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Category:REPORTABLE OCCURRENCE REPORT (SEE ALSO AO LER)
MONTHYEAR3F0399-04, Special Rept 99-01:on 990310,discovered Containment Tendons That Required Grease Addition in Excess of Prescribed Limits During Recent Insp Activites.Six Tendons Were Refilled with Appropriate Amount of Grease1999-03-10010 March 1999 Special Rept 99-01:on 990310,discovered Containment Tendons That Required Grease Addition in Excess of Prescribed Limits During Recent Insp Activites.Six Tendons Were Refilled with Appropriate Amount of Grease 3F0498-28, Ro:On 980421,unplanned Release of Effluent Water from Crystal River Nuclear Plant Regeneration Waste Neutralization Tank.Root Cause Analysis Currently Being Conducted.Pipe Isolated for Repairs1998-04-23023 April 1998 Ro:On 980421,unplanned Release of Effluent Water from Crystal River Nuclear Plant Regeneration Waste Neutralization Tank.Root Cause Analysis Currently Being Conducted.Pipe Isolated for Repairs 3F0398-21, Special Rept:On 980302,insp Vendor Notified FPC That Grease Sample for Tendon 51H25 Had Water Content of 14.9% Volume by Weight.Caused Undeterminate.Subject Tendon Was Partially re-greased During Performance of Surveillance1998-03-10010 March 1998 Special Rept:On 980302,insp Vendor Notified FPC That Grease Sample for Tendon 51H25 Had Water Content of 14.9% Volume by Weight.Caused Undeterminate.Subject Tendon Was Partially re-greased During Performance of Surveillance 3F0198-07, Special Rept 97-09:provides Details of Conditions Found Not Meeting Acceptance Criteria During Ongoing Twentieth Year Tendon Surveillance of Containment Post Tensioning Sys. Commitments Encl1998-01-0808 January 1998 Special Rept 97-09:provides Details of Conditions Found Not Meeting Acceptance Criteria During Ongoing Twentieth Year Tendon Surveillance of Containment Post Tensioning Sys. Commitments Encl 3F0198-04, Special Rept 97-08:on 971208,mid Range & High Range Noble Gas Stack Monitors Found to Be Inoperable Greater than Seven Days.Cables to low-medium-high Valve Controllers re-connected Inside Radiation Monitoring Panel1998-01-0303 January 1998 Special Rept 97-08:on 971208,mid Range & High Range Noble Gas Stack Monitors Found to Be Inoperable Greater than Seven Days.Cables to low-medium-high Valve Controllers re-connected Inside Radiation Monitoring Panel 3F1297-06, Special Rept 97-07:re Hoop Tendon 51H26 That Was Found to Have Normalized lift-off Force of More than 10% Below Predicted Value.Out of Tolerance Tendons Were Returned to Proper pre-stress Level.Commitment Attached1997-12-0606 December 1997 Special Rept 97-07:re Hoop Tendon 51H26 That Was Found to Have Normalized lift-off Force of More than 10% Below Predicted Value.Out of Tolerance Tendons Were Returned to Proper pre-stress Level.Commitment Attached 3F1197-14, Special Rept 97-03:on 971021,mid Range & High Range Noble Gas Monitors Found Inoperable Greater than Seven Days.Filter Holder Immediately re-installed1997-11-19019 November 1997 Special Rept 97-03:on 971021,mid Range & High Range Noble Gas Monitors Found Inoperable Greater than Seven Days.Filter Holder Immediately re-installed 3F8097-33, Special Rept 97-02:on 970714,fire Suppression Sys Required by Fire Protection Plan Out of Svc for Greater than Fourteen Days.Two Continuous Fire Watches Put in Place as Compensatory Measures as Required by CR-31997-08-22022 August 1997 Special Rept 97-02:on 970714,fire Suppression Sys Required by Fire Protection Plan Out of Svc for Greater than Fourteen Days.Two Continuous Fire Watches Put in Place as Compensatory Measures as Required by CR-3 3F1096-22, Special Rept:On 960902,unit Shutdown Due to Leak in Turbine Lube Oil Sys.Issue Will Be Resolved Before Startup from Current Outage1996-10-28028 October 1996 Special Rept:On 960902,unit Shutdown Due to Leak in Turbine Lube Oil Sys.Issue Will Be Resolved Before Startup from Current Outage 3F0896-25, Special Rept:On 960712,declared Seismic Monitoring Instrumentation Inoperable for More than 30 Days.Caused by Triaxial Peak Accelographs Failures.Instruments Will Be Omitted from FSAR Section 2.5.4.41996-08-28028 August 1996 Special Rept:On 960712,declared Seismic Monitoring Instrumentation Inoperable for More than 30 Days.Caused by Triaxial Peak Accelographs Failures.Instruments Will Be Omitted from FSAR Section 2.5.4.4 3F0496-30, Special Rept 96-02:on 960313,fire Detection Zones Required by Fire Protection Plan Out of Svc for Greater than Fourteen Days.Hourly Fire Watch Established1996-04-26026 April 1996 Special Rept 96-02:on 960313,fire Detection Zones Required by Fire Protection Plan Out of Svc for Greater than Fourteen Days.Hourly Fire Watch Established 3F0396-21, Special Rept 96-01:on 960218,RM-A1 Taken Out of Svc Due to Failure of Detector to Respond to Check Source.Replacement Detector from Stores & Bench Calibrate.Expects to Return RM-A1 to Svc Prior to Restart from Refueling Outage1996-03-26026 March 1996 Special Rept 96-01:on 960218,RM-A1 Taken Out of Svc Due to Failure of Detector to Respond to Check Source.Replacement Detector from Stores & Bench Calibrate.Expects to Return RM-A1 to Svc Prior to Restart from Refueling Outage 3F0895-16, Ro:On 950713,1 H non-emergency Rept Made Re Condition Suspected to Be Outside Design Basis of Plant.Based on Conclusions of Design Basis Evaluation,Rescinds 1 H non-emergency Rept (NRC Event 29062)1995-08-11011 August 1995 Ro:On 950713,1 H non-emergency Rept Made Re Condition Suspected to Be Outside Design Basis of Plant.Based on Conclusions of Design