ML17352A224
| ML17352A224 | |
| Person / Time | |
|---|---|
| Site: | Turkey Point, Saint Lucie  |
| Issue date: | 08/06/1993 |
| From: | Merschoff E NRC OFFICE OF INSPECTION & ENFORCEMENT (IE REGION II) |
| To: | Goldberg J FLORIDA POWER & LIGHT CO. |
| References | |
| NUDOCS 9309100135 | |
| Download: ML17352A224 (58) | |
Text
AUG -6 l993 Docket Nos. 50-250, 50-251, 50-335, 50-389 License Nos.
DPR-31, DPR-41, DPR-67, NPF-16 Florida Power and Light Company ATTN:
Hr. J.
H. Goldberg President
- Nuclear Division P. 0.
Box 14000 Juno
- Beach, FL 33408-0420 Gentlemen:
SUBJECT:
MEETING TO DISCUSS ENGINEERING INITIATIVES AT FLORIDA POWER AND LIGHT This letter refers to the meeting conducted at your request at the NRC Region II offices in Atlanta on July 16, 1993.
The purpose of the meeting was to allow Florida Power and Light (FPL) to make a presentation on engineering initiatives at FPL.
It is our opinion that this meeting was beneficial and provided a better understanding of the issues and status of current programs.
In accordance with Section 2.790 of the NRC's "Rules of Practice,"
Part 1,
Title 10, Code of Federal Regulations, a copy of this letter and its enclosures will be placed in the NRC Public Document Room.
Should you have any questions concerning this letter, please let us know.
Sincerely,
Enclosures:
1.
List of Attendees 2.
Presentation Summary cc w/encls:
D. A. Sager Site Vice President St. Lucie Nuclear Plant P. 0.
Box 128 Ft. Pierce, FL 34954-0128 Ellis W. Herschoff, Director Division of Reactor Projects 9~09100f g5 g30806 PDR ADQCK 05000250 P
Florida Power 8 Light Company AUG -6 lm cc w/encls cont'd:
T. F. Plunkett Site Vice President P. 0.
Box 029100 Miami, FL 33102 L.
W. Pearce Plant General Manager Turkey Point Nuclear Plant P. 0.
Box 029100
- Miami, FL 33102 T. V. Abatiello Site equality Manager Turkey Point Nuclear Plant P. 0.
Box 029100 Miami, FL 33102 E. J.
Weinkam Licensing Manager Turkey Point Nuclear Plant P. 0.
Box 029100
- Miami, FL 33102 R.
E. Grazio, Director Nuclear Licensing P. 0.
Box 14000 Juno
- Beach, FL 33408-0420 G. J.
Boissy Plant General Manager P. 0.
Box 128 Ft. Pierce, FL 34954-0128 Harold F. Reis, Esq.
Newman 5 'Holtzinger 1615 L Street, NW Washington, D.
C.
20036 John T. Butler, Esq.
- Steel, Hector and Davis 400 Southeast Financial Center
- Miami, FL 33131-2398'ill Passetti Department of Health and Rehabilitative Services 1317 Winewood Boulevard Tallahassee, FL 32399-0700 cc w/encls cont'd:
(See page 3)
Florida Power
& Light Company AUG -6 l993 cc w/encls cont'd:
Attorney General Department of Legal Affairs The Capitol Tallahassee, FL 32304 Administrator Department of Environmental Regulation Power Plant Siting Section State of Florida 2600 Blair Stone Road Tallahassee, FL 32301 Joaquin Avino County Manager of Metro Dade County ill NW 1st Street, 29th Floor
- Miami, FL 33128 Jack Shreve Public Counsel Office of the Public Counsel c/o The Florida Legislature ill West Madison Avenue, Room 812 Tallahassee, FL 32399-1400 Joe Myers, Director Division of Emergency Preparedness 2740 Centerview Drive Tallahassee, FL 32399-2100 Thomas R. L. Kindred County Administrator 2300 Virginia Avenue Ft. Pierce, FL 34982 Charles B. Brinkman Washington Nuclear Operations 12300 Twinbrook Parkway, Suite 3300 Rockville, MD 20852 bcc w/encls:
K. Landis, RII J. Norris, NRR L. Raghavan, NRR St. Lucie Resident Inspector Turkey Point Resident Inspector Document Control Room RI
- DRP RSchin 8/0/93 RII:
P RII:DRP KL n is MSinkule 8/5 /93 8/4 /93
ENCLOSURE I LIST OF ATTENDEES NRC L. A. Reyes, Deputy Regional Administrator, Region II (RII)
J.
