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Category:LICENSEE EVENT REPORT (SEE ALSO AO
MONTHYEARML17355A3891999-07-20020 July 1999 LER 99-001-00:on 990623,manual Rt from 100% Power Following Multiple Control Rod Drops Was Noted.Caused by Manual Action Taken by Reactor Control Operator.Inspected & Repaired Stationary Gripper Regulating Cards.With 990720 Ltr ML17354B1921998-11-18018 November 1998 LER 98-007-00:on 981020,containment Purge Supply,Valve Opened Wider than TS Limit.Caused by Improper Setting of Mechanical Stops.Incorporated Improved Standard Method of Measuring Angular Valve Position Into Sp.With 981118 Ltr ML17354B1361998-10-16016 October 1998 LER 98-004-00:on 980921,automatic Reactor Trip Occurred. Caused by Inadequate re-correlation of Intermediate Range Neutron Flux Instrumentation Reactor Trip Bistable. Enhanced Applicable Plant Procedures.With 981016 Ltr ML17354B0341998-07-15015 July 1998 LER 98-003-00:on 980619,discovered That Auxiliary Feedwater Sys Was Inoperable Due to Inadequate Inservice Testing of Valves.Caused by Misunderstanding of Testing Criteria.Util Revised Procedures & Verified Operability of Valves ML17354A9841998-06-18018 June 1998 LER 97-007-01:on 970730,automatic Reactor Trip Occurred Due to Closure of B Msiv.Caused by Failed BFD22S Relay.Six Relays on 3A,3B & 3C MSIVs Were Replaced & Implemented Plant Change to Disable Electronic Trip Function on 3 AFW Pumps ML17354A9741998-06-0909 June 1998 LER 98-002-00:on 980513,discovered Potential LOCA-initiated Electrical Fault Which Places ECCS Outside Design Basis. Caused by Inadequate Review of Effect on non-safety Circuit failures.Re-powered PC-*-600A Relays ML17354A8511998-03-24024 March 1998 LER 97-009-01:on 971114,discovered That CR Console Switch for 3B Sgfp Was Not in Start Position.Caused by Inadequate Procedural Guidance.Revised Procedures 3/4-OP-074,informed Personnel of Event & Performed Walkdown of CR ML17354A8441998-03-18018 March 1998 LER 98-001-00:on 980216,manual Reactor Trip Occurred Due to Loss of Turbine Control Oil Pressure W/Steam Leak in Auxiliary Feedwater Steam Supply Piping.Auxiliary Governor Maint Instructions Will Be revised.W/980318 Ltr ML17354A7361997-12-12012 December 1997 LER 97-009-01:on 971114,identified That CR Console Switch for 3B SG Feedwater Pump Was Not in Start Position.Caused by Inadequate Procedural Guidance.Procedures 3/4-OP-074,SGFP Were revised.W/971212 Ltr ML17354A6801997-10-0808 October 1997 LER 97-008-00:on 970909,containment Sump Debris Screens Outside Design Basis Due to Stress Damage Was Discovered. Caused by Inadequate Procedural Guidance & Personnel Error. Discrepancies Found on Screens corrected.W/971008 Ltr ML17354A6121997-08-29029 August 1997 LER 97-007-00:on 970730,automatic Reactor Trip Occurred. Caused by Closure of B Main Steam Isolation Valve.Failed W Relay & Equivalent Relays Were replaced.W/970829 Ltr ML17354A6081997-08-18018 August 1997 LER 97-006-00:on 970722,manual Reactor Trip Occurred Due to Failed Rod Control Power Supplies.Replaced Twelve Power Supplies in Rod Control Logic & Power cabinets.W/970818 Ltr ML17354A5801997-07-14014 July 1997 LER 97-005-00:on 970618,RCP Oil Collection Sys Was Found Outside Design Basis.Caused Because Design Did Not Consider Component Parts to Be Potential Leakage Sources.Entire RCP Oil Collection Sys Was reviewed.W/970714 Ltr ML17354A5141997-05-22022 May 1997 LER 97-002-00:on 970423,automatic Reactor Tripped.Caused by Actuation of Turbine Overspeed Protection Circuit. Administrative Procedures Governing Inadequate Work Controls Will Be Revised to Capture Lessons learned.W/970522 Ltr ML17354A5061997-05-0909 May 1997 LER 97-003-00:on 970410,mode Changed W/O Meeting Requirements of TS 3.0.4 Due to Inadequate Procedural Guidance.Night Order Was Issued to Inform Personnel That S/G Blowdown Keylock Switches Were Left in drain.W/970509 Ltr ML17354A5051997-05-0909 May 1997 LER 97-004-00:on 970411,auxiliary Feedwater Automatic Start Upon Trip of All Main Feedwater Pumps,Occurred.Caused by Mispositioned Valve Closing.Valves Listed as Inappropriately Positioned Were repositioned.W/970509 Ltr ML17354A4781997-04-25025 April 1997 LER 97-001-00:on 970327,ECCS Recirculation Loop Leakage Was Found to Be in Condition Outside Design Basis Due to Gasket Movement During Installation During Spring 1966 Reassembly. Gasket Replaced & Pump tested.W/970425 Ltr ML17354A4581997-03-28028 March 1997 LER 97-002-00:on 970303,manual Reactor Trip Following Rod Control Urgent Failure Alarm Occurred.Caused by Phase Failure Detection on Stationary a Circuits of 2BD Rod Control Cabinet.Air Conditioning replaced.W/970328 Ltr ML17354A4511997-03-26026 March 1997 LER 97-001-00:on 970118,missed Surveillance on CR Position Verification Occurred Due to Inoperable Rod Deviation Monitor.Faulty Circuit Common Connection Was Corrected & Rdm Operability Was restored.W/970326 Ltr ML17354A4061997-02-0303 February 1997 LER 96-004-03:on 970107,identified Three Instances of Inadequate Surveillance Testing.Caused by Inadequate Surveillance Procedures.Surveillance Procedures Revised ML17354A3771996-12-27027 December 1996 LER 96-012-00:on 961204,determined Containment Average Temp Being Determined Based on Only Two Temp Elements Instead of Three as Required by Tss.Caused by Log Only Requiring One Entry.Log revised.W/961227 Ltr ML17354A3261996-11-0606 November 1996 LER 96-011-00:on 961009,potential for Overpressurizing Post Accident Containment Vent Filter Housings Occurred.Caused by Improper Change Mgt.Monitoring Sys Operating Procedures revised.W/961106 Ltr ML17354A3071996-10-22022 October 1996 LER 96-010-00:on 960924,manual Reactor Shutdown Occurred. Caused by Failed Rod Control Sys Regulation Card in 2AC Power cabinet.2AC Power Cabinet DC Power Supplies,Cabling & Connectors checked.W/961022 Ltr ML17353A8711996-08-27027 August 1996 LER 96-009-00:on 960729,failed to Reflect Heavy Load Design Info in Procedural Controls.Caused by Failure to Incorporate 1982 Procedure Changes.Suspended Lifting of Heavy Loads & Took Turbine Bldg Crane OOS.W/960827 Ltr ML17353A7411996-06-18018 June 1996 LER 96-008-00:on 960521,surveillance Method for Testing Emergency Diesel Generators (EDG) Determined Inadequate. Caused by Personnel Error.All Four EDGs Rapid Start Tested & EDG Surveillance Procedures modified.W/960618 Ltr ML17353A7401996-06-18018 June 1996 LER 96-004-02:on 960524,identified Inadequate Surveillance