Basis Evaluation,Rescinds 1 H non-emergency Rept (NRC Event 29062) 3F0895-15, Special Rept 95-01:on 950630,ODCM Required Waste Gas Analyzer (WGDA-1) Declared Inoperable & Unavailable for Greater than Seven Days Due to Deficiency in Microprocessor. Microprocessor Replaced & WGDA-1 Returned to Operation1995-08-11011 August 1995 Special Rept 95-01:on 950630,ODCM Required Waste Gas Analyzer (WGDA-1) Declared Inoperable & Unavailable for Greater than Seven Days Due to Deficiency in Microprocessor. Microprocessor Replaced & WGDA-1 Returned to Operation 3F1094-07, Special Rept:On 940919,determined That Two Transmitters Which Comprise Rv Level Indication Sys Portion of Rc Inventory Tracking Sys Not Functioning Normally Due to Line Blockage in Common Tubing.Sys Restoration outage-dependent1994-10-10010 October 1994 Special Rept:On 940919,determined That Two Transmitters Which Comprise Rv Level Indication Sys Portion of Rc Inventory Tracking Sys Not Functioning Normally Due to Line Blockage in Common Tubing.Sys Restoration outage-dependent 3F1293-07, Special Rept 93-03:on 931124,ODCM Required Radiation Monitor Taken Out of Svc Due to Failure to Pass Check Source Functional Test & Unavailable for Greater than 7 Days. Subj Monitor Restored to Normal Operation on 9312061993-12-23023 December 1993 Special Rept 93-03:on 931124,ODCM Required Radiation Monitor Taken Out of Svc Due to Failure to Pass Check Source Functional Test & Unavailable for Greater than 7 Days. Subj Monitor Restored to Normal Operation on 931206 3F1093-17, Special Rept 93-02:on 931011,primary Meteorlogical Sys Taken Out of Svc for Performance of TS Surveillance 4.3.3.4 & TS 3.3.3.4 Entered Since Backup Sys Out of Svc.Surveillance Performed & Sys Returned to Operation on 9310191993-10-27027 October 1993 Special Rept 93-02:on 931011,primary Meteorlogical Sys Taken Out of Svc for Performance of TS Surveillance 4.3.3.4 & TS 3.3.3.4 Entered Since Backup Sys Out of Svc.Surveillance Performed & Sys Returned to Operation on 931019 3F0992-18, Special Rept 92-003:on 920815,auxiliary Bldg high-range Noble Gas Monitor Failed Calibr & Declared Inoperable for More than 7 Days.Automatic Isotopic Monitoring Sys Available for Use.Amplifier Components & detector-sensor Replaced1992-09-24024 September 1992 Special Rept 92-003:on 920815,auxiliary Bldg high-range Noble Gas Monitor Failed Calibr & Declared Inoperable for More than 7 Days.Automatic Isotopic Monitoring Sys Available for Use.Amplifier Components & detector-sensor Replaced 3F0692-10, Special Rept 92-02:on 920514,waste Gas Decay Tank Hydrogen & Oxygen Monitoring Channels Removed from Svc & Not Returned to Operable Status within 14 Days.Caused by Need to Facilitate Maint.Ts Amend Will Be in Place by Sept 19921992-06-12012 June 1992 Special Rept 92-02:on 920514,waste Gas Decay Tank Hydrogen & Oxygen Monitoring Channels Removed from Svc & Not Returned to Operable Status within 14 Days.Caused by Need to Facilitate Maint.Ts Amend Will Be in Place by Sept 1992 3F0592-17, Special Rept 92-01,on 920506,reactor Bldg Purge Exhaust Duct Monitor Was Taken Out of Svc.Caused by Inability to Calibrate RM-A1 Noble Gas Activity.Monitor mid-range Channel Was Recalibrated1992-05-26026 May 1992 Special Rept 92-01,on 920506,reactor Bldg Purge Exhaust Duct Monitor Was Taken Out of Svc.Caused by Inability to Calibrate RM-A1 Noble Gas Activity.Monitor mid-range Channel Was Recalibrated 3F0591-02, Special Rept 91-001:on 910320,waste Gas Analyzer Removed from Svc to Allow Isolation of Waste Gas Compressor from Maint.Moisture Discovered in Sample Tubing.Work Request to Correct Moisture Intrusion in Analyzer Sample Lines Written1991-05-0101 May 1991 Special Rept 91-001:on 910320,waste Gas Analyzer Removed from Svc to Allow Isolation of Waste Gas Compressor from Maint.Moisture Discovered in Sample Tubing.Work Request to Correct Moisture Intrusion in Analyzer Sample Lines Written 3F1190-13, Special Rept 90-04:on 901015,portion of Mounting Platform for Triaxial Peak Accelograph on Piping on Top of Steam Generator Melted1990-11-21021 November 1990 Special Rept 90-04:on 901015,portion of Mounting Platform for Triaxial Peak Accelograph on Piping on Top of Steam Generator Melted 3F0989-08, Special Rept 89-001:on 890826,dose Equivalent Iodine Dei of RCS Samples Exceeded Tech Specs Limit.Sampling & Analysis of RCS Continued at 4 H Intervals Until Dei Decrease Below Tech Spec Limit.Dei Analysis Results Presented1989-09-21021 September 1989 Special Rept 89-001:on 890826,dose Equivalent Iodine Dei of RCS Samples Exceeded Tech Specs Limit.Sampling & Analysis of RCS Continued at 4 H Intervals Until Dei Decrease Below Tech Spec Limit.Dei Analysis Results Presented 3F0389-01, Ro:On 890118,reactor Coolant Pump 1A Failed.Cause Not Discussed.Sequence of Events Encl1989-03-0101 March 1989 Ro:On 890118,reactor Coolant Pump 1A Failed.Cause Not Discussed.Sequence of Events Encl 3F1188-01, Special Rept 88-001:on 881009,RCS Sample Obtained & Analyzed for Iodine Activity Indicated Dose Equivalent Iodine (Dei) Exceeding Tech Spec Limit.Chemists Continued Sampling & Analysis of RCS at Intervals Until Dei Decreased1988-11-0101 November 1988 Special Rept 88-001:on 881009,RCS Sample Obtained & Analyzed for Iodine Activity Indicated Dose Equivalent Iodine (Dei) Exceeding Tech Spec Limit.Chemists Continued Sampling & Analysis of RCS at Intervals Until Dei Decreased 3F0688-19, Ro:On 880527,emergency Feedwater Piping Near Flow Control Valve Found to Be Warmer than Normal.Cause Not Stated.Water Added to Reseat & to Cool Emergency