June 1999 Safety Evaluation Granting Licensee Request to Use Guidance of GL 90-05 to Repair Flaws in ASME Class 3 Salt Svc Water System Piping for Plant ML20195G8231999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Pnps.With ML20207E7471999-05-27027 May 1999 Safety Evaluation Granting Request Re Reduction of IGSCC Insp of Category D Welds Due to Implementation of HWC to License DPR-35 ML20206M1971999-05-11011 May 1999 SER Accepting Request for Approval to Repair Flaws in ASME Code Class 3 Salt Svc Water Piping at Plant ML20206J6611999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Pilgrim Nuclear Power Station.With ML20205L0221999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Pilgrim Nuclear Power Station.With ML20207J5471999-03-0909 March 1999 Training Simulator,1999 4-Yr Certification Rept ML20207F9401999-03-0101 March 1999 Long Term Program Semi-Annual Rept for Pilgrim Nuclear Power Station ML20207H5451999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Pilgrim Nuclear Power Station.With ML20196E2151998-12-31031 December 1998 1998 Annual Rept for Boston Edison & Securities & Exchange Commission Form 10-K Rept.With ML20206Q2741998-12-31031 December 1998 Monthly Operating Rept for Dec 1998 for Pilgrim Nuclear Power Station.With ML20197J3591998-11-30030 November 1998 Monthly Operating Rept for Nov 1998 for Pilgrim Nuclear Power Station.With ML20195C9951998-10-31031 October 1998 Monthly Operating Rept for Oct 1998 for Pilgrim Nuclear Power Station.With ML20154K0721998-09-30030 September 1998 Monthly Operating Rept for Sept 1998 for Pilgrim Nuclear Power Station.With ML20153D3901998-09-22022 September 1998 Safety Evaluation Granting 970707 Request to Use Guidance in GL 90-05 to Repair Flaws in ASME Class 3 Salt Svc Water Sys Piping for Pilgrim Nuclear Power Station ML20197C5011998-09-0404 September 1998 Rev 12C,Pages 4 & 5 to Pilgrim Nuclear Power Station Colr ML20197C5471998-08-31031 August 1998 Rev 12C to Pilgrim Nuclear Power Station Colr ML20151W8231998-08-31031 August 1998 Monthly Operating Rept for Aug 1998 for Pilgrim Nuclear Power Station.With ML20237E2251998-08-26026 August 1998 Suppl & Revs to SE for Amend 173 for Pigrim Nuclear Power Station ML20237A9941998-07-31031 July 1998 Monthly Operating Rept for Pilgrim Nuclear Power Station ML20236U8201998-07-13013 July 1998 Rev 12B to Pilgrim Nuclear Power Station COLR (Cycle 12) ML20236P0151998-06-30030 June 1998 Monthly Operating Rept for June 1998 for Pilgrim Nuclear Power Station ML20249A3741998-05-31031 May 1998 Monthly Operating Rept for May 1998 for Pilgrim Nuclear Power Station.W/Undated Ltr ML20247H2081998-04-30030 April 1998 Monthly Operating Rept for Apr 1998 for Pilgrim Nuclear Power Station ML20207B7601998-03-31031 March 1998 Final Rept, Pilgrim Nuclear Power Station Site-Specific Offsite Radiological Emergency Preparedenss Prompt Alert & Notification System Quality Assurance Verification, Prepared for FEMA ML20216G3911998-03-31031 March 1998 Monthly Operating Rept for Mar 1998 for Pilgrim Nuclear Power Station ML20216J3741998-03-19019 March 1998 Safety Evaluation Accepting Licensee Request to Evaluate Elevated Tailpipe Temp on Safety Relief Valve SRV 203-3B ML20248L2241998-02-28028 February 1998 Monthly Operating Rept for Feb 1998 for Pilgrim Nuclear Station ML20202G5251998-01-31031 January 1998 Monthly Operating Rept for Jan 1998 for Pilgrim Nuclear Power Station ML20236M8511997-12-31031 December 1997 1997 Annual Rept for Boston Edison & Securities & Exchange Commission Form 10-K Rept ML20198L7701997-12-31031 December 1997 Monthly Operating Rept for Dec 1997 for Pilgrim Nuclear Power Station ML20203D6101997-11-30030 November 1997 Monthly Operating Rept for Nov 1997 for Pilgrim Nuclear Power Station ML20202D5761997-11-0808 November 1997 1997 Evaluated