Testing.Caused by Inadequate Surveillance Procedures.Entered Tech Spec Statements,Tested Required Instruments Functions & Revised Plant procedure.W/960618 Ltr ML17353A6901996-05-13013 May 1996 LER 96-004-01:on 960220,identified Potential Tech Spec non-compliance Associated W/Surveillance Testing of AFW Actuation Circuitry on Sg.Caused by Inadequate Surveillance Procedures.Procedures revised.W/960513 Ltr ML17353A6741996-05-0606 May 1996 LER 96-001-00:on 960409,manual Rt Occurred Due to Turbine Governer Control Oil Perturbation.Disassembled & Inspected Governor Valve for Cleanliness & Corrosion products.W/960506 Ltr ML17353A6651996-04-29029 April 1996 LER 96-007-00:on 960329,inadvertent ESF Actuation Occurred During Refueling Outage Due to Cognitive Personnel Error. Personnel Involved Counseled & Integrated Safeguards Test Procedures Being revised.W/960429 Ltr ML17353A6601996-04-25025 April 1996 LER 96-006-00:on 960327,manual Rt Occurred Due to 3C Transformer Lockout & Loss of 3B SG Mfp.Replaced SAM Timer Relay in 3AC16.W/960425 Ltr ML17353A6491996-04-23023 April 1996 LER 96-005-00:on 960326,certain Safety Injection Accumulator Filled Evolutions Resulted in cross-tied Configuration.C/A: Night Order Written & Operations Procedure 3/4-OP-064 revised.W/960423 Ltr ML17353A6051996-03-18018 March 1996 LER 96-003-00:on 960222,two Arpi Inoperable & TS 3.0.3 Entered.Proposed License Amend Submitted to Revise Allowed Misalignment from +/-12 Steps to =/-18 Steps Between Arpi & Dpi at Less than 90% power.W/960318 Ltr ML17353A6041996-03-18018 March 1996 LER 96-004-00:on 960220,surveillance Testing of AFW Actuation Circuitry Was Inadequate.Caused by Inadequate Surveillance Procedures.Tested Untested Portions of Actuation Logic for AFW Automatic Start signal.W/960318 Ltr ML17353A5861996-03-0606 March 1996 LER 96-002-00:on 960209,automatic Turbine Trip/Rt Occurred Due to High SG Level.Caused by Personnel Error.Replaced Both Hinge Pins on B Sgfp Discharge Check valve.W/960306 Ltr ML17353A5761996-03-0101 March 1996 LER 96-001-00:on 960131,intake CWS Flow Rates Found W/ Potential to Be Less than Required by Design Basis.Caused by Influx of Aquatic Grass & Algae Onto Basket Strainers of Icw Flow Path.Mechanically Cleaned strainers.W/960301 Ltr ML17353A4451995-11-0909 November 1995 LER 95-007-00:on 951017,manual Rt Occurred Following Drop of Four Control Rods.Caused by Water Intrusion Into Rod Control Power Cabinet 2BD.Inspected Control Power Cabinet 2BD for Other Water damage.W/951109 Ltr ML17353A4241995-10-12012 October 1995 LER 95-006-00:on 950913,analysis Showed That CCW Exchangers Susceptible to Damage Due to flow-induced Vibration.Ccw Sys Has Been Flow Balanced to Closer tolerances.W/951012 Ltr ML17353A3601995-09-13013 September 1995 LER 95-005-00:on 950818,containment Pressure Testing Procedure Resulted in Inhibiting Both Trains of Containment Pressure from Initiated Esf.Revised Procedure to Require Testing of Each Train separately.W/950913 Ltr ML17353A2951995-07-17017 July 1995 LER 94-005-02:on 941103,both Units Outside Design Basis Due to Design Defect in Safeguards Bus Sequencer Test Logic. Resumed Monthly Manual Testing of Sequencer ML17352B1581995-05-0505 May 1995 LER 95-004-00:on 950407,unit Being Shutdown to Investigate Recurring non-urgent Failure Alarms from Redundant Rod Control Power Supplies.Reactor Manually Tripped.All Four PS-3 Power Supplies replaced.W/950505 Ltr ML17352B1181995-04-0707 April 1995 LER 95-003-00:on 950309,intake Cooling Water Flow Rate Through CCW Heat Exchangers Fell Below Assumed Design Basis. Caused by an Influx of Aquatic Grass & Algae Onto Basket Strainers.Strainers cleaned.W/950407 Ltr ML17352B0701995-03-13013 March 1995 LER 95-002-00:on 950215,inadequate Definition of Loops Filled Resulted in Units in Condition Prohibited by Ts. Issued TS Position Statement to Define Term Loops Filled as Used in TS 6.4.1.1.4.W/950313 Ltr ML17352B0321995-02-0909 February 1995 LER 94-005-01:on 941103,design Defect Found in Safeguards Bus Sequencer Test Logic,Placing Facility Outside Design Basis.Design Mods to Eliminate Software Logic Problems Will Be Implemented During Next Refueling outages.W/950209 Ltr ML17352B0101995-01-20020 January 1995 LER 94-006-00:on 941226,C Main Feedwater Control Valve Failed Closed,Causing Reactor & Turbine Trips.Caused by Loose Screw Terminal Connection.I/P Transducers Replaced W/ New Model W/Different Design Wire connection.W/950120 Ltr ML17352A9511994-12-13013 December 1994 LER 94-006-00:on 941130,Unit 4 Tripped Automatically.Caused by Failure of Flexible Link Connection Between Main Generator B Phase Bus & Associated Isolated Phase Bus Bar. All Bolts on Flexible Link checked.W/941213 Ltr ML17352A8871994-11-10010 November 1994 LER 94-005-00:on 941103,design Defect in Safeguards Bus Sequencer Test Logic Places Both Units Outside Design Basis. Caused by 3A Sequencer Failed to Respond as Expected to Opposite Unit SI signal.W/941110 Ltr ML17352A8851994-11-10010 November 1994 LER 94-004-00:on 941103,Unit 3 Outside Design Basis Due to Two of Three Required Safety Injection Pumps Inoperable. Control Switches for 3A & 3B Safety Injection Pumps Immediately Returned to automatic.W/941110 Ltr ML17352A8421994-10-21021 October 1994 LER 94-004-00:on 940923,Unit 4 Tripped Automatically from Rated Power.Caused by Faulty Regulator Transistor.Faulty Backup Power Supply Replaced & Maint History for Power Supplies reviewed.W/941021 Ltr ML17352A8431994-10-20020 October 1994 LER 94-005-00:on 940924,Unit 4 Manually Tripped.Caused by Manual Actuation.Light Bulb & Socket replaced.W/941020 Ltr ML17352B1671994-08-16016 August 1994 LER 94-003-00:on 940720 & 21,util Discovered That Several Required Valve Stroke Time Surveillances Had Not Been Performed.Caused by Personnel Error.Personnel Reassigned & Procedures and Surveillance Tracking Software Enhanced 1999-07-20
[Table view] Category:RO)