Feedwater Line & Valve Closed to Prevent Inadvertent Manual Addition of Water1988-06-28028 June 1988 Ro:On 880527,emergency Feedwater Piping Near Flow Control Valve Found to Be Warmer than Normal.Cause Not Stated.Water Added to Reseat & to Cool Emergency Feedwater Line & Valve Closed to Prevent Inadvertent Manual Addition of Water 3F0388-02, Special Rept 87-05-01:two Steam Generator Tubes Found Defective,Having Indications Greater than 40% Through Wall & One Tube Identified as Degraded W/Indication of 38% Through Wall.Tubes Removed from Svc by Plugging.Addl Info Encl1988-03-21021 March 1988 Special Rept 87-05-01:two Steam Generator Tubes Found Defective,Having Indications Greater than 40% Through Wall & One Tube Identified as Degraded W/Indication of 38% Through Wall.Tubes Removed from Svc by Plugging.Addl Info Encl 3F0188-19, Special Rept 87-05:during Refuel IV Outage,Steam Generator Eddy Current Testing Revealed Defective tubes.Pre-outage Planning Developed 6% Random Sampling Insp Plan That Would Be Completed on a Steam Generator1988-01-20020 January 1988 Special Rept 87-05:during Refuel IV Outage,Steam Generator Eddy Current Testing Revealed Defective tubes.Pre-outage Planning Developed 6% Random Sampling Insp Plan That Would Be Completed on a Steam Generator 3F1187-09, Special Rept 87-04:Tech Spec 3.3.3.10 Violated.Caused by Removal of Waste Gas Decay Tank Hydrogen & Oxygen Monitors from Svc & Not Returned to Operable Status within 14 Days. Monitors Will Remain Out of Svc Until Sys in Use1987-11-18018 November 1987 Special Rept 87-04:Tech Spec 3.3.3.10 Violated.Caused by Removal of Waste Gas Decay Tank Hydrogen & Oxygen Monitors from Svc & Not Returned to Operable Status within 14 Days. Monitors Will Remain Out of Svc Until Sys in Use ML20236L4161987-11-0505 November 1987 Special Rept 87-03:on 870927,during Channel Check of Triaxial Peak,Monitor SI-005-MEI Found Inoperable.Cause Undetermined.Replacement Monitor to Be Installed After Refueling & Engineering Design Evaluation to Be Made 3F0887-01, Special Rept 87-02:on 870702,reactor Trip Occurred from 88% Rated Thermal Power.Primary Coolant Sample Obtained & Analyzed for Iodine Activity,Per Tech Spec 4.4.8.Reactor Power History,Fuel Burnup & Time Duration Provided1987-08-0303 August 1987 Special Rept 87-02:on 870702,reactor Trip Occurred from 88% Rated Thermal Power.Primary Coolant Sample Obtained & Analyzed for Iodine Activity,Per Tech Spec 4.4.8.Reactor Power History,Fuel Burnup & Time Duration Provided 3F0687-06, Special Rept 87-01:on 870519,auxiliary Bldg & Fuel Handling Area Exhaust Duct mid-range Noble Gas Monitor Inoperable for Seven or More Days.Caused by Alarm Circuit Repair Altering Calibr of Monitor,Rendering Instrument Inoperable1987-06-0909 June 1987 Special Rept 87-01:on 870519,auxiliary Bldg & Fuel Handling Area Exhaust Duct mid-range Noble Gas Monitor Inoperable for Seven or More Days.Caused by Alarm Circuit Repair Altering Calibr of Monitor,Rendering Instrument Inoperable 3F0287-17, Ro:On 870121,during Performance of Surveillance Procedure SP-110,CRD a Ac Breaker Failed to Trip.Caused by Malfunction of Undervoltage Trip Coil Device.Breaker Replaced & Successfully Tested1987-02-23023 February 1987 Ro:On 870121,during Performance of Surveillance Procedure SP-110,CRD a Ac Breaker Failed to Trip.Caused by Malfunction of Undervoltage Trip Coil Device.Breaker Replaced & Successfully Tested 3F0287-21, Ro:On 870112,6-month Interval for Containment Air Lock Type B Tests Found Exceeded Due to Inconsistencies Between Tech Specs & App J.Caused by Failure to Recognize Dual Sources of Requirements.Test Schedule Revised & Tech Spec Changed1987-02-23023 February 1987 Ro:On 870112,6-month Interval for Containment Air Lock Type B Tests Found Exceeded Due to Inconsistencies Between Tech Specs & App J.Caused by Failure to Recognize Dual Sources of Requirements.Test Schedule Revised & Tech Spec Changed 3F0187-07, Special Rept 86-01:on 861223,during Startup from Mode 5,unit Entered Mode 4 W/Noble Gas Activity Monitor & Fuel Handling Bldg Area Exhaust Duct Inoperable.Caused by Poor Response of Installed Check Source.Instrument Recalibr1987-01-0909 January 1987 Special Rept 86-01:on 861223,during Startup from Mode 5,unit Entered Mode 4 W/Noble Gas Activity Monitor & Fuel Handling Bldg Area Exhaust Duct Inoperable.Caused by Poor Response of Installed Check Source.Instrument Recalibr ML20211E0731986-09-26026 September 1986 Unplanned Operating Event Rept 85-6, Manual Reactor Trip Following MSIV Closure Due to Inadvertent Emergency Feedwater Actuation,851009 3F0786-22, Ro:On 860629,reactor Bldg Vented to Relieve Long Term Pressure Buildup.Initially Reported on 860630.Draft LER Under Mgt Review to Determine Reporting Requirements.Next Rept Will Be Submitted by 8608081986-07-29029 July 1986 Ro:On 860629,reactor Bldg Vented to Relieve Long Term Pressure Buildup.Initially Reported on 860630.Draft LER Under Mgt Review to Determine Reporting Requirements.Next Rept Will Be Submitted by 860808 3F0386-13, Suppl 2 to Special Rept 85-03:on 850807,intermediate- & high-range Channels of Gaseous Release Monitors RM-A1 & RM-A2 Not Calibr.Mod to Achieve Overlap & Calibr of Intermediate Channels Completed1986-03-31031 March 1986 Suppl 2 to Special Rept 85-03:on 850807,intermediate- & high-range Channels of Gaseous Release Monitors RM-A1 & RM-A2 Not Calibr.Mod to Achieve Overlap & Calibr of Intermediate Channels Completed 3F0286-08, RO:86-002-00:on 860110,incident Occurred in Seawater Intake Area Resulting in Deaths of Two Divers.All