R. Johnson, Deputy Director, Division of Reactor Projects (DRP), RII J.
P. Jaudon, Deputy Director, Division of Reactor Safety (DRS), RII N. N. Berkow, Director, Project Directorate II-2, DRP-I/II, Office of Nuclear Reactor Regulation (NRR)
M. V. Sinkule, Chief, Reactor Projects Branch II, DRP, RII C. A. Julian, Chief, Engineering
P. Schin, Project Engineer, DRP, RII G. A. Hallstrom, Reactor Inspector, Materials and Processes
H. Goldberg, President, Nuclear Division W. H. Bohlke, Vice President, Nuclear Engineering and Licensing J.
B. Hosmer, Director, Nuclear Engineering G. J. Boissy, Plant General
- Manager, St. Lucie J. Scarola, Site Engineering
- Manager, St. Lucie D. H. West, Technical
- Manager, St. Lucie L. A. Rogers, Supervisor, Instrumentation and Control Maintenance, St. Lucie D.
M. Wolf, Supervisor, Site Engineering, St. Lucie J. J. Hutchinson,
- Manager, Equipment Support and Inspections
ENCLOSURE 2
NRC/FPL SEMIANNUALCOMMUNICATIONMEETING NRC REGION Il OFFICE, ATLANTA JULY 16, 10:00 A.M. - 12 NOON
PURPOSE Discuss Engineering And Technical Support To Both Plants Nith Focus Qn:
- 1) St Lucie Challenges
- 2) Process Improvements
INTRODUCTIONS J. Goldberg W.H. Bohlke G.J. Boissy J.B. Hosmer D.H. West L.A. Rogers J. Scarola D.M. Wolf J.J. Hutchinson President, Nuclear Division Vice President, Nuclear Engineering And Licensing Plant General Manager, PSL Director, Nuclear Engineering Manager, PSL Technical Support Supervisor, PSL I&CMaintenance Project Manager, PSL Engineering Supervisor, PSL Site Engineering Manager, Equipment Support 8c Inspections
NRC/FPL SEMIANNUALCOMMUNICATIONMEETING NRC REGION II OFFICE, ATLANTA JULY 16, 1993 10:00 A.M. - 12 NOON MEETINGAGENDA
~
INTRODUCTION/PURPOSE'SL CHALLENGES
~ ST. LUCIE RCP SHAFT ROOT CAUSE EVALUATION
~
ST. LUCIE PRESSURIZER INCONEL 600 NOZZLE
~ UNLATCHEDCEA
~
DROPPED CEA
~ ST. LUCIE CODE SAFETIES
~ ST. LUCIE LESSONS LEARNED W. BOHLKE D. WEST J.SCAROLA'.