MONTHYEARML17355A3891999-07-20020 July 1999 LER 99-001-00:on 990623,manual Rt from 100% Power Following Multiple Control Rod Drops Was Noted.Caused by Manual Action Taken by Reactor Control Operator.Inspected & Repaired Stationary Gripper Regulating Cards.With 990720 Ltr ML17354B1921998-11-18018 November 1998 LER 98-007-00:on 981020,containment Purge Supply,Valve Opened Wider than TS Limit.Caused by Improper Setting of Mechanical Stops.Incorporated Improved Standard Method of Measuring Angular Valve Position Into Sp.With 981118 Ltr ML17354B1361998-10-16016 October 1998 LER 98-004-00:on 980921,automatic Reactor Trip Occurred. Caused by Inadequate re-correlation of Intermediate Range Neutron Flux Instrumentation Reactor Trip Bistable. Enhanced Applicable Plant Procedures.With 981016 Ltr ML17354B0341998-07-15015 July 1998 LER 98-003-00:on 980619,discovered That Auxiliary Feedwater Sys Was Inoperable Due to Inadequate Inservice Testing of Valves.Caused by Misunderstanding of Testing Criteria.Util Revised Procedures & Verified Operability of Valves ML17354A9841998-06-18018 June 1998 LER 97-007-01:on 970730,automatic Reactor Trip Occurred Due to Closure of B Msiv.Caused by Failed BFD22S Relay.Six Relays on 3A,3B & 3C MSIVs Were Replaced & Implemented Plant Change to Disable Electronic Trip Function on 3 AFW Pumps ML17354A9741998-06-0909 June 1998 LER 98-002-00:on 980513,discovered Potential LOCA-initiated Electrical Fault Which Places ECCS Outside Design Basis. Caused by Inadequate Review of Effect on non-safety Circuit failures.Re-powered PC-*-600A Relays ML17354A8511998-03-24024 March 1998 LER 97-009-01:on 971114,discovered That CR Console Switch for 3B Sgfp Was Not in Start Position.Caused by Inadequate Procedural Guidance.Revised Procedures 3/4-OP-074,informed Personnel of Event & Performed Walkdown of CR ML17354A8441998-03-18018 March 1998 LER 98-001-00:on 980216,manual Reactor Trip Occurred Due to Loss of Turbine Control Oil Pressure W/Steam Leak in Auxiliary Feedwater Steam Supply Piping.Auxiliary Governor Maint Instructions Will Be revised.W/980318 Ltr ML17354A7361997-12-12012 December 1997 LER 97-009-01:on 971114,identified That CR Console Switch for 3B SG Feedwater Pump Was Not in Start Position.Caused by Inadequate Procedural Guidance.Procedures 3/4-OP-074,SGFP Were revised.W/971212 Ltr ML17354A6801997-10-0808 October 1997 LER 97-008-00:on 970909,containment Sump Debris Screens Outside Design Basis Due to Stress Damage Was Discovered. Caused by Inadequate Procedural Guidance & Personnel Error. Discrepancies Found on Screens corrected.W/971008 Ltr ML17354A6121997-08-29029 August 1997 LER 97-007-00:on 970730,automatic Reactor Trip Occurred. Caused by Closure of B Main Steam Isolation Valve.Failed W Relay & Equivalent Relays Were replaced.W/970829 Ltr ML17354A6081997-08-18018 August 1997 LER 97-006-00:on 970722,manual Reactor Trip Occurred Due to Failed Rod Control Power Supplies.Replaced Twelve Power Supplies in Rod Control Logic & Power cabinets.W/970818 Ltr ML17354A5801997-07-14014 July 1997 LER 97-005-00:on 970618,RCP Oil Collection Sys Was Found Outside Design Basis.Caused Because Design Did Not Consider Component Parts to Be Potential Leakage Sources.Entire RCP Oil Collection Sys Was reviewed.W/970714 Ltr ML17354A5141997-05-22022 May 1997 LER 97-002-00:on 970423,automatic Reactor Tripped.Caused by Actuation of Turbine Overspeed Protection Circuit. Administrative Procedures Governing Inadequate Work Controls Will Be Revised to Capture Lessons learned.W/970522 Ltr ML17354A5061997-05-0909 May 1997 LER 97-003-00:on 970410,mode Changed W/O Meeting Requirements of TS 3.0.4 Due to Inadequate Procedural Guidance.Night Order Was Issued to Inform Personnel That S/G Blowdown Keylock Switches Were Left in drain.W/970509 Ltr ML17354A5051997-05-0909 May 1997 LER 97-004-00:on 970411,auxiliary Feedwater Automatic Start Upon Trip of All Main Feedwater Pumps,Occurred.Caused by Mispositioned Valve Closing.Valves Listed as Inappropriately Positioned Were repositioned.W/970509 Ltr ML17354A4781997-04-25025 April 1997 LER 97-001-00:on 970327,ECCS Recirculation Loop Leakage Was Found to Be in Condition Outside Design Basis Due to Gasket Movement During Installation During Spring 1966 Reassembly. Gasket Replaced & Pump tested.W/970425 Ltr ML17354A4581997-03-28028 March 1997 LER 97-002-00:on 970303,manual Reactor Trip Following Rod Control Urgent Failure Alarm Occurred.Caused by Phase Failure Detection on Stationary a Circuits of 2BD Rod Control Cabinet.Air Conditioning replaced.W/970328 Ltr ML17354A4511997-03-26026 March 1997 LER 97-001-00:on 970118,missed Surveillance on CR Position Verification Occurred Due to Inoperable Rod Deviation Monitor.Faulty Circuit Common Connection Was Corrected & Rdm Operability Was restored.W/970326 Ltr ML17354A4061997-02-0303 February 1997 LER 96-004-03:on 970107,identified Three Instances of Inadequate Surveillance Testing.Caused by Inadequate Surveillance Procedures.Surveillance Procedures Revised ML17354A3771996-12-27027 December 1996 LER 96-012-00:on 961204,determined Containment Average Temp Being Determined Based on Only Two Temp Elements Instead of Three as Required by Tss.Caused by Log Only Requiring One Entry.Log revised.W/961227 Ltr ML17354A3261996-11-0606 November 1996 LER 96-011-00:on 961009,potential for Overpressurizing Post Accident Containment Vent Filter Housings Occurred.Caused by Improper Change Mgt.Monitoring Sys Operating Procedures revised.W/961106 Ltr ML17354A3071996-10-22022 October 1996 LER 96-010-00:on 960924,manual Reactor Shutdown Occurred. Caused by Failed Rod Control Sys Regulation Card in 2AC Power cabinet.2AC Power Cabinet DC Power Supplies,Cabling & Connectors checked.W/961022 Ltr ML17353A8711996-08-27027 August 1996 LER 96-009-00:on 960729,failed to Reflect Heavy Load Design Info in Procedural Controls.Caused by Failure to Incorporate 1982 Procedure Changes.Suspended Lifting of Heavy Loads & Took Turbine Bldg Crane OOS.W/960827 Ltr ML17353A7411996-06-18018 June 1996 LER 96-008-00:on 960521,surveillance Method for Testing Emergency Diesel Generators (EDG) Determined Inadequate. Caused by Personnel Error.All Four EDGs Rapid Start Tested & EDG Surveillance Procedures modified.W/960618 Ltr ML17353A7401996-06-18018 June 1996 LER 96-004-02:on 960524,identified Inadequate Surveillance Testing.Caused by Inadequate Surveillance Procedures.Entered Tech Spec Statements,Tested Required Instruments Functions & Revised Plant procedure.W/960618 Ltr ML17353A6901996-05-13013 May 1996 LER 96-004-01:on 960220,identified Potential Tech Spec non-compliance Associated W/Surveillance Testing of AFW Actuation Circuitry on Sg.Caused by Inadequate Surveillance Procedures.Procedures revised.W/960513 Ltr ML17353A6741996-05-0606 May 1996 LER 96-001-00:on 960409,manual Rt Occurred Due to Turbine Governer Control Oil Perturbation.Disassembled & Inspected Governor Valve for Cleanliness & Corrosion products.W/960506 Ltr