Seawater Pumps Shut Off for 2 H 45 Minutes.Ler Will Be Sent by 8602211986-02-10010 February 1986 RO:86-002-00:on 860110,incident Occurred in Seawater Intake Area Resulting in Deaths of Two Divers.All Seawater Pumps Shut Off for 2 H 45 Minutes.Ler Will Be Sent by 860221 3F0885-10, Special Rept 85-03:on 850807,discovered That mid- & high- Range Channels of Gaseous Effluent Release Monitors Out of Calibr.Caused by Delays in Contractual Arrangements for Supplies.Action Taken to Obtain Matls.Part 21 Related1985-08-21021 August 1985 Special Rept 85-03:on 850807,discovered That mid- & high- Range Channels of Gaseous Effluent Release Monitors Out of Calibr.Caused by Delays in Contractual Arrangements for Supplies.Action Taken to Obtain Matls.Part 21 Related 3F0785-29, Revised Special Rept 85-01 Re Inoperability of Three Triaxial Peak Accelographs.Installation of Reactor Vessel Head Device Delayed Until 850714 Due to Unforeseen Activities1985-07-24024 July 1985 Revised Special Rept 85-01 Re Inoperability of Three Triaxial Peak Accelographs.Installation of Reactor Vessel Head Device Delayed Until 850714 Due to Unforeseen Activities 3F0785-30, Suppl 1 to Special Rept 85-02:Halon Portion of Fire Suppression Sys Inoperable.Addl Work Required Due to Unanticipated Difficulties W/Asbestos Matls in Areas Being Modified.Operability Not Restored by 8507011985-07-24024 July 1985 Suppl 1 to Special Rept 85-02:Halon Portion of Fire Suppression Sys Inoperable.Addl Work Required Due to Unanticipated Difficulties W/Asbestos Matls in Areas Being Modified.Operability Not Restored by 850701 3F0585-14, Special Rept 85-02:on 850408,during Refueling & Mod Outage, Halon Portion of Fire Suppression Sys for Cable Spreading Room Taken Out of Svc in Support of Various Mods to Cable Spreading Room.Fire Watches Immediately Established1985-05-22022 May 1985 Special Rept 85-02:on 850408,during Refueling & Mod Outage, Halon Portion of Fire Suppression Sys for Cable Spreading Room Taken Out of Svc in Support of Various Mods to Cable Spreading Room.Fire Watches Immediately Established 3F0485-20, Special Rept 85-01:on 850317,during Performance of Refueling Interval Surveillance,All Three Triaxial Peak Accelographs Required by Tech Specs Discovered Inoperable.Cause Undetermined.Accelographs Will Be Repaired1985-04-26026 April 1985 Special Rept 85-01:on 850317,during Performance of Refueling Interval Surveillance,All Three Triaxial Peak Accelographs Required by Tech Specs Discovered Inoperable.Cause Undetermined.Accelographs Will Be Repaired 3F1284-04, Special Rept SR-84-5:on 841029,Halon Portion of Fire Suppression Sys for Cable Spreading Room Taken Out of Svc for Mod to Cable Spreading Room.Sys Will Be Out of Svc Periodically During Mod for Welding in Cable Spreading Room1984-12-0707 December 1984 Special Rept SR-84-5:on 841029,Halon Portion of Fire Suppression Sys for Cable Spreading Room Taken Out of Svc for Mod to Cable Spreading Room.Sys Will Be Out of Svc Periodically During Mod for Welding in Cable Spreading Room 3F1084-05, Special Rept 84-04:on 840919,fire Suppression Water Sys Placed in Degraded Mode of Operation to Support Sys Mod. Caused by Redundant Loop Flow Path Allowing Only One Fire Svc Sys Header to Remain in Svc.Loop Removed1984-10-0303 October 1984 Special Rept 84-04:on 840919,fire Suppression Water Sys Placed in Degraded Mode of Operation to Support Sys Mod. Caused by Redundant Loop Flow Path Allowing Only One Fire Svc Sys Header to Remain in Svc.Loop Removed 3F0784-16, Special Rept 84-03:on 840424,false Low & High Pressure Injection Occurred When Channel 2 Low Pressure Bistable Inadvertently Actuated.Cause Not Stated.Bistable Replaced. Plant Stabilized W/Injection of Borated Water Into RCS1984-07-23023 July 1984 Special Rept 84-03:on 840424,false Low & High Pressure Injection Occurred When Channel 2 Low Pressure Bistable Inadvertently Actuated.Cause Not Stated.Bistable Replaced. Plant Stabilized W/Injection of Borated Water Into RCS 3F0684-09, Special Rept 84-02:on 840312,engineered Safeguards High Pressure Injection Initiated.Caused by Spurious Actuation of Channel 2 Train B.Equipment Replaced & Borated Water Injected1984-06-13013 June 1984 Special Rept 84-02:on 840312,engineered Safeguards High Pressure Injection Initiated.Caused by Spurious Actuation of Channel 2 Train B.Equipment Replaced & Borated Water Injected 3F0184-22, RO Special Rept 84-01:on 840114,leak Found in Fire Suppression Water Sys,Rendering Sys Inoperable.Caused by Compliance W/Tech Spec Limiting Condition for Operation.Sys Returned to Operable Status on 8401151984-01-23023 January 1984 RO Special Rept 84-01:on 840114,leak Found in Fire Suppression Water Sys,Rendering Sys Inoperable.Caused by Compliance W/Tech Spec Limiting Condition for Operation.Sys Returned to Operable Status on 840115 3F1283-06, RO 83-050:on 830719,mode Ascension Occurred (Mode 5 to 4) Prior to Completing Required Surveillance.Occurrence Analysis Continuing.Ler Will Be Submitted by 8312221983-12-0505 December 1983 RO 83-050:on 830719,mode Ascension Occurred (Mode 5 to 4) Prior to Completing Required Surveillance.Occurrence Analysis Continuing.Ler Will Be Submitted by 831222 1999-03-10
[Table view] Category:TEXT-SAFETY REPORT
