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Category:REPORTABLE OCCURRENCE REPORT (SEE ALSO AO LER)
MONTHYEARL-95-089, Special Rept:On 950517,Standby Feedwater Pump B Removed from Svc & Returned to Operable Status 950710.Caused by Prime Mover for B Standby Feedwater Pump Being Changed from Electric Motor to Diesel Driver Per Amend 164/1581995-04-21021 April 1995 Special Rept:On 950517,Standby Feedwater Pump B Removed from Svc & Returned to Operable Status 950710.Caused by Prime Mover for B Standby Feedwater Pump Being Changed from Electric Motor to Diesel Driver Per Amend 164/158 ML20235M9971989-02-23023 February 1989 Special Rept:Fire Protection Sys Impaired for Greater than 7 Days.On 890118,rust Holes Noted on Fire Door 67-2.On 890121,repair Required for Thermolog Insulation.Caused by Time Deterioration.Fire Patrols Established L-87-140, Special Rept:On 870225,electric Driven Fire Pump Exceeded 7- Day Tech Spec Limit for Permissible Time Pump May Remain Out of Svc W/O NRC Notification.Caused by Leakage of Bearing Grease Past Seal.Shaft,Sleeves & Bearings Replaced1987-03-27027 March 1987 Special Rept:On 870225,electric Driven Fire Pump Exceeded 7- Day Tech Spec Limit for Permissible Time Pump May Remain Out of Svc W/O NRC Notification.Caused by Leakage of Bearing Grease Past Seal.Shaft,Sleeves & Bearings Replaced L-87-141, RO 87-03:on 870315,NRC Notified of Intention to Remove IAEA Seals on Equipment Hatch & Reactor Missile Shields.Caused by Performance of Maint & Insps on Reactor Head.Addl Work Will Be Performed When Reactor Head Removed1987-03-25025 March 1987 RO 87-03:on 870315,NRC Notified of Intention to Remove IAEA Seals on Equipment Hatch & Reactor Missile Shields.Caused by Performance of Maint & Insps on Reactor Head.Addl Work Will Be Performed When Reactor Head Removed ML20210D1791987-01-30030 January 1987 RO 87-01:on 870127,area Lights in Spent Fuel Pool Burnt Out. Caused by Low Wattage Bulbs.Bulbs Replaced W/Longer Life Bulbs.Area Lights Will Be Verified Once Per Day L-86-500, Ro:Fire Barriers Breached for More than 7 Days.Caused by App R Work Which Still Remains to Be Completed.Compensatory Measures Implemented.Affected Fire Barrier/Conduit Seals Listed1986-12-0808 December 1986 Ro:Fire Barriers Breached for More than 7 Days.Caused by App R Work Which Still Remains to Be Completed.Compensatory Measures Implemented.Affected Fire Barrier/Conduit Seals Listed L-86-485, Special Rept:On 861030,electric Driven Fire Pump Out of Svc for More than 7-day Tech Spec Limit.Caused by Independent Failure of Low Pressure Start Switch & Flow Indicator, Resulting in Unscheduled Maint.Bearing Seal Replaced1986-12-0101 December 1986 Special Rept:On 861030,electric Driven Fire Pump Out of Svc for More than 7-day Tech Spec Limit.Caused by Independent Failure of Low Pressure Start Switch & Flow Indicator, Resulting in Unscheduled Maint.Bearing Seal Replaced L-86-456, Special Rept:Fire Barriers Breached for Longer than 7 Days. Caused by App R Work in Progress.Breached Barriers Listed1986-11-0606 November 1986 Special Rept:Fire Barriers Breached for Longer than 7 Days. Caused by App R Work in Progress.Breached Barriers Listed L-86-377, Special Rept:On 860819,condenser Air Ejector High Range Noble Gas Effluent Monitor Exceeded 7 Day Outage Reportability Limitations Established in Tech Spec Table 3.5-5.Caused by Water Intrusion Into Casing of Detector1986-09-18018 September 1986 Special Rept:On 860819,condenser Air Ejector High Range Noble Gas Effluent Monitor Exceeded 7 Day Outage Reportability Limitations Established in Tech Spec Table 3.5-5.Caused by Water Intrusion Into Casing of Detector L-86-283, RO 86-3:on 860708 & 10,loss of Lighting in Spent Fuel Pool Occurred.Caused by Deenergization of 4-kV Bus 4C.Bus Realigned to Normal Power Supply.Work Plans Discussed in 860708 Telcon1986-07-11011 July 1986 RO 86-3:on 860708 & 10,loss of Lighting in Spent Fuel Pool Occurred.Caused by Deenergization of 4-kV Bus 4C.Bus Realigned to Normal Power Supply.Work Plans Discussed in 860708 Telcon L-85-146, Special Rept:On 850308,diesel Driven Fire Pump Declared Out of Svc as Result of Inoperable Immersion Heater in Diesel Cooling Sys.Caused by Defective Thermostat Switch.Immersion Heater Assembly Replaced1985-04-0808 April 1985 Special