ML17353A6651996-04-29029 April 1996 LER 96-007-00:on 960329,inadvertent ESF Actuation Occurred During Refueling Outage Due to Cognitive Personnel Error. Personnel Involved Counseled & Integrated Safeguards Test Procedures Being revised.W/960429 Ltr ML17353A6601996-04-25025 April 1996 LER 96-006-00:on 960327,manual Rt Occurred Due to 3C Transformer Lockout & Loss of 3B SG Mfp.Replaced SAM Timer Relay in 3AC16.W/960425 Ltr ML17353A6491996-04-23023 April 1996 LER 96-005-00:on 960326,certain Safety Injection Accumulator Filled Evolutions Resulted in cross-tied Configuration.C/A: Night Order Written & Operations Procedure 3/4-OP-064 revised.W/960423 Ltr ML17353A6051996-03-18018 March 1996 LER 96-003-00:on 960222,two Arpi Inoperable & TS 3.0.3 Entered.Proposed License Amend Submitted to Revise Allowed Misalignment from +/-12 Steps to =/-18 Steps Between Arpi & Dpi at Less than 90% power.W/960318 Ltr ML17353A6041996-03-18018 March 1996 LER 96-004-00:on 960220,surveillance Testing of AFW Actuation Circuitry Was Inadequate.Caused by Inadequate Surveillance Procedures.Tested Untested Portions of Actuation Logic for AFW Automatic Start signal.W/960318 Ltr ML17353A5861996-03-0606 March 1996 LER 96-002-00:on 960209,automatic Turbine Trip/Rt Occurred Due to High SG Level.Caused by Personnel Error.Replaced Both Hinge Pins on B Sgfp Discharge Check valve.W/960306 Ltr ML17353A5761996-03-0101 March 1996 LER 96-001-00:on 960131,intake CWS Flow Rates Found W/ Potential to Be Less than Required by Design Basis.Caused by Influx of Aquatic Grass & Algae Onto Basket Strainers of Icw Flow Path.Mechanically Cleaned strainers.W/960301 Ltr ML17353A4451995-11-0909 November 1995 LER 95-007-00:on 951017,manual Rt Occurred Following Drop of Four Control Rods.Caused by Water Intrusion Into Rod Control Power Cabinet 2BD.Inspected Control Power Cabinet 2BD for Other Water damage.W/951109 Ltr ML17353A4241995-10-12012 October 1995 LER 95-006-00:on 950913,analysis Showed That CCW Exchangers Susceptible to Damage Due to flow-induced Vibration.Ccw Sys Has Been Flow Balanced to Closer tolerances.W/951012 Ltr ML17353A3601995-09-13013 September 1995 LER 95-005-00:on 950818,containment Pressure Testing Procedure Resulted in Inhibiting Both Trains of Containment Pressure from Initiated Esf.Revised Procedure to Require Testing of Each Train separately.W/950913 Ltr ML17353A2951995-07-17017 July 1995 LER 94-005-02:on 941103,both Units Outside Design Basis Due to Design Defect in Safeguards Bus Sequencer Test Logic. Resumed Monthly Manual Testing of Sequencer ML17352B1581995-05-0505 May 1995 LER 95-004-00:on 950407,unit Being Shutdown to Investigate Recurring non-urgent Failure Alarms from Redundant Rod Control Power Supplies.Reactor Manually Tripped.All Four PS-3 Power Supplies replaced.W/950505 Ltr ML17352B1181995-04-0707 April 1995 LER 95-003-00:on 950309,intake Cooling Water Flow Rate Through CCW Heat Exchangers Fell Below Assumed Design Basis. Caused by an Influx of Aquatic Grass & Algae Onto Basket Strainers.Strainers cleaned.W/950407 Ltr ML17352B0701995-03-13013 March 1995 LER 95-002-00:on 950215,inadequate Definition of Loops Filled Resulted in Units in Condition Prohibited by Ts. Issued TS Position Statement to Define Term Loops Filled as Used in TS 6.4.1.1.4.W/950313 Ltr ML17352B0321995-02-0909 February 1995 LER 94-005-01:on 941103,design Defect Found in Safeguards Bus Sequencer Test Logic,Placing Facility Outside Design Basis.Design Mods to Eliminate Software Logic Problems Will Be Implemented During Next Refueling outages.W/950209 Ltr ML17352B0101995-01-20020 January 1995 LER 94-006-00:on 941226,C Main Feedwater Control Valve Failed Closed,Causing Reactor & Turbine Trips.Caused by Loose Screw Terminal Connection.I/P Transducers Replaced W/ New Model W/Different Design Wire connection.W/950120 Ltr ML17352A9511994-12-13013 December 1994 LER 94-006-00:on 941130,Unit 4 Tripped Automatically.Caused by Failure of Flexible Link Connection Between Main Generator B Phase Bus & Associated Isolated Phase Bus Bar. All Bolts on Flexible Link checked.W/941213 Ltr ML17352A8871994-11-10010 November 1994 LER 94-005-00:on 941103,design Defect in Safeguards Bus Sequencer Test Logic Places Both Units Outside Design Basis. Caused by 3A Sequencer Failed to Respond as Expected to Opposite Unit SI signal.W/941110 Ltr ML17352A8851994-11-10010 November 1994 LER 94-004-00:on 941103,Unit 3 Outside Design Basis Due to Two of Three Required Safety Injection Pumps Inoperable. Control Switches for 3A & 3B Safety Injection Pumps Immediately Returned to automatic.W/941110 Ltr ML17352A8421994-10-21021 October 1994 LER 94-004-00:on 940923,Unit 4 Tripped Automatically from Rated Power.Caused by Faulty Regulator Transistor.Faulty Backup Power Supply Replaced & Maint History for Power Supplies reviewed.W/941021 Ltr ML17352A8431994-10-20020 October 1994 LER 94-005-00:on 940924,Unit 4 Manually Tripped.Caused by Manual Actuation.Light Bulb & Socket replaced.W/941020 Ltr ML17352B1671994-08-16016 August 1994 LER 94-003-00:on 940720 & 21,util Discovered That Several Required Valve Stroke Time Surveillances Had Not Been Performed.Caused by Personnel Error.Personnel Reassigned & Procedures and Surveillance Tracking Software Enhanced 1999-07-20
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217L9371999-10-20020 October 1999 Safety Evaluation Supporting Licensee Proposed Alternative from Certain Requirements of ASME Code,Section XI for First 10-Yr Interval Request for Relief for Containment Inservice Insp Program ML17355A4471999-09-30030 September 1999 Monthly Operating Repts for Sept 1999 for Turkey Point,Units 3 & 4.With 991008 Ltr ML17355A4121999-08-31031 August 1999 Monthly Operating Repts for Aug 1999 for Turkey Point,Units 3 & 4.With 990909 Ltr ML17355A3981999-07-31031 July 1999 Monthly Operating Repts for July 1999 for Turkey Point,Units 3 & 4.With 990809 Ltr ML17355A3891999-07-20020 July 1999 LER 99-001-00:on 990623,manual Rt from 100% Power Following Multiple Control Rod Drops Was Noted.Caused by Manual Action Taken by Reactor Control Operator.Inspected & Repaired Stationary Gripper Regulating Cards.With 990720 Ltr ML17355A3841999-06-30030 June 1999 Monthly Operating Repts for June 1999 for Turkey Point,Units 3 & 4.With 990713 Ltr ML17355A3681999-06-30030 June 1999 Revised Update to Topical QA Rept, Dtd June 1999 ML17355A3611999-06-30030 June 1999 Refueling Outage ISI Rept. ML17355A3511999-05-31031 