Exercise BECO-LTR-97-111, Monthly Operating Rept for Oct 1997 for Pilgrim Nuclear Power Station1997-10-31031 October 1997 Monthly Operating Rept for Oct 1997 for Pilgrim Nuclear Power Station ML20217D6431997-10-0101 October 1997 Safety Evaluation Granting Request for Approval to Repair Flaws in Accordance W/Gl 90-05 for ASME Class 3 SSW Piping for Pilgrim ML20217H5621997-09-30030 September 1997 Monthly Operating Rept for Sept 1997 for Pilgrim Nuclear Power Station ML20216J4131997-08-31031 August 1997 Monthly Operating Rept for Aug 1997 for Pilgrim Nuclear Power Station ML20210J3321997-07-31031 July 1997 Monthly Operating Rept for Jul 1997 for Pilgrim Nuclear Power Station 1999-09-08
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Text
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g[jI 10 CFR 50.73
. BOSTON EDISON
- Pdgnm Nuclear Power Stahon Rocky Hdl Road Plymouth, Massachusetts o236o E. T. Boulette, PhD Senior V~ c e President--Nuclear June 30 , 1993 BECo Ltr. 93-86 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555 Docket No. 50-293 License No. DPR-35 The enclosed Licensee Event Report (LER) 93-014-00, " Automatic Scram Resulting From Operation of Auxiliary Transformer Differential Relay During Power Ascension", is submitted in accordance with 10 CFR Part 50.73.
Please do not hesitate to contact me if there are any questions regarding this report.
l LY U , .t A
E.T.Boultte},Ph' l DWE/bal
Enclosure:
LER 93-014-00 cc: Mr. Thomas T. Martin Regional Administrator, Region I U.S. Nuclear Regulatory Commission ,
l 475 Allendale Rd.
1 King of Prussia, PA 19406 -
Mr. R. B. Eaton L Div. of Reactor Projects I/II l Office of NRR USNRC l One White Flint North - Mail Stop 1401 L 11555 Rockville Pike l Rockville, MD 20852 L
Sr. NRC Resident Inspector - Pilgrim Station l Standard BEco LER Distribution l
l l 9307090093 930630 PDR ADOCK 05000293
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NRC FORM 366 U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO,3150-0104 i o.o n
ESTtMATED BURDEN PER RESPONSE TO COMPLY WlTH TH!S
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LICENSEE EVENT REPORT (LER) % % % S % T C Rc f n C 5 70T L &"* C AND RECORDS MANAGEMENT BRANCH (MNBU 7714), U 8. NUCLEAR REGULATORY COMMISSION, WASHINGTON. DC 20555 0001, AND TO THE PAPERWORK REDUCTION PRCUECT p1500104), OFFICE (see reverse tot numoer of $g:ts/charac*ers for each tacca) OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
FACILITY NAME (1) , DOCKET NUMBER (2) PAGE (3)
PILGRIM NUCLEAP POWER STATION 05000 -293 1 of 9 I TITLE (4)
Automatic Scram Resulting nom Operation of Auxiliary Transformer Differential Relay During Power Ascension EVENT DATE (5) LER NUMBER (6) REPORT DATE (7) OTHER FACILITIES INVOLVED (8)
SEQUENTIAL REVISION F ACILOY NAME DOCKET NUMBER MONTH CAY YEAR YEAR NUMBER NUMBER MONTH DAY YEAR N/A 05000 F ACluTY NAME DOCKET NUMBER 05 31 93 93 014 00 06 30 93 N/A 05000 OPERATING THIS REPORT IS SUBMITTED PURSUANT TO THE REQUIREMENTS OF 10 CFR 6: (Check one or more)(11)
ODE (9) N 20.402(b) 20.405(c) X 50.73(a)(2)(iv) 73.71(b)
O R g[yE 20.405(a)(1)(i) 50.36(c)(1) 50.73(a)(2)(v) 73.71(c) g 20.405(a)(1)(ii) 50.36(c)(2) 50.73(a)(2)(vii) OTHER 20.405(a)(1)(iii) 50.73(a)(2)(i) 50.73(a)(2)(viii)(A) 20.405(a)(1)(iv) 50.73(a)(2)(ii) 50.73(a)(2)(viii)(B) ,byscgbg 20.405(a)(1)(v) 50.73(a)(2)(iii) 50.73(a)(2)(x) Forma 4 LICENSEE CONTACT FOR THIS LER (12)
NAME TELEPHONE NUMBER (Inchede Area Code)
Douglas W. Ellis - Senior Compliance Engineer (508) 747-8160 COMPLETE ONE LINE FOR EACH COMPONENT FAILURE DESCRIBED IN THIS REPORT (13)
CAUSE SYSifM COMPONENT MANUFACTURER S CAUSE SYSTEM COMPONENT MANUFACTURER 9 SUPPLEMENTAL REPORT EXPECTED (14) " " ' " "# "
EXPECTED YES NO SUBMISSION tit ya. compi te EXPECTED SUDMISSION DATEI y DATE (15)
ABSTRACT (16)