MONTHYEARML20217G0191999-10-15015 October 1999 Safety Evaluation Concluding That Licensee Followed Analytical Methods Provided in GL 90-05.Grants Relief Until Next Refueling Outage,Scheduled to Start on 991001.Temporary non-Code Repair Must Then Be Replaced with Code Repair 3F1099-19, Part 21 Rept Re Damage on safety-grade Cable Provided to FPC by Bicc Brand-Rex Co.Damage Was Created During Cabling Process While Combining Three Conducters.Corrective Action Program Precursor Card PC99-2868 Was Initiated1999-10-13013 October 1999 Part 21 Rept Re Damage on safety-grade Cable Provided to FPC by Bicc Brand-Rex Co.Damage Was Created During Cabling Process While Combining Three Conducters.Corrective Action Program Precursor Card PC99-2868 Was Initiated ML20217B0931999-10-0606 October 1999 Part 21 Rept Re Damaged Safety Grade Electrical Cabling Found in Supply on 990831.Damage Created During Cabling Process While Combining Three Conductors Just Prior to Closing.Vendor Notified of Reporting of Issue ML20212L0881999-10-0404 October 1999 SER Accepting Licensee Requests for Relief 98-012 to 98-018 Related to Implementation of Subsections IWE & Iwl of ASME Section XI for Containment Insp for Crystal River Unit 3 ML20212J8631999-10-0101 October 1999 Safety Evaluation Supporting Licensee Proposed Alternatives to Provide Reasonable Assurance of Structural Integrity of Subject Welds & Provide Acceptable Level of Quality & Safety.Relief Granted Per 10CFR50.55a(g)(6)(i) ML20212E9031999-09-30030 September 1999 FPC Crystal River Unit 3 Plant Reference Simulator Four Year Simulator Certification Rept Sept 1995-Sept 1999 3F1099-02, Monthly Operating Rept for Sept 1999 for Crystal River,Unit 3.With1999-09-30030 September 1999 Monthly Operating Rept for Sept 1999 for Crystal River,Unit 3.With ML20212E6911999-09-21021 September 1999 Safety Evaluation Supporting Proposed EALs Changes for Plant Unit 3.Changes Meet Requirements of 10CFR50.47(b)(4) & App E to 10CFR50 ML20211L1321999-08-31031 August 1999 EAL Basis Document 3F0999-02, Monthly Operating Rept for Aug 1999 for Crystal River,Unit 3.With1999-08-31031 August 1999 Monthly Operating Rept for Aug 1999 for Crystal River,Unit 3.With ML20212C1501999-08-31031 August 1999 Non-proprietary Version of Rev 0 to Crystal River Unit 3 Enhanced Spent Fuel Storage Engineering Input to LAR Number 239 ML20211B7291999-08-16016 August 1999 Rev 2 to Cycle 11 Colr ML20210P1111999-08-0505 August 1999 SER Accepting Evaluation of Third 10-year Interval Inservice Insp Program Requests for Relief for Plant,Unit 3 ML20210U5341999-07-31031 July 1999 Monthly Operating Rept for July 1999 for Crystal River,Unit 3 ML20209F5601999-07-31031 July 1999 EAL Basis Document, for Jul 1999 3F0799-01, Monthly Operating Rept for June 1999 for Crystal River,Unit 3.With1999-06-30030 June 1999 Monthly Operating Rept for June 1999 for Crystal River,Unit 3.With ML20210U5411999-06-30030 June 1999 Revised Monthly Operating Rept for June 1999 for Crystal River,Unit 3 3F0699-07, Monthly Operating Rept for May 1999 for Crystal River,Unit 3.With1999-05-31031 May 1999 Monthly Operating Rept for May 1999 for Crystal River,Unit 3.With ML20210U5601999-05-31031 May 1999 Revised Monthly Operating Rept for May 1999 for Crystal River,Unit 3 ML20195C6271999-05-28028 May 1999 Non-proprietary Rev 0 to Addendum to Topical Rept BAW-2346P, CR-3 Plant Specific MSLB Leak Rates ML20196L2031999-05-19019 May 1999 Non-proprietary Rev 0 to BAW-2346NP, Alternate Repair Criteria for Tube End Cracking in Tube-to-Tubesheet Roll Joint of Once-Through Sgs 3F0599-04, Monthly Operating Rept for Apr 1999 for Crystal River Unit 3.With1999-04-30030 April 1999 Monthly Operating Rept for Apr 1999 for Crystal River Unit 3.With ML20210U5631999-04-30030 April 1999 Revised Monthly Operating Rept for Apr 1999 for Crystal River,Unit 3 3F0499-04, Monthly Operating Rept for Mar 1999 for Crystal River Unit 3.With1999-03-31031 March 1999 Monthly Operating Rept for Mar 1999 for Crystal River Unit 3.With ML20204D9661999-03-31031 March 1999 Non-proprietary Rev 1,Addendum a to BAW-2342, OTSG Repair Roll Qualification Rept 3F0399-04, Special Rept 99-01:on 990310,discovered Containment Tendons That Required Grease Addition in Excess of Prescribed Limits During Recent Insp Activites.Six Tendons Were Refilled with Appropriate Amount of Grease1999-03-10010 March 1999 Special Rept 99-01:on 990310,discovered Containment Tendons That Required Grease Addition in Excess of Prescribed Limits During Recent Insp Activites.Six Tendons Were Refilled with Appropriate Amount of Grease 3F0399-03, Monthly Operating Rept for Feb 1999 for Crystal River Unit 3.With1999-02-28028 February 1999 Monthly Operating Rept for Feb 1999 for Crystal River Unit 3.With ML20203A4381999-02-0303 February 1999 Safety Evaluation Supporting EAL Changes for License DPR-72, Per 10CFR50.47(b)(4) & App E to 10CFR50 ML20206E9891998-12-31031 December 1998 Kissimmee Utility Authority 1998 Annual Rept ML20206E9021998-12-31031 December 1998 Florida Progress Corp 1998 Annual Rept ML20206E9701998-12-31031 December 1998 Ouc 1998 Annual Rept. with Financial Statements from Seminole Electric Cooperative,Inc 3F0199-05, Monthly Operating Rept for Dec 1998 for Crystal River Unit 3.With1998-12-31031 December 1998 Monthly Operating Rept for Dec 1998 for Crystal River Unit 3.With ML20206E9261998-12-31031 December 1998 Gainesville Regional Utilities 1998 Annual Rept 3F1298-13, Monthly Operating Rept for Nov 1998 for Crystal River,Unit 3.With1998-11-30030 November 1998 Monthly Operating Rept for Nov 1998 for Crystal River,Unit 3.With 3F1198-05, Monthly Operating Rept for Oct 1998 for Crystal River,Unit 3.With1998-10-31031 October 1998 Monthly Operating Rept for Oct 1998 for Crystal River,Unit 3.With ML20155F4071998-10-31031 October 1998 Rev 2 to Pressure/Temp Limits Rept ML20155J2701998-10-28028 October 