May 1999 Monthly Operating Repts for May 1999 for Turkey Point,Units 3 & 4.With 990609 Ltr ML17355A3331999-04-30030 April 1999 Monthly Operating Repts for Apr 1999 for Turkey Point,Units 3 & 4.With 990511 Ltr ML20217B9871999-04-0808 April 1999 Changes,Tests & Experiments Made as Allowed by 10CFR50.59 for Period Covering 971014-990408 ML17355A2881999-04-0505 April 1999 COLR for Turkey Point Unit 4 Cycle 18. ML17355A2911999-03-31031 March 1999 Monthly Operating Repts for Mar 1999 for Turkey Point,Units 3 & 4.With 990414 Ltr ML17355A2551999-02-28028 February 1999 Monthly Operating Repts for Feb 1999 for Turkey Point Nuclear Power Plant,Units 3 & 4.With 990315 Ltr ML17355A2261999-01-31031 January 1999 Monthly Operating Repts for Jan 1999 for Turkey Point,Units 3 & 4.With 990211 Ltr ML17355A2201999-01-20020 January 1999 Refueling Outage ISI Rept. ML17355A1911998-12-31031 December 1998 Monthly Operating Repts for Dec 1998 for Turkey Point,Units 3 & 4.With 990112 Ltr ML18008A0461998-11-30030 November 1998 Monthly Operating Repts for Nov 1998 for Turkey Point,Units 3 & 4.With 981209 Ltr ML17354B1921998-11-18018 November 1998 LER 98-007-00:on 981020,containment Purge Supply,Valve Opened Wider than TS Limit.Caused by Improper Setting of Mechanical Stops.Incorporated Improved Standard Method of Measuring Angular Valve Position Into Sp.With 981118 Ltr ML17354B1891998-11-0909 November 1998 Simulatory Certification Update 2. ML17354B1901998-10-31031 October 1998 Monthly Operating Repts for Oct 1998 for Turkey Point,Units 3 & 4.With 981112 Ltr ML17354B1591998-10-23023 October 1998 COLR for Turkey Point Unit 3 Cycle 17. ML17354B1361998-10-16016 October 1998 LER 98-004-00:on 980921,automatic Reactor Trip Occurred. Caused by Inadequate re-correlation of Intermediate Range Neutron Flux Instrumentation Reactor Trip Bistable. Enhanced Applicable Plant Procedures.With 981016 Ltr ML17354B1311998-09-30030 September 1998 Monthly Operating Repts for Sept 1998 for Turkey Point Unit 3 & 4.With 981012 Ltr ML17354B0971998-09-0909 September 1998 Part 21 Rept Re Possible Machining Defect in Certain One Inch Stainless Steel Swagelok Front Ferrules,Part Number SS-1613-1.Caused by Tubing Slipping Out of Fitting at Three Times Working Pressure of Tubing.Notified Affected Utils ML17354B0981998-08-31031 August 1998 Monthly Operating Repts for Aug 1998 for Turkey Points,Units 3 & 4.With 980915 Ltr ML17354B0771998-07-31031 July 1998 Monthly Operating Repts for July 1998 for Turkey Point,Units 3 & 4.W/980810 Ltr ML17354B0341998-07-15015 July 1998 LER 98-003-00:on 980619,discovered That Auxiliary Feedwater Sys Was Inoperable Due to Inadequate Inservice Testing of Valves.Caused by Misunderstanding of Testing Criteria.Util Revised Procedures & Verified Operability of Valves ML17354B0241998-06-30030 June 1998 Monthly Operating Repts for June 1998 for Turkey Point,Units 3 & 4.W/980709 Ltr ML17354B0171998-06-29029 June 1998 Rev 1 to PTN-FPER-97-013, Evaluation of Turbine Lube Oil Fire. ML17354A9841998-06-18018 June 1998 LER 97-007-01:on 970730,automatic Reactor Trip Occurred Due to Closure of B Msiv.Caused by Failed BFD22S Relay.Six Relays on 3A,3B & 3C MSIVs Were Replaced & Implemented Plant Change to Disable Electronic Trip Function on 3 AFW Pumps ML17354A9741998-06-0909 June 1998 LER 98-002-00:on 980513,discovered Potential LOCA-initiated Electrical Fault Which Places ECCS Outside Design Basis. Caused by Inadequate Review of Effect on non-safety Circuit failures.Re-powered PC-*-600A Relays ML20248F7441998-05-31031 May 1998 Reactor Vessel Working Group,Response to RAI Regarding Reactor Pressure Vessel Integrity ML17354A9711998-05-31031 May 1998 Monthly Operating Repts for Turkey Point,Units 3 & 4. W/980611 Ltr ML17354A9231998-04-30030 April 1998 Monthly Operating Repts for Apr 1998 for Turkey Point,Units 3 & 4.W/980511 Ltr ML17354A8821998-03-31031 March 1998 Monthly Operating Repts for Mar 1998 for Turkey Point,Units 3 & 4.W/980409 Ltr ML17354A8511998-03-24024 March 1998 LER 97-009-01:on 971114,discovered That CR Console Switch for 3B Sgfp Was Not in Start Position.Caused by Inadequate Procedural Guidance.Revised Procedures 3/4-OP-074,informed Personnel of Event & Performed Walkdown of CR ML17354B0001998-03-18018 March 1998 Florida Power & Light Topical Quality Asurance Rept, Dtd June 1998 ML17354A8441998-03-18018 March 1998 LER 98-001-00:on 980216,manual Reactor Trip Occurred Due to Loss of Turbine Control Oil Pressure W/Steam Leak in Auxiliary Feedwater Steam Supply Piping.Auxiliary Governor Maint Instructions Will Be revised.W/980318 Ltr ML17354A8311998-02-28028 February 1998 Monthly Operating Repts for Feb 1998 for Turkey Point,Units 3 & 4.W/980311 Ltr ML17354A7871998-01-31031 January 1998 Monthly Operating Repts for Jan 1998 for Turkey Point,Units 3 & 4.W/980209 Ltr ML17354A7581997-12-31031 December 1997 Monthly Operating Repts for Dec 1997 for Turkey Point,Unit 3 & 4.W/980112 Ltr ML17354A7361997-12-12012 December 1997 LER 97-009-01:on 971114,identified That CR Console Switch for 3B SG Feedwater Pump Was Not in Start Position.Caused by Inadequate Procedural Guidance.Procedures 3/4-OP-074,SGFP Were revised.W/971212 Ltr ML17354A7381997-11-30030 November 1997 Monthly Operating Repts for Nov 1997 for Turkey Point,Units 3 & 4.W/971215 Ltr ML17354A7211997-10-31031 October 1997 Monthly Operating Repts for Oct 1997 for Turkey Point,Units 3 & 4.W/971114 Ltr ML17354A7491997-10-13013 October 1997 SG Insp Rept. ML17354A8851997-10-13013 October 1997 FPL Units 3 & 4 Changes,Tests & Experiments Made as Allowed by 10CFR50.59 for Period Covering 960408-971013. ML17354A6801997-10-0808 October 1997 LER 97-008-00:on 970909,containment Sump Debris Screens Outside Design Basis Due to Stress Damage Was Discovered. Caused by Inadequate Procedural Guidance & Personnel Error. Discrepancies Found on Screens corrected.W/971008 Ltr ML17354A6791997-10-0606 October 1997 COLR Unit 4 Cycle 17, for Turkey Point ML17354A6811997-09-30030 September 1997 Monthly Operating Repts for Sept 1997 for Turkey Point,Units 3 & 4.W/971009 Ltr 1999-09-30
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ACCELERAT<0 DOCUMENT'T DISTR BUTION SYSTEM REGULAT INFORMATION DISTRIBUTIO YSTEM (RIDS)
ACCESSION HBR:9305030309 DOC.DATE: 93/04/26 NOTARIZED: NO DOCKET FACIL:50-250 Turkey Point Plant, Unit 3, Florida Power and Light C 05000250 AUTH. NAME AUTHOR AFFILIATION KNORRiJ.E. Florida Power & Light Co.