HUTCHINSON L. ROGERS D. WOLF G. BOISSY 5 MIN
'I5 MIN 10 MIN 10 MIN 10 MIN 10 MIN 10 MIN PROCESS IMPROVEMENTS
~
ENGINEERING PROCESS IMPROVEMENTS TO SUPPORT OPERATIONS & MAINTENANCE
~
OPEN DISCUSSION J.HOSMER 5 MIN 25 MIN
ENGINEERlNG JOURNEY
~ Successfully Transitioned To A3E Independence
~ Conduct Quarterly Self Assessments
~ Transition Continues As Engineering Focuses On involvement With Operations And Maintenance
~ People Philosophy
- More People On Site
~ Product Philosophy
- Products More Focused On Operations And Maintenance
~ Avoid Repeating Mistakes (Internal/Industry}
- Problem Reports
..- Tech Alerts
ST. LUCIE REACTOR COOLANT PUMP I.BACKGROUND VENDOR'RYON JACKSON HEAD/FLOW:
245 FT/81,250 GPM SEAL:
~ 4 Stages including Vapor Seal
~ 1-1.5 GPM Controlled Bleed Off
~ Seal injection Capability installed As Modification
~ Seal inlection Used For FillAnd Vent, Heat-Up And Cooldown
~ Design Pressure 2485 psig
~ Design Temperature 250' SHAFT:
~ 304 Stainless Steel
~ Stainless Steel Pump Hydrostatic Bearing COOLING: ~ CCW Cools Motor And Seal HNP/A355-1
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II. PROBLEM
~ PSL NO. t 6/30/90 Pump 1A1 Experienced High Seal
- Leakoff Flow Requiring Plant Shutdown-Resultant Inspection Revealed Bent Shaft
~ PSL NO. 2 1/13/93 Pump 3A1 Experienced High Vibration Requiring Plant Shutdown - Resultant Inspection Revealed A Cracked Shaft
~
For Both Events The Unit Was Safely Shutdown Based On Existing Indications Aec)ACULATINS IQPGLER (6 ))
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AREAOF CRACKIN SHAFT2A1 AND BEND IN SHAFT 1A1 HYDAO5TATlc BEAANO (5 1)
I 4 ~
HNP/A357%
2A1 CRACK LOCATIONS:
THERMAL BARRIER ZONE RUNOUT GROOVE CRACKS I/
SHAFT Q UPPER SIDE PLATE HNP/A362<
III. ANALYSlS
~ Formed Plant/Engineering Team
~ Byron Jackson/Combustion Engineering Participation
~ Performed Dimensional & NDE of 2A1 Shaft
~ Review Operating/Maintenance/Modification History
~ 2A1 8 1A1 RCP's Idle for H/U &C/D
~ Reviewed 1A1 (Unit No. 1) Analysis
- Confirmed Thermal Transient Can Bend AShaft
~ Industry Survey
- Use of Seal Injection
- Other RCP Shaft Failures o Preliminary Root Cause Is Thermal Stress From Seal Injection
~ Analysis Continuing HNP/A358-5
SHORT TERM IV. CORRECTIVE ACTIONS Plant and Engineering Team Assigned To Address Short Term Actions
~ Installed New Rotating Assembly
- Improved Alignment Procedures
~ Engineering/Operations/Maintenance Evaluation Of Operating w/o Seal Injection
~ Changed Procedures On Both Units To Eliminate Use Of Seal Injection, Except During Fill And Vent Operations And Emergency Procedures
~ Moved Vibration Monitoring Instrumentation From Lower Motor To Pump Coupling
~ Prepared Startup Procedure For Monitoring
& Data Collection HNP/A360A4
V. LONG TERM CORRECTIVE ACTIONS A. Long Term Root Cause Team Formed
- St. Lucie Plant Staff Mechanical Maintenance
- St. Lucie Plant Reliability Maintenance
- St. Lucie Plant Technical Staff
- Nuclear Engineering Pump Specialists
- Nuclear Engineering Supervisor Component Specialists
- Nuclear Engineering Thermal/Hydraulic Analysis Specialist
- Nuclear Engineering Systems & Operations Specialist
- Nuclear Engineering Design
- Nuclear Engineering Metallurgist
- Pump Vendor (Byron Jackson)
V. LONG TERM CORRECTIVE ACTIONS (Continued)
B. Long Term Root Cause Team Overall Action Plan 0 Osing Event Tree/FMEA Methodology To Identify Potential Causes
- Perform Pump Shaft Metallurgical Analysis
- Perform Stress Analysis - Pump Rotor
- Operating & Maintenance Procedures Review
- Analyze Manufacturing And Pre-Service Test Data
- Evaluate RCP Modification Packages
- Evaluate RCP Vibration Data (Prior To 8c Following Failure}
- Provide Additional Monitoring Instrumentation To RCPs
- Draw Conclusion Re Root Cause
- Recommend Further Corrective Actions And Issue Report HNPIA363A4
V. LONG TERM CORRECTIVE ACTIONS (Continued)
C. Action Plan Status
~ Manufacturing & Pre-Service Data Analysis Completed
- Concluded That InitiallyDefective Assembly ls Not A Probable Root Cause
~ Thermal Stress Analysis
- Preliminary Conclusion That Seal Injection Thermal Stresses Can Propagate Small Surface/Subsurface Flaws (c.010 In)
- Crack Initiation & Propagation Investigation ls Continuing
- Definition Qf Mechanical Loads That Could Cause Crack Propagation Is Continuing
~ RCP Runout
~ RCP Shaft Misalignment
~ S/U Torque Against Reverse Flow
~ Disassembly Of Pump Rotating Assembly For Dimensional Sc Metallurgical Analysis Has Begun HNP/A419-9
Vl.