On May 31, 1993, at 1921 hours0.0222 days <br />0.534 hours <br />0.00318 weeks <br />7.309405e-4 months <br />, an automatic scram occurred while at 24 percent reactor power. The event included a trip of the Turbine-Generator and transfer of the Auxiliary Power Distribution System. The scram was the result of the closing of the Turbine Stop Valves while the Turbine first stage pressure was greater than the scram bypass pressure.
The Turbine Stop Valves were closing as a result of the Turbine trip. The Turbine-Generator trip was initiated by the operation of a Unit Auxiliary Transformer differential relay.
The operation of the relay was investigated for cause. The investigation included relay calibration, differential circuit wiring checks, Unit Auxiliary Transformer insulation resistance testing and oil sample analysis, cable insulation resistance testing, breaker testing, and performance of a test approximating the conditions existing at the time of the event. The investigation could not determine the cause for the operation of the '
relay. The unit returned to commercial service on June 3,1993.
This event occurred during power ascension from a refueling outage with the reactor mode selector switch in the RUN position. The Reactor Vessel (RV) pressure was 940 psig with RV water temperature at 540 degrees Fahrenheit. This report is submitted in accordance with 10 CFR 50.73(a)(2)(iv). This event posed no threat to the public health and safety.
NRC FORM 36eA (*192)
NRC FORM*
366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-o104 i s-m EXPIRES 5/31/95 ESTtMATED BURDEN PER RESPONSE TO COMPT.Y Wmi THIS !
LICENSEE EVENT REPORT (LER) L"M O"s EG F#J%nAEJioOJETTs
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TEXT CONTINUATION *$u"$oEc"d*^[ss"oNSYGfGN n N E AG M N D ,WA GT N.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3) veas *iONE N 2 Of 9 PILGRIM NUCLEAR POWER STATION 05000-293 93 --014- 00 TEXT (if more space is required, use additional copies of NRC Form 366A)(17)
BACKGROUND The Auxiliary Power Distribution System (APDS) consists of six 4160 VAC buses. The APDS is divided into emergency service (Buses A5 and A6) and normal service (Buses A1, A2, A3, A4). Buses A5 and A6 supply power to essential loads required during normal operations and abnormal operational transients and accidents. Buses A1, A2, A3, A4 supply power to other station auxiliaries during planned operations. Power is distributed to the six 4160 VAC buses during normal operation from either the unit source (Unit Auxiliary Transformer) or the preferred offsite source (Startup Transformer). The preferred power source is used to supply the 4160 VAC buses during normal startup and shutdown. After the main generator has been synchronized to the 345 KV transmission system, the 4160 VAC buses are transferred from the preferred power source to the unit power source. The 4160 VAC emergency service Buses A5 and A6 can also be supplied from the standby power source (Emergency Diesel Generators 'A' and 'B'), the secondary power source (Shutdown Transformer), or the Station Blackout Diesel Generator (Bus A5 or Bus A6). Located at the end of this report is a figure depicting a simplified single line diagram of the emergency service portion of the APDS and related power sources.
At the time of the event, power ascension from the recent refueling outage (RF0 9) was in progress. Operating conditions and systems' status were as follows:
- The reactor power level was approximately 24 percent with the reactor mode selector switch in the RUN position. The Reactor Vessel (RV) pressure was approximately 940 psig with the RV water temperature at approximately 540 degrees Fahrenheit. The RV water level was approximately +29 inches. The Turbine first stage pressure was approximately 110 psig.