PLUNKETT,T.F. Florida Power & Light Co.
RECIP.NAME RECIPIENT AFFILIATION
SUBJECT:
LER 93-005-00:on 930325,discovered that setpoint for overpressure mitigating sys outside limiting design &
licensing bases when RCS is water solid. Caused by erroneous pressure differential. Controls instituted.W/930426 ltr.
DISTRIBUTION CODE'E22T COPIES RECEIVED'LTR 3 ENCL 50.73/50.9 Licensee Event Report (LER), Incident Rpt, etc.
L SIZE'ITLE:
't NOTES:
RECIPIENT COPIES RECIPIENT COPIES ID CODE/NAME LTTR ENCL ID CODE/NAME LTTR ENCL PD2-2 LA 1 1 PD2-2 PD 1 1 RAGHAVAN,L 1 1 INTERNAL: ACNW 2 2 AEOD/DOA 1 1 AEOD/DSP/TPAB 1 1 AEOD/ROAB/DSP 2 2 NRR/DE/EELB 1 1 NRR/DE/EMEB 1 1 NRR/DORS/OEAB 1 1 NRR/DRCH/HHFB 1 1 NRR/DRCH/HICB 1 1 NRR/DRCH/HOLB 1 1 NRR/DRIL/RPEB 1 1 NRR/DRSS/PRPB 2 2 N A/SPLB 1 1 NRR/DSSA/SRXB 1 1 G- FI.B 02 1 1 RES/DSIR/EIB 1 1 RGN2 FILE 01 1 1 EXTERNAL: EG&G BRYCEIJ.H 2 2 L ST LOBBY WARD 1 1 NRC PDR 1 1 NSIC MURPHYiG.A 1 1 NSIC POORE,W. 1 1 NUDOCS FULL TXT 1 1 NOTE TO ALL "RIDS" RECIPIENTS:
PLEASE HELP US TO REDUCE WASTE! CONTACT THE DOCUMEN'I CON'I'ROL DESK, ROOM Pl-37 (EXT. 504-2065) TO ELIMINATE YOUR NAME FROM DISTRIBUTION LISTS FOR DOCUMENTS YOU DON'T NEED!
FULL TEXT CONVERSION REQUIRED TOTAL NUMBER OF COPIES REQUIRED: LTTR 30 ENCL 30
P.O. Box 029100, Miami, FL, 33102-9100 l=PL APR 26 89.;
L-93-105 10 CFR 50.73 10 CFR 50.4 U. S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D. C. 20555 Gentlemen:
Re: Turkey Point Units 3 Ir 4 Docket Nos. 50-250 and 50-251 Reportable Event: 93-005-00 Setpoint for Overpressure Mitigating System Found Non-conservative with Res ect to 10 CFR 50 A endix G The attached Licensee Event Report 250/93-005-00 is being provided in accordance with 10 CFR 50.73 (a) (2) (ii) (B) and 10 CFR 50.4 (d) .
If there are any questions, please contact us.
Very truly yours,
/
/~i 7
/
T. F. Plunkett Vice President Turkey Point Nuclear TFP/JEK/jk enclosure cc: Stewart USNRC D. Ebneter, Regional Administrator, Region II, Ross C. Butcher, Senior Resident Inspector, USNRC, Turkey Point Plant cofj g 9305030309 930426 PDR ADOCK 05000250 zpP S PDR an FPL Group cornpanir
LICENSEE EVENT REPORT {LER}
FACILITY HAME (1) DOCKET NUMBER (2) PAGE (3)
TURKEY POINT UNITS 3 AND 4 05000250 1 OF 8 TITLE (4) SETPOINT FOR OVERPRESSURE MITIGATING SYSTEM FOUND NON- CONSERVATIVE WITH RESPECT TO 10 CFR 50 APPENDIX G.
EVENT DATE (5) LER NUMBER(6) RPT DATE (7) OTHER FACILITIES INVOLVED (8)
MON DAY YR YR SEQ ¹ R¹ MON DAY YR FACILITY HAMES DOCKET ¹ (S) 03 25 93 93 005 00 04 26 93 Turkey Point Unit 4 05000251 OPERATING MODE (9) 10 CFR 50.73 a 2 ii B POWER LEVEL (10) 100 LICENSEE CONTACT FOR THIS LER (12)
J. E. Knorr, Regulation and Compliance Analyst TELEPHONE NUMBER 305-246-6757 COMPLETE OHE LINE FOR EACH COMPONENT FAILURE DESCRIBED IH THIS REPORT (13)
CAUSE SYSTEM COMPONENT MANUFACTURER HPRDS? CAUSE SYSTEM COMPONENT MANUFACTURER NPRDST SUPPLEMENTAL REPORT EXPECTED (14) NO Z YES 0 EXPECTED SUBMISSIO MONTH DAY YEAR N
(if yes, cceplete EXPECTED SUBMISSION DATE) DATE (15)
ABSTRACT (16)
On March 25, 1993, Turkey Point Units 3 and 4 were in Mode 1 at 100: power. On that date, Florida Power E Light (FPL) received information from its Nuclear Steam Supply System vendor that the setpoint for the Overpressure Mitigating System (OMS) is non-conservative with respect to 10 CFR 50 Appendix G. FPL therefore determined that the overpressure mitigating system on both Units 3 and 4 is placed outside the limiting design and licensing bases OMS analysis under the following conditions:
- 1. Reactor Coolant System (RCS) temperature less than 105 'F,
- 2. RCS is water solid, and
- 3. Three Reactor Coolant Pumps (RCPs) are running.