Rept:On 850308,diesel Driven Fire Pump Declared Out of Svc as Result of Inoperable Immersion Heater in Diesel Cooling Sys.Caused by Defective Thermostat Switch.Immersion Heater Assembly Replaced ML20079Q8771983-10-0505 October 1983 RO 251-83-016:discovered Containment Spray Pumps 4A & B on Both Manual Discharge Valves 4-891A & B Locked in Closed Position.Investigation in Progress.Related Info Encl ML20084B7041978-08-25025 August 1978 Ro:On 780813,metal Impact Monitoring Sys Alarmed Six Times in 1 H.Caused by Acoustic Emissions Produced by Reactor Vessel During Periods of Changing Pressure & Temp.Tubesheet Photographs of Steam Generators Verified ML20084F2561975-12-0505 December 1975 RO 251-75-3 Re Leak of Spent Fuel Pit Concrete Wall. V-shaped Stainless Steel Drain Trough Installed on Concrete Wall of Fuel Transfer Tube.Mod of Spent Fuel Storage Sys Under Consideration ML20084F3211975-12-0505 December 1975 RO 250-75-3:on 751105,spring Hanger on Main Steam Line 3A Inside Containment Found Distorted.Cause Unknown.Plant Change/Mod Being Generated to Provide New Hanger Design to Withstand Spurious Closure Load & Hydro & Test Loads ML20084F7161975-08-18018 August 1975 ROs 250-75-2 & 251-75-2 Re Several Malfunctions of Spent Fuel Pit (SFP) Cooling Pumps.Cause Not Determined.Excessive Internal Stress Suspected as Cause.Redundant Cooling Pump to Be Installed in Each SFP Cooling Sys ML20084F5861975-07-0707 July 1975 RO 251-75-1 Re ECCS Analysis.Audit by Westinghouse of Calculations of ECCS Analysis for Large Break Spectrum Cycle 2 Has Shown Value for Peak Clad Temp in Error.Caused by Using Fuel Design Data for Unit 3 ML20084F6971975-04-14014 April 1975 RO 250-75-1 Re Apparent Discrepancy Between Measured Control Rod Worth & Vendor Predictions.Cause Not Stated.Fuel Vendor Recalculated Predictions & Results Are Now Consistent W/Util Predicted Values ML20084C1321974-12-20020 December 1974 RO 251-74-6:on 741201,w/planned Shutdown in Progress,Turbine Tripped.Caused by Failure of Turbine Control Valve Spring Adjusting Bolt.Defective Bolt Replaced & Zyglo Testing of Remaining Three Bolts Performed ML20084C0921974-11-26026 November 1974 RO 74-5:on 741126,filling of Spent Fuel Pit & Reactor Refueling Cavity During Refueling Revealed Leaks in Stainless Steel Liners of Both Structures.Cause Under Investigation.Small Head Tank Installed as Temporary Action ML20084C6411974-08-0808 August 1974 RO 250-74-5:abnormally High Failure Rates Occurred in Teledyne/Philbrick-Nexus Type 140801 Operational Amplifiers Used in Upper & Lower Flux Deviation Circuits.Cause Unknown. Investigation to Recommend Solution to Be Performed ML20084C6651974-07-15015 July 1974 ROs 250-74-3 & 251-74-3:capacitor Failures in Rod Control Power Supply Filter Assemblies Caused Control Rod Drops, Initiating Turbine Runbacks.Cause Unknown.Investigation in Process by Vendor ML20084C6461974-07-0101 July 1974 ROs 250-74-4 & 251-74-4:numerous Failures Experienced W/ Sample Suction Pumps Employed in Tracerlab Containment Gaseous & Air Particulate Radiation Monitoring Sys.Cause Unknown.Re Evaluation of Leak Detection Sys in Progress ML20084C6931974-05-31031 May 1974 Ro:On 740425,generators in Both Units Tripped When Both Generator Circuit Breaker Protection Sys Relays Energized During Functional Testing of Unit 4 Startup Transformer Protection Sys Relays.No Equipment Damage or AO Resulted ML20084C7061974-05-30030 May 1974 RO 250-74-2 & 251-74-2:while Conducting Normal Shutdown on Unit 3,turbine Stop Valves Failed to Close.Caused by Phosphate Deposits Between Valve Shafts & Bushings.Phosphate Buildup Problems Also Found W/Unit 4 ML20084D0571974-04-0202 April 1974 Suppl to Special Maint Rept 73-1:on 731211,investigation Conducted Re Torque Check of Fischer & Porter Co Electronic Differential Pressure Transmitters Due to High Failure Rate. Caused by Inadequate Clamping Force ML20084D2311973-12-11011 December 1973 Special Maint Rept 73-1:on 731023-25 & 1103-05,during Startup & Initial Operation,Fischer & Porter Co Electronic Differential Pressure Transmitters,Models 2495 & 2496 Found to Fail Internally.Caused by through-bolts Not Torqued 1995-04-21
[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
[Table view] |
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' > May 31, 1974 i .