- The Recirculation System motor-generator (MG) sets / pumps 'A' and 'B' were in service in the manual control mode. Core flow was approximately 23 million pounds per hour.
- The 345 KV transmission system lines 342 and 355 were energized. The 345 KV switchyard air type circuit breakers 102, 103, 104 and 105 were closed. The Main Transformer, Start-up Transformer (SUT) and Unit Auxiliary Transformer (UAT) were energized. The Shutdown Transformer (SDT) and Station Blackout Diesel Generator were in st6ndby service.
- Safety-related swing type 480 VAC load center Bus B1 was energized by Bus AS.
- The source of power to the APDS buses was being transferred as part of power ascension.
NHC FOAM 366A (592)
NRC FORM
- 366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 tum EXPIRES 5/31/95 ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS LICENSEE EVENT REPORT (LER) N O TRE O s? %n A E L 17 k "T M L* 2 TEXT CONTINUATION Eu"'[TEC$"i Os's"ON 0N DC x
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FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR R PILGRIM NUCLEAR POWER STATION 05000-293 93 --014-- 00 TEXT (tf more space is required, use additional copies of NRC Form 366A)(17)
The APDS buses were being transferred in accordance with Procedure 2.2.4 (Rev. 9), " Unit Auxiliary Transformer". For a transfer, the synchronizing switch of the bus to be transferred is placed in the ON position, the breaker connecting the UAT to the bus is closed, the breaker connecting the SVT to the bus is opened, the synchronizing switch is placed in the OFF position, and the automatic transfer switch is placed in the ON position. The nonsafety-related buses are transferred first followed by the safety-related buses. After individually transferring Buses Al, A2, A3 and A4 to the VAT, the source of power for Bus A5 was being transferred from the SVT to the UAT. Switchgear breaker 152-505 (A505) was closed and breaker 152-504 (A504) was being opened with the transfer switch in the OFF position.
EVENT DESCRIPTION On May 31,1993, at 1921 hours0.0222 days <br />0.534 hours <br />0.00318 weeks <br />7.309405e-4 months <br />, an automatic Reactor Protection System (RPS) scram signal and scram occurred while at 24 percent reactor oower. The scram signal occurred as a result of a Turbine-Generator trip. The Turbine-u m rator trip was initiated by the actuation of the UAT phase 'C' differential relay 187-3 that actuated the Generator Lockout Relay 286-1. The actuation of relay 286-1 included the following designed responses:
- Automatic transfer of the source of power to Buses A1, A2, A3, and A4 from the UAT to the SUT. Bus A5 and related electrical loads became de-energized and was automatically re-energized by the SDT after a time delay of approximately 12 seconds.
The de-energization of Bus A5 and related 480 VAC Bus B1 and motor control centers (MCCs) resulted in responses that included:
- Automatic transfer of Bus 86 from Bus 81 to Bus 82.
- Automatic actuation of a portion of the Primary Containment Isolation Control System (PCIS) Groups 2,3, and 6 circuitry and Reactor Building Isolation Control System (RBIS). The related inboard Group 2 isolation valves that were open closed automatically. The related Group 3/RHR System Shutdown Cooling (SDC) isolation valves M0-1001-47 and -50 and Low Pressure Coolant Injection (LPCI) injection valves M0-1001-29A/B remained closed. The related inboard Group 6/RWCU System isolation valve MO-1201-2 closed automatically. The Reactor Building Train ' A' supply and exhaust ventilation dampers closed automatically and the Standby Gas Treatment System (SGTS) Train 'A' started automatically.
- Automatic opening of the Generator Field Breaker 41M.
- Automatic actuation of the Turbine Master Trip Solenoid (MTS-1) that initiated a Turbine Trip (VT-1).