The acceptance criteria for the setpoint assuines a mass addition produced by the start of a Safety Injection (SI) pump. Technical Specification recIuirements and administrative controls prevent the injection of water .into the RCS due to a start of an SI pump.
Additional administrative controls have been instituted to limit the nuinber of RCPs running at low RCS temperatures.
LICENSEE Ij+NT REPORT (LER) TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 Ec 4 05000250 93-005-00 2 OF 8 DESCRIPTION OR THE EVENT On March 25, 1993, Turkey Point Units,3 and 4 were in Mode 1 at 100.
power. That same day, Florida Power E Light (FPL) received information from its Nuclear Steam Supply System (NSSS) vendor that the setpoint for the Overpressure Mitigating System (OMS) is non-conservative with respect to 10 CFR 50 Appendix G at the current 13.1 effective full power years (EFPY) of operation of Turkey Point Unit 3. FPL therefore determined that the OMS on both Units 3 and 4 would be placed outside the limiting design and licensing basis OMS analysis under the following conditions:
- 1. Reactor Coolant System (RCS) temperature less than 105 'F,
- 2. RCS water solid, and
- 3. Three Reactor Coolant Pumps (RCPs) running.
The acceptance criteria for the OMS setpoint assumes a mass addition event produced by the start of a Safety Injection (SI) pump. Given the above conditions and the mass addition event, the OMS setpoint of 415 psig could result in a short term pressure excursion in the RCS to 560 psig. The 10 CFR 50 Appendix G limit for Turkey Point based upon calculations assuming 85 'F RCS temperature for the current time in reactor vessel life, is 507.56 psig at 13.1 EFPY.
Technical Specification requirements and administrative. controls prevent the injection of water into the RCS due to the start of an SI pump. Nonetheless, additional administrative controls have been instituted to limit the number of RCPs running at low RCS temperatures.
II. CAUSE OF THE EVENT The pressure difference between the wide-range pressure transmitter and the reactor vessel belt-line (where the Appendix G limit is defined) including the core differential pressure resulting from three RCPs in operation had not been considered in the original setpoint analysis for OMS performed by the NSSS vendor.
III. ANALYSIS OF THE EVENT System Description The OMS is designed to mitigate heat input and mass input induced pressure transients during water solid cold shutdown transient and steady-state conditions. The OMS uses the Power Operated Relief Valves (PORVs), with a 415 z 15 psig setpoint, as the pressure relief path.
The OMS pressure transmitter design employs two separate RCS hot leg mounted pressure transmitters, PT-*-403 and 405, for initiation of PORV opening under cold overpressure scenarios.
LICENSEE EQNT REPORT (LER) TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 Ec 4 05000250 93-005-00 3 oF 8 The OMS was designed to provide overpressure protection for the following cases:
- 1) The start of an idle RCP with the secondary water temperature of the steam generators 50 'F above the RCS cold leg temperature.
- 2) The inadvertent start of two charging pumps with a loss of letdown (which is analytically enveloped by item 3); or
- 3) The start of an SI pump and its injection of water into a water solid RCS.
Cases g1 and g3 are stated in the basis for Technical Specification 3.4.9.3. All three cases were addressed'n the original generic NSSS vendor analysis.
Issue Analysis Recently, the NSSS vendor investigated the relationship between PORV settings, pressure sensing location and the actual corresponding pressure within the reactor vessel belt line region. The NSSS vendor determined that the pressure difference, during RCP operation, between wide range pressure indication location and the vessel belt line region had not been explicitly considered in the OMS setpoint calculations.
The pressure differential is the result of core pressure drop, and line losses with one or more RCPs in operation, and elevation differences between the area of interest in the reactor vessel and the hot leg location of the pressure transmitter taps. The consequence of this bias is most significant at low temperatures, while water solid with three RCPs in operation. Therefore, mass or thermal input transients under these conditions represent the most limiting events.
A plant specific review conducted by the NSSS vendor has determined that the identified calculational issues exist as part of the original Units 3 and 4 OMS designs. Discussions with the NSSS vendor (the OMS designer) confirm that the bias associated with core pressure drop (dynamic head) and elevation differences (static head) were not considered in the original Turkey Point Units 3 and 4 OMS design.
Also, PORV setpoint tolerance (z15 psig) was not explicitly considered under the original Turkey Point Units 3 and 4 OMS design.
NSSS vendor letter FPL-88-844, Heatup and Cooldown Curves and OMS Setpoint Instrument Uncertainties, dated September 13, 1988, and FPL "
Engineering Evaluations for pressure transmitter static head correction have dealt with the issues of static head and PORV setpoint tolerance.
In both instances, the amount of error introduced into the setpoint
'calculations (static head and setpoint tolerances) was determined to be insignificant and bounded by the conservatism contained in the formulation of the Appendix G curves. Therefore, these sources of bias do not pose a potential analytical overpressure concern.
LICENSEE E+NT REPORT (LER) TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 Ec 4 05000250 93-005-00 4 QF 8 A plant specific calculation has been completed by the NSSS vendor which indicates the differential pressure between the vessel belt line and the RCS hot leg resulting from running all three RCPs at Turkey Point is 57 psid at 85'F. The 20 effective full power years'ppendix G pressure limit at 85'F (the coldest temperature for which the Turkey Point reactor vessels are analyzed) is 503 psig. One heat injection and two mass injection scenarios are considered that may challenge this limit.
HEAT INJECTION The heat injection scenario arises when one or more steam generators are warmer than the stagnant, water solid RCS. This is postulated to occur when a cooldown has been performed using natural circulation and/or residual heat removal. In these cases, one or more steam generators may have been permitted to stagnate, remaining warmer than the bulk RCS temperature. When the first RCP is started, heat is transferred into the RCS causing a pressure increase.
Using the Cold Overpressure Mitigating System Setpoint Evaluation completed by the NSSS vendor, a conservative estimate of the pressure overshoot due to the heat input transient is 22 psig.
This calculation assumes a PORV opening time of 3.2 seconds.
Because the initial conditions needed to cause this transient are no longer present after the first RCP is started (since RCS and Steam Generator temperatures quickly equalize), only the core differential pressure due to one RCP running is applicable. The core differential pressure caused by a single running RCP is 25 psid (as shown by an NSSS vendor calculation at 85 'F) after has attained full speed. This differential pressure is then added it to the pressure transient caused by the heat injection:
OMS se tpo3 nt o ~ ~ ~ ~ ~ ~ 415 psig The potential pressure overshoot above the PORV setpoint 22 psig Estimated vessel core differential pressure ~25 sid Total possible reactor vessel actual pressure 462 psig Therefore, heat injection from an RCP start does not pose a potential overpressure concern.
MASS INJECTION MAXIMUM CHARGING WITH LETDOWN ISOLATED The first potential mass input transient considered in the OMS design is charging pump water injection with letdown isolated. A calculation has been performed by FPL to determine the pressure overshoot for the cases of two and three running charging pumps as a function of PORV stroke time. For three charging pumps running at full speed with letdown isolated and a PORV stroke time of 3.2 seconds, the pressure overshoot is 30 psig.