1998 Second Ten-Year Insp Interval Closeout Summary Rept 3F1098-06, Monthly Operating Rept for Sept 1998 for Crystal River Unit 3.With1998-09-30030 September 1998 Monthly Operating Rept for Sept 1998 for Crystal River Unit 3.With ML20206E9461998-09-30030 September 1998 Utilities Commission City of New Smyrna Beach,Fl Comprehensive Annual Financial Rept Sept 30,1998 & 1997 ML20206E9561998-09-30030 September 1998 City of Ocala Comprehensive Annual Financial Rept for Yr Ended 980930 ML20206E9101998-09-30030 September 1998 City of Bushnell Fl Comprehensive Annual Financial Rept for Fiscal Yr Ended 980930 ML20206E9811998-09-30030 September 1998 City of Tallahassee,Fl Comprehensive Annual Financial Rept for Yr Ended 980930 ML20195E3121998-09-30030 September 1998 Comprehensive Annual Financial Rept for City of Leesburg,Fl Fiscal Yr Ended 980930 3F0998-07, Monthly Operating Rept for Aug 1998 for Crystal River Unit 3.With1998-08-31031 August 1998 Monthly Operating Rept for Aug 1998 for Crystal River Unit 3.With ML20236W6501998-07-31031 July 1998 Emergency Action Level Basis Document 3F0898-02, Monthly Operating Rept for Jul 1998 for Crystal River,Unit 11998-07-31031 July 1998 Monthly Operating Rept for Jul 1998 for Crystal River,Unit 1 ML20236V8801998-07-30030 July 1998 Control Room Habitability Rept 3F0798-01, Monthly Operating Rept for June 1998 for Crystal River Unit 31998-06-30030 June 1998 Monthly Operating Rept for June 1998 for Crystal River Unit 3 ML20236Q4611998-06-30030 June 1998 SER for Crystal River Power Station,Unit 3,individual Plant Exam (Ipe).Concludes That Plant IPE Complete Re Info Requested by GL 88-20 & IPE Results Reasonable Given Plant Design,Operation & History 3F0698-02, Monthly Operating Rept for May 1998 for Crystal River Unit 31998-05-31031 May 1998 Monthly Operating Rept for May 1998 for Crystal River Unit 3 1999-09-30
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e.ee Florida Power C ORPOR ATioN June 28, 1988 3F0688-19 Document Control Desk U.S. Nuclear Regulatory Commission Washington, D.C. 20555
Subject:
Crystal River Unit 3 Docket No. 50-302 Operating License No. DPR-72 Emergency Feedwater
Dear Sir:
Enclosed is a report addressing the concerns on the leak at BFV-18.
Additionally, a Licensee Event Report concerning this subject will be submitted by July 21, 1988.
Should there be any questions, please contact this office.
I Sincerely,
) )
i Rolf C. Widell, Director Nuclear Operations Site Support RCW/REF/dhd Bnclosure xc: Regional Administrator, Region II Senior Resident Inspector l
8807060345 880628 ff PDR ADOCK 05000302 gjp S PDC Post Office Box 219
- Telephone (904) 795-3802 (
A Florida Progress Company
-t. ,- .
FLORIDA POWER CORPORATION CRYSTAL RIVER UNIT-3
' EMERGENCY FEEDWATER LINE LEAK JUSTIFICATION FOR CONTINUED OPERATION MACEGROUND:
Following the. restart of crystal River-Unit 3 from Refuel VI
'in January 1988, a check valve (EFV-18) in the Emergency Feedwater Pump 3B (EFP-2) injection line to.the "B" Once Through' Steam Generator (OTSG) was identified as having a small bonnet leak. At the time of discovery, the water leaking from EFV-18 was cold, and thought to be from the emergency feedwater tank. A flow diagram is provided as Figure 1.
On May 27, 1988, during a routine. plant walk down, the Shift Operations Technical Advisor (SOTA) discovered the emergency feedwater piping for the "B" OTSG near flow control valve EFV-55 to be warmer than normal. This was an indication that check valve ~FWV-43 wac not preventing back flow into the emergency feedwater line from the OTSG. This was discussed with the' Shift Supervisor on duty at that time and increased awareness of the condition was maintained. By June 19, the temperature'of the line from the reactor building penetration ,
to EFV-18 was hot enough to cause some flashing of the water ;
-leaking from EFV-18. A Non-Conforming Operations Report (NCOR 88-81) was written on June 19, to evaluate and track the situation, and upon further investigation by the Engineering Department, a one hour report was initiated on
-June 21, based on exceeding the design basis temperature for the emergency feedwater line ( Ref: 10CFR72(b)(1)(ii)(B) ).
The elevated temperatures triggered an Engineering review of potential resolutions to the problem, and during the review it was determined that the original thermal analysis was calculated using a lower temperature than presently measured on' contact with the piping. The emergency feedwater piping and associated reactor building penetration design temperatures were originally specified as 1100F. The actual measured temperatures on contact with the piping and penetration exceeded this design specification. The maximum temperature reading recorded on the pipe at the penetration was 4900F. Attachment 1 provides a summary of temperature data' associated with the elevated temperatures of the piping and penetration. '
A review of operational history revealed several events which could have resulted in the heat up of the emergency feedwater lines and penetrations. Attachment 2 lists these events along with a brief explanation of each.
-,' i ,
INTERIM ACTIONS:
The following activities have been initiated or accomplished in response to the over heating of the emergency feedwater -
line.
- 1. Added water using EFP-2 to attempt to resent FWV-43 and to cool the emergency feedwater line on May 27, June 6, June 8, June 10 June 12 and June 19, 1988. The attempts to reseat FWV-43 were unsuccessful, and the cool down of the line met ,cith only temporary success.