NRC FORM 366A (5 02)
NRC FORM*
366A U.S. NUCLEAR REGULATORY COMMISslON APPROVED BY OMB NO. 3150-o104 u-m EXPlRES 5/31/95 l CST: MATED BURDEN PER RESPONSE TO COMPLY WITH THIS LICENSEE EVENT REPORT (LER) 1 %^ M f f f "R E s L T f0 1 Fl O 2 TEXT CONTINUATION N u"tYr E $ Ns5"dN N $ "o"N"" t E A N o"d E TO THE PAPERWOAK NEDUCTION PfniECT (3150-0104), OFFICE OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR IE PILGRIM NUCLEAR POWER STATION 05000-293 93 --014-- 00 TEXT Of more space is required, use additional copies of NRC Form 366A)(17)
The Turbine trip included the following designed responses:
- Closure of the Turbine Stop Valves and Combined Intermediate Valves. The Turbine Stop Valves closure (i.e., not fully open) resulted in the RPS scram signal.
- Closure of the four Turbine Control Valves and the sequential opening of the three Turbine Bypass Valves.
- Actuation of the Turbine Lockout Relay 286-2.
As expected, the RV water level decreased in response to the scram due to a decrease in the void fraction in the RV water. The RV water level eventually decreased to approximately +3 inches. The decrease in RV water level, to less than the low RV water level setpoint (calibrated at approximately +12 inches) resulted in automatic actuations of the PCIS and RBIS.
The PCIS actuation resulted in the following designed responses:
- Automatic closing of the outboard Group 2 isolation valves that were open. The inboard Group 2 isolation valves remained closed.
- The Group 3/RHR System SDC isolation valves M0-1001-47 and -50 remained closed. The Group 3/RHR LPCI valves M0-1001-29A/B remained closed.
. Automatic closing of the outboard Group 6/RWCU System isolation valves M0-1201-5 and
-80. The inboard Group 6 isolation valve M0-1201-2 remained closed.
The RBIS actuation resulted in the automatic closing of the Reactor Building / Secondary Containment System (SCS) Train 'B' supply and exhaust ventilation dampers and automatic start of the SGTS Train 'B'. The Train 'A' ventilation dampers remained closed and the SGTS Train 'A' remained in service.
Initial Control Room operator response was orderly and included the following. The reactor mode selector switch was moved from the RUN position to the SHUTDOWN position and all control rods were verified to be inserted in accordance with procedure 2.1.6, " Reactor Scram". Emergency Operating Procedure E0P-01, "RPV Control", was initiated because the RV water level decreased to less than +9 inches. Procedure 2.1.7, " Vessel Heatup and Cooldown", was initiated.
The PCIS circuitry was reset and the RWCU System was returned to service at 1934 hours0.0224 days <br />0.537 hours <br />0.0032 weeks <br />7.35887e-4 months <br />.
The RPS was reset at 1950 hours0.0226 days <br />0.542 hours <br />0.00322 weeks <br />7.41975e-4 months <br />. At 1953 hours0.0226 days <br />0.543 hours <br />0.00323 weeks <br />7.431165e-4 months <br />, the source of power for Bus A5 was transferred from the SDT to the SVT. The RBIS circuitry was reset, the SGTS was returned to standby service, and the Reactor Building ventilation system was returned to service at 2010 hours0.0233 days <br />0.558 hours <br />0.00332 weeks <br />7.64805e-4 months <br />. The Recirculation System MG set / pump 'A' was restarted at 2026 hours0.0234 days <br />0.563 hours <br />0.00335 weeks <br />7.70893e-4 months <br />. After resetting the Generator Lockout Relay 286-1, the 345 KV switchyard ring bus was restored at 2057 hours0.0238 days <br />0.571 hours <br />0.0034 weeks <br />7.826885e-4 months <br /> when ACBs 104 and 105 were reclosed. E0P-01 was terminated at 2101 hours0.0243 days <br />0.584 hours <br />0.00347 weeks <br />7.994305e-4 months <br />.
l WC FOAM 36eA $92)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-o104 i s-m, EXPlRES 5/31/95 ESTlMATED BURDEN PER RESPONSE TO COMPLY WITH THis LICENSEE EVENT REPORT (LER) ZTO&"
WJ'a'L"##r*LJf00NA"Mi TEXT CONTINUATION EttN"Rv Cdu7s'sEENEN*tNsSdx7IN TO THE PAPERWORK REDUCTION PROJECT (3150-0104), OF FICE OF MANAGEMENT AND BUDGET, WASHINGTON, DC 20503.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR D N PILGRIM NUCLEAR POWER STATION 05000-293 93 --014-- 00 TEXT (if more space is required, use additional copies of NRC Form 366A)(17)
On June 1,1993, at 0205 hours0.00237 days <br />0.0569 hours <br />3.38955e-4 weeks <br />7.80025e-5 months <br />, the Recirculation System Loop 'B' MG set / pump was removed from service and the RHR System Loop 'B' was put into service in the SDC mode with one pump in service.