1 m (o 4 q Mr. Norman C. Moseley, Director Region II Directorate of Regulatory Operations p fg'If t/g t y, ,
gg U. S. Atomic Energy Commission -
q Wg A uri 230 Peachtree Street, N. W., Suite 818 T 'c r Atlanta, Georgia 303D3 17.- 5.#gh, .W 8 NU h:;
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Dear Mr. Moseley:
TURKEY POINT PLANT / Q' T]"~ t '
l DOCKET NOS. 50-250 AND 50-251 UNIT TRIPS - APRIL 25, 1974 I
At the request of Mr. Austin Hardin of your staff, we are re-porting the tripping of Units 3 and 4 at the Turkey Point Plant.
SUMMARY
About 3:49 p.m., on April 25, 1974, Unit Nos. 3 and 4 ceneratun trippea wnen both generator circuit breaker protection system relays were energized during functional testing of Un'it No. 4 I
Startup Transformer protection system relays.
Trip of Unit Nos. 3 and 4 turbine-generators caused an auto- '
matic trip of both Unit Nos. 3 and 4 reactors. The reactor protection systems and engineered safeguards system equipment performed satisfactorily after the reactors tripped.
There was no equipment damage, abnormal occurrence or unusual event as a result of the unit trips.
Unit No. 3 was returned to service at 5:45 p.m., on April 25, 1974. .
Unit No. 4 was returned to service at 5:40 a.m., on April 26, 1974.
UNIT CONDITIONS BEFORE TRIPS l Unit No. 4 Startup Transformer was electrically isolated for functional testing of protection system relays and periodic maintenance on associated equipment. All of the specified 1 '
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clearance requests, notifications, authorizations and approvals necessary to begin work on No. 4 Startup Transformer were met.
All of the conditions specified in the Technical Specifications for this work were also met.
Unit No. 4 had been operating at 723 MWe (98% R.P.) steady-state power level for several hours before the trip. Unit No. 3 had been operating at 720 MWe (97% R.P.) steady-state power level for several hours.
DESCRIPTION OF OCCURRENCE No. 4 Startup Transformer protective relays were tested and de-monstrated satisfactory operation. However, when the Startup Transformer lockout relay was " reset", current flowed through an unanticipated path (" sneak circuit") and energized Unit No. 4 generator breaker protection system relays. This opened both of the generator breakers on Unit Nos. 3 and 4. Both No. 3 and 4 reactors tripped.
automatically tripped when the turbine-generators The minimum system frequency recorded during the transient was 58.6 Hz. Underfrequency load shedding relays operated to reduce the interconnected system load by automatically opening feeder breakers. Frequency was restored to 60 Hz within six seconds interconnected system power flows were returned to normal within twenty minutes.
We estimate 99% of FPL's customers were back in service within twenty minutes, though some isolated outages lasted up to an hour. Some short term power interruptions also occurred to customers on other Florida systems as a result of the incident.
The instantaneous loss of 1443 MWe, when both Unit Nos. 3 and 4 tripped, is the largest single loss of generation experienced in FPL's system. In comparison to previous system disturbances,
' customer load was restored faster than any previous occurrence.
Refer to Table I for load shedding data.
DESIGNATION OF APPARENT CAUSE OF TRIPS Review, analysis, and evaluation of Unit Nos. 3 and 4 annunciators, records and Turkey Point Plant switchyard oscillographs concluded that both Unit Nos. 3 and 4 generators breakers. operated as a result of the actuation of the generato'r Sack-up protection relays during functional testing of Unit No. 4 Startup Transformer relays.