- 2. Closed EFV-56 and EFV-57 (normally open "B" OTSG emergency feedwater flow control valves) on June 21 to prevent an inadvertent, manual addition of water to the heated line and penetration, and to possibly aid in the reduction of the leak at EFV-18 (See Figure 1). This action did not prevent the automatic EFIC actuated function of emergency feedwater to the "B" OTSG. The EFIC control logic will automatically open these valves upon initiation of emergency feedwater. These valves were reopened on June 22.
- 3. Performed a 100FR50 Appendix J Type B pressure test to accident pressure on the annular space of emergency feedwater penetration #109 on June 21. The test demonstrated the penetration remains leak tight.
- 4. Performed visual inspections of the piping, components and the penetration from EFP-2 to the exterior end cap of penetration F109 at the reactor building wall including the main fiedwater branch cross connection at FWV-34. These inspections were conducted on June 20, 21, and 22. In addition a visual inspection of accessible piping inside -the reactor building was performed. There were no apparent deformation or yielding of the piping, supports or penetration with the exception of EFH-126, a six way pipe restraint. This pipe restraint is a branch line structural support and the damage involved the anchor bolts pulling away from the concrete floor slab by approximately 1/4 to 1/2 inch. There was also surface chipping and spalling of the concrete adjacent to the anchor bolt penetration holes. An analysis of the effects of the EFH-126 damage was commenced along with repair efforts on the pipe restraint.
The restraint was repaired on June 24. The repair included replacement of the three 5 inch and one 8 inch anchor bolts with four one inch in diameter 12 inch long anchor bolts and grouting the space between the base plate and concrete ceiling. The analysis is discussed in the Justification for Continued Operation (JCO) section.
4
- 5. Initiated analysis on the following:
Manual calculations on the thermal stresses on the penetration steel components and a review of the temperature effects on the concrete-components (initiated June 21)
Thermal analysis on the piping inside the reactor building based on the elevated temperatures (initiated June 21)
Thermal analysis on the piping outside the reactor building in response to the elevated temperatures (initiated June 23)
Ret ..a 1 these analyses are discussed in the JC0 C .toL.
- 6. Initiated a Non-Destructive Examination (NDE) on the endplate to pipe weld at the penetration outside of the reactor building. The results of the NDE activities are provided in the JC0 section.
- 7. A radiograph of FWV-43 was performed on June 23. The valve internals appear to be intact and functional.
- 8. Installed a temporary modification on June 22 to short circuit the leak at EFV-18 to prevent hot water from migrating from the "B" OTSG to EFV-18. A diagram of the flow path of the modification is provided in Figure 2.
This modification, MAR T88-06-ll-01, utilizes a small positive displacement pump to inject water back into the emergency feedwater line at drain valve EFV-65 at a rate that slightly exceeds (approximately 1-2 liters per hour more) the collected leakage at EFV-18. By reinjecting the water into the emergency feedwater line at this point, the leak at EFV-18 is short circuited, thus preventing hot condensate water from the "B" OTSG migrating toward EFV-18, and a resultant heatup of the piping and penetration. This temporary modification cooled the line and has prevented the recurrence of the temperature rise enperienced in the line due to the EFV-18 leak.
- 9. Initiated a review of the long term environmental qualification issues essociated with components on the emergency feedwater line.
L - . . - _ _ _ _ _ _ _ _ _ _ _ _ -
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}.
s JUSTIFICATION-FOR CONTINUED OPERATION The temporary modification installed on June'22 to control the leak at EFV-18 has successfully maintained the
-temperatures of the'energency feedwater line to well below-1500F. .The.present penetration temperatures are being maintained at 95 to 1500F. 'This has reduced the-thermal
-stresses on'the.line,-components, and penetration to within acceptable design conditions,.and has eliminated the concerns Lover' thermal shock and water hammer in the event of emergency feedwater initiation.
The ability to maintain the system configuration, metering pump, makeup, etc., is enhanced by hourly monitoring of system operation and contact temperatures on the emergency feedwater pipe at the reactor building penetration. An additional pump and other components essential to the operation have been obtained and made available in the event that failure of these components should occur. The change out of the major components is estimated to require approximately two hours, and based on an observed 15.to.20 degree per hour temperature rise when the leak is not abated, the repair effort could be accomplished without exceeding 1500F at the penetration.
.There is an additional method to prevent the temperature in the emergency feedwater line from increasing should the above modification fail to accomplish this. Either emergency
'feedwater pump can.be placed into recirculation and the appropriate flow control valve, EFV-55 or EFV-57, opened a small amount to allow water to be injected into-the-line.
Thereby short circuiting the leak in much the same way as the installed temporary modification. Although this is not intended to be utilized for long durations, it would allow sufficient time to re-establish the temporary metering pump as the primary means of leak control while precluding an unacceptable temperature rise in the emergency feedwater line.
le The "B" OTSG emergency feedwater line check valve, FWV-43, which,is allowing back flow from the OTSG is also of concern.
This valve may not be completely seated due to insufficient differential pressure across the valve needed to overcome the slight frictional forces in the hinge mechanism, or to force the disc into a fully seated position. This valve is listed in CR-3's Technical Specifications Table 3.6-1 as a containment inclation valve but requires only a functional test of its ability to open and allow emergency feedwater injection into the "B" OTSG. There are no requirements to
-leak check this valve or to test its isolation time. Since the steam side piping and OTSG provide the primary containment integrity boundary, the only credible design basis accident involving FWV-43 is a steam generator tube rupture (SGTR). Nith FWV-43 allowing back flow and EFV-18 experiencing a leak to atmosphere, an unmonitored release path could exist to the environment during a SGTR scenario.
While this is an undesirable condition, the small leak at EFV-18 (approximately 0.5 to 1 gpm) does not significantly
[
- , a impact the offsite doses during such an event and is bounded by1the FSAR accident analysis which assumes all noble gas and iodine radioisotopes are released through the main steam relief-valves for.the duration of the event. There are no significant-adverse conditions anticipated inside the plant
=which would prevent safe shutdown operations due.to such a
. release.