Problem Report 93.9283 was written to document the event. The NRC Operations Center was notified of the event in accordance with 10 CFR 50.72 at 2013 hours0.0233 days <br />0.559 hours <br />0.00333 weeks <br />7.659465e-4 months <br /> on May 31, 1993.
A post trip review of the event was initiated in accordance with procedure 1.3.37 (Rev. 8), " Post Trip Reviews".
'.AUSE The cause of the scram was the closing of the Turbine Stop Valves (i.e., not full open) with the Turbine first stage pressure at approximately 110 psig.
The cause of the operation of the UAT phase 'C' differential relay 187-3 was investigated.
The investigation revealed no reason for the operation of the relay. The following possible causes were investigated and were eliminated as the probable cause of the operation of the relay (Westinghouse type HU-1, style 2908346A10):
- Actuation of the UAT overcurrent differential circuit:
- Visual inspection and checks of connections for tightness were satisfactory.
e The phase 'A', 'B', 'C' current transformers were saturation tested with satisfactory as-found results.
. The phase 'C' relay 187-3 was calibrated with satisfactory as-found results.
- A loose screw was found and removed from the phase 'C' relay 187-3. The loose screw, located inside and at the bottom of the relay housing, was not believed i to be the cause of the trip of the relay.
l
- The phase 'B' and 'C' relays (187-3) were interchanged for investigative l purposes in anticipation of planned testing (TP 93-101).
- Fault in the UAT, Isophase Bus Ducts, or cables from the UAT to the APDS buses:
- The UAT was insulation resistance tested with satisfactory as-found results.
. An oil sample from the UAT was analyzed for dissolved gases. The analysis results were found to be in the normal range.
- The Isophase Bus Ducts connecting the Generator to the Main Transformer and UAT were insulation resistance tested with satisfactory as-found results.
The 4160 VAC cables from the UAT to the APDS buses were insulation resistance tested with satisfactory as-found results.
A RC FORM 366A (S-92)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104 Mg EXPIRES 5/31/95 EST1 MATED BURDEN PER RCSPONSE TO COMPLY WITH THS LICENSEE EVENT REPORT (LER) 2"MTEE3fJ0J 3*0Jf0O @ 2 TEXT CONTINUATION $51NY $CESSEESIN O DC% 0 3 3" = = J f R = & % T i "
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR R N7MB PILGRIM NUCLEAR POWER STATION 05000-293 93 --014 -- 00 TEXT (11 more space is required, use additional copies of NRC Form 366A)(17)
- Fault or misoperation of the Bus A5 switchgear breakers 152-5d4 or 152-505:
The breakers were tested. The testing consisted of timing, contact resistance, phase-to-phase and phase-to-ground insulation resistance tests. The tests were completed with satisfactory as-found results.
Interfacing components that could not be verified by the methods noted above were tested as part of Procedure TP 93-101 (Rev. 0), "A5 Transfer.Between Startup and Unit Auxiliary Transformer". The procedure was written to approximate the conditions existing at the time of the event on May 31, 1993. The test included the start of selected electrical
- loads, and transfer of APDS buses from the SVT to the VAT. Buses Al, A2, A3, and A4, and A5 were transferred with satisfactory results. After the transfer of Bus A5 to the VAT, Bus A5 was transferred to the SVT and then back to the UAT. Bus A5 was transferred to and from the UAT and SUT four times. The transfers occurred with satisfactory results.
During the performance of TP 93-101, a circulating current of approximately 500 amperes was detected while both the VAT and SUT were powering Bus A5 in parallel. Circulating currents during bus transfers have been observed in the past. This information and the differential relay current input readings measured during the performance of TP 93-101 were provided to the Nuclear Engineering Department for further analysis. If the analysis reveals significant new information regarding the cause of the operatior of the differential relay, this report will be supplemented.
CORRECTIVE ACTION The UAT phase 'B' and 'C' differential relays were left interchanged as an investigative aid in the event the VAT differential circuit operates in the future.