.-m pir. Norman C.O aseley .O
. Page'3 May 31, 1974 .
ANALYSIS OF OCCURRENCE UNIT NO. 3 When No. 3 reactor tripped, the reactor protection system and engineered safeguard system equipment operated properly to place the unit in a safe condition. There was no equipment damage, abnormal occurrence or unusual event as a result of this trip.
After the cause of the trip was determined and conditions ev-aluated as satisfactory, the reactor was returned to service.
No. 3 unit conditions after the unit trip were more conservative than similar incidents analyzed and presented in Section 14 of Turkey Point Unit Nos. 3 and 4 FSAR. Therefore, Unit No. 3 trip did not present any danger to the health and safety of the public.
UNIT NO. 4 When No. 4 reactor. tripped, all reactor protection system and engineered safeguards system equipment operated properly to place the unit in a safe condition even though No. 4 Startup Transformer was electrically isolated and normal auxiliary power supply was unavailable. Emergency power supply was~ supplied by automatic start of both A and B Emergency Diesel-generators.
The emergency Diesel-generators continued to operate until No. 4 Gia: Lup Transformer was returned to service.
About five minutes after No. 4 reactor tripped, the 1085 psig safety valve on No. 4A Steam Generator main steam line header lifted and did not rescat. Immediate operator actions included additional boration of the reactor coolant system to ensure that adequate reactor shutdown margin was maintained. Feedwater flow-to No. 4A Steam Generator was controlled to maintain adequate water level while efforts were made to close the safety valve. When the manual lif ting device was removed from the safety valve, the safety valve rescated. (Refer to Figure 1 for details)
Review of Unit No. 4 recorder charts, indicators and annunciators show that No. 4A loop cold Icg temperature was reduced to a minimum of 517 F (compared to normal hot shutdown temperature of 547 F) and maintained this temperature for about. thirty minutes.
No. 4A loop cold leg temperature returned to 547 F within an' additional thirty minutes. This rate of temperature change is well within allowable cooldown rates. Nos. 4B and 4C loop cold leg temperatures increased 10 to 15 F to about 565 F af ter the unit trip, then returned to 547 F within about thirty minutes.
l
Mr.NormanC.o u scley .O
'Page 4 May 31, 1974 There was no equipment damage, abnormal occurence, or unusual event as a result of this trip. After the cause of the unit trip was determined, No. 4 Startup Transformer returned to servicq and auxiliary power supply restored, the reactor was returned to service.
Comparison of No. 4 reactor conditions after the trip with similar incidents analyzed and presented in Section 14 of Turkey Point Unit Nos. 3 and 4 Final Safety Analysis Report concludes that actual conditions were equal to or more conservative than the conditions assumptions in the Safety Analysis. Therefore, the Unit No. 4 trip did not present any danger to the health and safety of the public.
CORRECTIVE ACTION Florida Power 4 Light Company Relay Engineers have recommended that both Unit Nos. 3 and 4 Startup Transformer protective system be modified by installing additional isolation switches and a diode to provide for complete isolation of the primary and the back-up protection system relays during relay tests. This recom-mended change is being reviewed to obtain approval and authorization necessary to make this change.
If you have further questions about this occurrence, please do not hccitate to call me.
Very truly yours, Ic-
. D.' Schmidt Director of Power Resources VTC/kaw cc: Mr. John F. O' Leary Jack R. Newman, Esquire m
9
FLORIDA POWER 6 LIGilT COMPANY TURKEY POINT UNIT NOS. 364 UNIT TRIPS - APRIL 25, 1974 TABL'E I The underfrequency relay trips shed the interconnected system load as follows:
UTILITY LOAD - MW Florida Power 6 Light Company 850 Florida Power Corporation 330 Tampa Electric Company 130 Jacksonville Electric Authority 100 Orlando Utilities Commission 34 City of Lakeland 18 TOTAL 1 462
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The failure of the safety valve to rescat after opening was found to be caused by the loss of a cotter key in the safety valve topworks.
This cotter key locks the manual 11f t collar in proper position on the safety valve spindle. When.the cotter key vibrated out, the manual i lift collar vibrated down and made contact with the manual lifting device.
When the safety valve operated, the manual lift collar rotated further dowrl the spindle. This physically prevented the safety valve from rescating as the steam pressure decreased.
The safety vdive was rescated by removirig the manual i i f ting arm.
The safety valve was repaired by returned the manual. lift collar to j
its original position, installing a new cotter key, and replacing the manual lifting arm. .The safety valve.is now operable.
,