C LICENSEE ENT REPORT (LERI TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 Ec 4 05000250 93-005-00 5 oF 8 Thus the worst case reactor vessel pressure for this mass input transient case would be:
Setpoint 415 psig Transient pressure overshoot 30 psig Calculated vessel core differential pressure 57 sid Total possible reactor vessel actual pressure 502 psig As such, mass injection from running three full speed charging pumps with letdown isolated does not pose a potential overpressure concern.
SAFETY INJECTION PUMP START The second (and limiting) scenario potentially occurs when an SI pump is started while inadvertently aligned to the RCS during cold, solid conditions with all three RCPs running. Based on the results of a plant specific evaluation which determined parametrically the maximum permissible PORV setpoint, there is no margin between the Appendix G curve at 85'F and the predicted maximum pressure attained. In this case, any differential pressure caused by an operating RCP will cause an overpressure excursion in excess of the Appendix G curve.
The following table reflects the maximum vessel pressure obtained for each combination of running RCPs assuming the inadvertent start of an SI pump with the lack of isolation of the flow path to the RCS:
g of h,P Total RCPs (psid) Pressure 503 25 528 36 539 57 560 If this limiting mass injection event occurred with any running RCPs, the Appendix G curve would be exceeded. However, as discussed below, the Appendix G curve is not the ultimate pressure ..
limit to determine operability of an OMS system. Several mitigating factors contribute to the OMS being able to protect the vessel in this postulated event. Post-event stress analyses have been completed to evaluate the actual cold overpressure events which have occurred in the industry. These analyses have found .
that in none of the cases has a problem been noted with regard to the vessel integrity. For pressure excursions less than 100 psig above the Appendix G curve, the NSSS vendor has stated that there is no significant hazard to the vessel.
LICENSEE ENT REPORT (LER) TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 6 4 05000250 93-005-00 6oFS APPENDIX G REQUIREMENTS There are numerous conservatisms in the ASME Appendix G pressure/temperature curve calculations. Some of these are:
a) The safety factor of 2 on the principal membrane (pressure) stresses.
b) The margin factor of Reg Guide 1.99 Rev 2 is applied to Nil Ductility Transition Reference Temperature (RT<HpT)) .
c) The use of an assumed flaw of a length equal to one-quarter of the reactor vessel wall thickness (~/I'law).
d) The increased mechanical properties of the vessel which accompanies material embrittlement (elevated yield strength and flow stress).
Additionally, there are conservatisms specific to the Turkey Point vessels.
a) It is assumed that the weld is longitudinal. However, vessels such as those at Turkey Point do not contain longitudinal welds. This is equivalent to an additional safety factor of 2 in the calculated results since the postulated flaw (in the embrittled weld material) cannot be oriented normal to the greatest stress (hoop stress).
Rather, the only plausible orientation for the postulated flaw is normal to the axial stresses, which in turn is half that of the hoop stress.
b) Inservice inspections of the Turkey Point Units 3 and 4 vessels were performed during the 1991 Dual Unit Outage.
During that inspection no unresolved flaws were identified.
The curves resulting from calculations based partly on the above assumptions have historically formed the upper bound of OMS design pressure transients. However, this creates a restrictive operating window resulting in an increased potential for inadvertent PORV actuation (and the associated increased risk of a loss of coolant accident from a failed-open PORV). For these reasons the American Society of Mechanical Engineers Code pressure excursions to 110 'f Committee has recently approved Code Case N-514, "Low Temperature Overpressure Protection," relaxing [OMS] design criteria to limit temperature overpressure transients.
draws upon the inherent the Appendix G limits during low conservatism The basis for this code case in the formulation of the Appendix G curves. Assuming the 110% of Appendix G limits, the overpressure which could be found during the mass injection scenario is as follows:
110% of Appendix G limit SI pump start scenario maximum pressure Maximum calculated pressure above code allowable
. . . . . . . . . . . 553 560 7
psig psig psid
LICENSEE EQNT REPORT (LER) TEXT CTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 & 4 05000250 93-005-00 7OF8 As stated earlier, the Appendix G limit at 85 'F is 503 psig; one-hundred and ten percent of the Appendix G curve at 85'F is 553 psig. The only postulated cold overpressure transient that exceeds this limit is the Safety Injection case with three (3)
RCPs running during the event. At 105'F, the Appendix G curve has increased to 510 psig, resulting in a 110% limit of 561 psig. At this point, sufficient margin exists to permit unrestricted simultaneous operation of all three RCPs. Based on this, RCP operation should be limited to no more than two RCPs running simultaneously at temperatures less than 105'F.
An alternative to limiting RCP operation is to decrease the stroke time of the PORVs. This action will reduce the time until the PORVs reach full relieving capacity, and correspondingly reducing the magnitude'f the pressure overshoot. The 553 psig limit afforded by Code Case N-514 is reduced 57 psig by the RCP differential, resulting in a maximum allowable sensed pressure of 496 psig. A linear interpolation of PORV stroke times between 2 and 3 seconds provides a corresponding stroke time of 2.8 seconds in order to limit pressure to 496 psig. Also, an additional .25 seconds may be added to this time to account for a lack of pressure under the valve disk during testing. Therefore, PORVs are verified to stroke full open in less than or equal to if the 3.0 seconds, the OMS may be considered to be within the limits of the code as amended by N-514. Recent tests of the PORV stoke times have shown consistent opening times of less than three seconds.
IV. CORRECTIVE ACTIONS Administrative controls have been instituted which will provide assurance that a challenge to the overpressure mitigating system will not result in pressure iri the reactor vessel rising above the Appendix G limit. These controls are as follows:
Prior to all three of the following conditions being true:
a) Technical Specifications 3.4.9.2 require PORVs operable; and b) Reactor coolant system water solid and c) RCS temperature less than 105'F, At least one of the following actions will be taken:
(a) At least one RCP breaker will be opened and placed under administrative control to prevent the inadvertent start of the associated RCP; or (b) The stroke time of both PORVs shall be verified to be equal to or less than 2.8 seconds (3.05 seconds as tested);
LICENSEE NT REPORT (LER) TEXT CONTINUATION FACILITY NAME DOCKET NUMBER LER NUMBER PAGE NO.
TURKEY POINT UNITS 3 Ec 4 05000250 93-005-00 8oF8 Either of these restrictions is sufficient. The restriction of choice will be implemented by incorporation into existing operating procedures prior to the next entry into Mode 5 from the cold condition. Procedure 4-GOP-305 has been revised to require RCP restrictions during the April 1993 refueling shutdown as outlined in this Licensee Event Report. Procedure 3-GOP-305 has been similarly revised to have procedures in place if a shutdown of Unit 3 is required prior to the resolution of the exemption request discussed in corrective action number 2.
- 2. An exemption request from 10 CFR 50.60 to permit the use of ASME Code case N-514 was submitted to the NRC by FPL letter L-93-093, dated April 8, 1993.
V. ADDITIONAL INFORMATION System and component identification described in this report:
SYSTEM OR COMPONENT EIIS CODE IEEE 803a/83 AB N/A AB N/A Reactor Vessel RPV Pressure Transmitter PT Power Operated Relief Valves (PORVs)
Steam Generators SB SG Charging Pumps CB P Letdown CB N/A Residual Heat Removal BP N/A Reactor Coolant Pump P Safety Injection Pump BQ