The unit returned to commercial service at 2322 hours0.0269 days <br />0.645 hours <br />0.00384 weeks <br />8.83521e-4 months <br /> on June 3, 1993.
The source of power for the APDS including Bus A5 was subsequently transferred from the SUT to the VAT with satisfactory results.
SAFETY CONSEQUENCES The Standby AC Power (4160 VAC) System consists of EDGs ' A' and 'B' that are self contained and independent of the offsite power sources. Bus A5 and related AC powered load center busses, motor control centers, and distribution panels including Panels Y3 and C-941 became de-energized for approximately 12 seconds. Bus A5 and related electrical system became de-energized due to the automatic opening of switchgear breaker 152-505 while breaker 152-504 was open. Breaker 152-504 was open and did not close because the Bus A5 transfer switch was in the 0FF position at the time for the transfer. The EDG 'A' did not start as a result of Bus A5 becoming de-energized (i.e., switchgear breakers 152-504 and 152-505 open) because the SVT-Bus A5 degraded voltage relays are connected to the 4160 VAC feeder cables on the SVT side of switchgear breaker 152-504. The SVT remained energized during the event. The SDT automatically re-energized Bus A5 after a designed time delay of approximately 12 seconds NHC FORM 366A p 02)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-o104 n-q -
EXPIRES 5/31/95 ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS LICENSEE EVENT REPORT (LER) ECE"Mo'S0J3%Mohsu"*r's TEXT CONTINUATION $"tEro"nv*c"cEs' sees $"d7 ens'oEE 1%="#1"MTas"ERT= ""
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR M NU PILGRIM NUCLEAR POWER STATION 05000-293 93 -014- 00 TEXT (tt more space is required, use additional copas of NRC Form 366A)(17)
The post trip review included safety assessments regarding transient RV and reactor parameters, the initiating RPS trip signal, Drywell pressure and temperature, Suppression Pool water level and temperature, and safety limits. The assessments concluded automatic actions that occurred should have, the initiating RPS trip signal was appropriate for this event, Technical Specifications were met, and safety limits were not exceeded.
The decrease in the RV water level was the expected response to the scram and accompanying shrink in the RV water. The Technical Specifications 3.1 and 3.2. A trip setting for a low RV water level is > +9 inches. The resulting PCIS and RBIS actuations were the expected designed responses to a low RV water le/el condition (i.e., less than the calibrated setting of approximately +12 inches).
This report is submitted in accordance with 10 CFR 50.73(a)(2)(iv) because the actuation of the RPS, although an expected designed response to the closing of the Turbine Stop Valves with the Turbine first stage pressure at greater than approximately 108 psig, was not planned. This report is also submitted in accordance with subpart (a)(2)(iv) because the actuation of portions of the PCIS and RBIS, although a designed response to the de-energization of relays powered from Bus A5 via Bus Bl/MCC-B17/ Panels Y3 and C-941, was not planned.
SIMILARITY TO PREVIOUS EVENTS A review was conducted of Pilgrim Station Licensee Event Reports (LERs) submitted since January 1984. The review focused on LERs submitted in accordance with 10 CFR 50.73(a)(2)(iv) that involved a similar scram due to the operation of the UAT differential circuitry or other Main Generator protective circuits. The review identified no scrams due to the operation of the VAT differential circuit and identified somewhat similar events involving the operation of other Main Generator circuits reported in LERs 50-293/89-026-01 and 90-008-00.
For LER 89-026-01, an automatic scram occurred on August 30, 1989, at 1917 hours0.0222 days <br />0.533 hours <br />0.00317 weeks <br />7.294185e-4 months <br />, while at 65 percent reactor power. The cause of the scram signal was high RV pressure (ultimately 1069 psig) that occurred as a result of an automatic Turbine runback. The runback included the automatic adjustment of the Turbine Control Valves and sequential opening of the Turbine Bypass Valves. The runback occurred as a result of the failure of the primary winding of the Main Generator 24 KV phase ' A' potential transformer and a Generator Voltage Balance Relay 260 (General Electric type CFVB) wiring error that affected the transfer function of the Generator's Voltage Regulator. The wiring error was due to a drawing error. The error was not previously detected because the surveillance test prccedure (3.M.3-39) used to functionally test the relay, although demonstrating the vcitage balance relay functions and alarm functions, did not include a step to identify the auxiliary relay that actuates the same alarm (Panel C-3R, " Generator Potential Fuse Blown"). Corrective action taken included correction of the wiring error after correcting ;
the drawing and revision of the surveillance procedure to identify the specific auxiliary ;
relay that actuates when the relays are actuated during functional testing of the voltage 1 balance relay.