Preliminary analysis of the one-piping restraint, EFH-126, which was identified as recently damaged from stresses induced by the-heated pipe indicate that dead load capability of-the piping was not_affected, but that the seismic restraint capability was reduced to less than acceptable safety factor's. This support was repaired on June 23. The repair effort was commenced in parallel with the analysis effort and was completed prior to the verification of the analytis il results which indicated problems with the seismic loading en the pipe restraint. Continued operation with the damaged support was deemed acceptable due to the short time -
frame of the-loss of this pipe restraint combined with the low probability of a seismic event at CR-3.
The higher than analyzed for temperatures on the emergency feedwater line, components and penetration are under analysis. Preliminary results have been reviewed and the n following conclusion made.
Penetration M :
The concrete in the innsdiate vicinity of Penetration #109 has not been degraded and is still capable of meeting its original design requirements. The maximum measured concrete surface temperature near the penetration sleeve was 1950F.
The penetration sleeve was measured at 2720F on the exterior surface of the reactor bailding. Concrete temperatures are postulated to be higher on the outside edges and cooler toward the center of the penetration due to higher heat trans#er from contact with the penetration end plates.
Appendix A, titled "Thermal Considerations," of the ACI Code 349. O," Code Requirements for Nuclear Safety Related Conccete Structures" allow long term temperatures in local areu (such as around penetrations) of 2000F maximum.
Temperatures of 3500F for concrete surfaces are permitted for accident or any other short term period. Concrete chemical
, composition breakdown which would significantly affect concrete strength does not typically occur until temperatures (concrete) exceed 4000F.
The conservative thermal stress analysis of penetration #109 steel indicated that the 3/4 inch thick, outside containment, end plate had been stressed to the point where it deflected to relieve the thermal loading. This does not af# met the operability of the penetration or the piping since this end plate is not considered as part of the containment coundary or as a pipe support. The end plate was attached to the
-3.. .
2 penetration sleeve to allow pressure testing during plant
. construction. The containment boundary at the penetration is formed by a two inch thick end plate on the inside containment end of the penetration assembly. The thermal stress analysis indicated that the loading on this plate remained well below code allowable. Visual examinations conducted on the penetration external end pla,es and process pipe revealed no damage. Leak rate testing at containment peuk accident pressure also confirmed that the penetration remains intact.-
A liquid penetrunt examination of the penetration end plate to process pipe weld outside of the reactor building was conducted to reveal whether any damage had resulted from
- stresses induced by the increased temperatures. No indications were identified from the examination.
During the initial review phase following the discovery of the high temperature, continued operation was deemed acceptable based on the following:
Visual inspections of the penetration steel and surrounding concrete both inside and outside of the reactor building which revealed no apparent damage, Acceptable testing of the penetration to accident pressure utilizing a 10CFR50, Appendix J, Type B test, and Review of the design and function of the penetration end plates.
Emergency Feedwater Line Piping and Supports:
The thermal analysis for the piping inside the reactor building indicates that the piping and pipe hungers have not been subjected to stresses excaeding the design allowables and that all supports remained witidn allowable stress values when the thermal loads were combined with dead weight and OBE loading conditions. The thermal analya*,s on the piping outside of the reactor building has nat been coupleted.
Following discovery of the elevated temperatures, continued operation was deemed acceptable based on the following:
Visual inspections of accessible portions of the affected piping and pipe supports both inside and outside of the reactor building identified only one restraint which had partially pulled loose from its point of attachment, and no other pipe or pipe support damage or expansion contact indications.
Review of piping and support configuration which indicated the layout of the line afforded a good measure of flexibility to accommodate the thermal stresses which would be expected under these conditions.
Review of potential problems with water hammer effects in
~
the event-of emergency feedwater initiation indicated that this was an unlikely event based on the line being at the steam generator pressure and temperature, and the fact that the' initial injection would be with heated water which would reduce the likelihood of water hammer. -The once through steam generator emergency feedwater nozzles exit into the steam space, and the nozzle header routinely -
contains.some steam during normal operations.
LONG TERM ACTIONS:
Florida Power Corporation is presently developing options for long term repair efforts. These options include:
Online leak repair of EFV-18
- Repair of EFV-18 during a Mode 5 outage. The next scheduled Mode 5 outage is Refuel VII in September 1989.
However, this valve would be repaired during any unscheduled Mode 5 outage, and FPC is exploring the potential windows of opportunity for a scheduled outage this fall if the online leak repair efforts are unsuccessful.
Upgrade of the emergency feedwater piping, components and penetrations to accommodate the increased temperatures recently experienced.
If the emergency feedwater lite leak increases dramatically, or heating of the pipe or penetration occurs which cannot be controlled and exceeds 1500F, Florida Power Corporation will consider the emergency feedwater line as inoperable and take the specified actions stated in the Technical Specifications.
_ _ _ _ _ _ )
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.ATTACRMENT 1 EMERGENCY FREDW&TER LINE TEMPERATURE PROFILES PEN # PEN #
DATE TIME 109 (SLV) 109 (PIPE) FWV-43 EFV-55 EFV-18 ,.
6/19/88 - - -
490*F 330' F 228 F 6/21/88 -
272 F 480 F 480 F 375 F 255'F 6/22/88 1230 298 F 475 F 460 F 334 F 258 F 1830 224 F 278 F 240 F 122 F ,
122*F 2100 173 F 169 F -
111 F 107 F 6/23/88 0130 120 F 122*F 118 F 98 F 97 F 0600 110 F 106 F 101 F 98 F 96 F 6/24/88 0800 108 F 112 F -
92*F 94*F 1600 -
128 F - - -
6/25/88 - -
97*F - - -
6/26/88 - -
96 F - - -
,,.. e
ATTACHMENT 2 HISTORY OF EMERGENCY FREDWATER LINE
, TEMPERATURE EXCURSIONS REFERENCE DESCRIPTION UOBR 82-25 Applied main feedwater through the emergency feedwater line for approximately 17 minutes. No temperature data was available, however, main feedwater temperatures would be expected to be approximately 4750F.
LER 82-76 Failure of EFW ultrasonic flow meters due to excessive pipe temperatures. No times or temperatures were available LER 83-43 Failure of EFW ultrasonic flow meters due to excessive pipe temperatures due to back flow through FWV-43. No time or temperatures were available.
EQ #88-1191 Identified apparent overheating of all four emergency feedwater lines while plant was in Mode 2 in March 1988. The lines were cooled using emergency feedwater and the temperature rise was not experienced again until June.
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