MC F DAM 366 A [t3 94 I
~ - - . - . _ - . . . . . -. _ _~ .. - - - . .. - - _ _ - - . ._. ...
i NRC FORM 366A U.S. NUCLEAR REGULATORV COMMISSION APPROVED DV OMD NO. 31504104 l naq
- EXPlRES 5/31/95 l ESTIMArED BURDEN PER RESPONSE TO COMPW WITH THIS LICENSEE EVENT REPORT (LER) l$3"OSE30Talu"Ro"e'NTT%ArWo OiNFs22 TEXT CONTINUATlON $S ErE c"$v"Ils"N E Nr"OI"E N d"[ $$
TO THE PAPERWORK REDUCTION PHOJECT (3150 0104), OFFICE OF MANAGEMENT AND BUDOET, WASHINGTON, DC 20603.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER (6) PAGE (3)
YEAR I NU PILGRIM NUCLEAR POWER STATION 05000-293 93 --014 - 00 TEXT pt more space is required. use additional copies of NRC Form 360A)(17)
For LER 90-008-00, an automatic scram due to a load rejection occurred on May 13, 1990, at 1603 hours0.0186 days <br />0.445 hours <br />0.00265 weeks <br />6.099415e-4 months <br />, while at 100 percent reactor power. The load rejection was caused by a momentary fault on the offsite 345 KV transmission system. The Main Generator's Loss of Field Relay 240 detected the fault and immediately tripped the generator without an expected 15 cycle time delay because one of its components, the telephone relay coil, was de fect ive . The relay had been calibrated and functionally tested on October 26, 1989. At that time, the operation of the coil was tested in accordance with the vendor manual. The relay's time delay was built-in and not adjustable, and was not required to be timed. The relay was installed during plant construction (c. 1972). The cause for the open coil was investigated and believed to be a random or age-related failure. The relay was the only one of its type (Westinghouse type KLF-1) installed at Pilgrim Station and was replaced with another type KLF-1 relay having an adjustable time delay. The relay's calibration sheet was revised to include a calibration of thc adjustable time delay.
ENERGY INDUSTRY IDENTIFICATION SYSTEM (EIIS) CODES The EIIS codes for this report are as follows:
COMPONENTS CODES Relay, Differential Protective (187-3) 87 Transformer (UAT) XFMR SYSTEMS Containment Isolation Control System (PCIS, RBIS) JM Engineered Safety Features Actuation System JE (PCIS, RBIS, RPS)
Medium-Voltage Power System EA Plant Protection System (RPS) JC Reactor Water Cleanup (RWCU) System CE Standby Gas Treatment System (SGTS) BH l
l NRC FORM 366A (592)
NRC FORM 366A U.S. NUCLEAR REGULATORY COMMISSION APPROVED BY OMB NO. 3150-0104
. o,-u ; EXPIRES 0/31/95 ESTIMATED BURDEN PER RESPONSE TO COMPLY WITH THIS gg INFORMATON COLLECTON NEQUEST. 60 0 HRS FORWARD CE SE ggfE aW T REPOgT I4 (fg 3.
IIf COMMENTS REGARDING BURDEN ESTIMATE TO THE INFORMATION AND NFCORDs MANAGF MENT HRANr.H tvNRR ??14'. U 5 NUCtE AR TEXT CONTINUATION REculATORY COMWSSON. WASHINGTON, DC 20SSS000t, AND TO THE PAPERWORK REDUCTON PRClJECT (3150 0904;, OFFICE OF M ANAGEMENT AND BUDGET, W ARHtNGTON, DC 20503.
FACILITY NAME (1) DOCKET NUMBER (2) LER NUMBER 16) PAGE (3)
SEQUENTIAL REviRION YEAR NUMBER NUMelER P!LGRIM NUCLEAR POWER STATION 05000 293 9 Of 9 93 014 00 TEXT (it more space is required, use accitsonal copies of NRC Form 366A)(17)
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