SUMMARY
~ Replaced Damaged RCP Rotating Assembly
~ Changed Procedures To Eliminate Use Of Seal Injection (Suspected Root Cause)
~ Relocated Vibration Monitoring Probes To Pump Side Of Coupling
~ Proceeding With Further Analysis To Confirm Root Cause And Final Corrective Actions
~ Expect Final Recommendations By 12/93 10 HNP/A364A-10
PRESSURIZER INSTRUMENT NOZZLE CRACKING March 3, 1993, Visually Identified Four Steam Space Nozzles With Leakage On Unit 2 In Mode 5
~
Background:
- SONGS 3 Instrument Nozzle Leaks '86
- Pressurizer Steam Space Nozzles Replaced '87
- Hot Leg & Pressurizer Liquid Space Replaced '89
~ Analysis:
- No Significant Safety Hazard
- Susceptible Material Inconel Alloy600
- High Temperature Environment
~ Root Cause:
- Primary Water Stress Corrosion Cracking
~ Immediate Corrective Action:
- Steam Space Nozzles Replaced With Alloy690
- Inspected Liquid Space Nozzles Of Same Heat
~ Long Term Corrective Actions:
- Inspect During Refueling lnconel 600 Nozzles
- Replace Pressurizer Liquid Space Nozzles In '96
- Continue To Monitor Industry Data JS/A400-1
Figure 1 I-600 SUSCEPTIBILITYTO PWSCC FUNCTION OF STRESS, ENVIRONMENTAND MICROSTRUCTURE (1) RESIDUAL (2) APPLIED (1) PRIMARYCOOLANT CHEMISlRY (2) TEMPERATURE MIGROSTBUGTUBE
- CARBIDEDISIRIBUTION
+ Y.S. INDICATOR 1400 gatsrht Chmactsrisths PWSGG POTENTIAL
PRESSURIZER INSTRUMENT NOZZLE REPAIR
~ Examination Phase:
- NSSS To Perform The Work
- Independent Oversight (FPL 5 Vendor)
- PT Examination
- Destructive Examination
~ Surface Preparation:
- Removal Of Cracks
- Clad Build-Up
~ Nozzle Replacement:
- Nozzles Machined
- Nozzles Welded ln Place
~ Errors Made:
- ASME Code Compliance
~ Size Of Weld Rods
.. ~ Thermocouple Placement
- Work Control
~ Lessons Learned:
- improve Technical Oversight On Special Process Jobs
~ Safety Significance:
- Qualified Weld
ST. LUC/F UNIT 2 PRESSURIZER UPPER 4 LOWER INSTRUMENTHOZZLEANAL%IS PRESSURIZER NOZZLE EXAMPINDINGS UPPER NOZZLE LOCATIONS(PCtt KN64$7)
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SURGE NOZZLE 120 ELECTRIC HEATERS (30)
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ST LUCIS UNIT 1 McLOY 600 RCS PBNBTRLTION SUXXARY (3-93)
PBN3T$UkTION TYPB (HBAT g)
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PZR NOZZLBS STATUS PRBDICTBD LIFB REPLACEMENT INSPECTION RBCOMMENDATION RECOMMENDATIONS 7-STBAM Ec NOR .
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MONITOR MONITOR MONITOR NONB NON PRBSSURB-APPLICATION MONITOR 1100 DAYS c 1100 DAYS c 1100 DAYS NA NORMAL B.A.
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- Indicates heats vith industry failure history.
NOTB: i) Based on one failure point, hut many more survival points exist with
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ST LUCER UNIT 2 ALLOY 600 RCS PBNBTRATION SUXXARY (3-93)
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STATUS CRACKED 3-93 PRBDICTBD LIFB RBPLACEMENT RECOMMENDATION ALLOY 690 (1993)
INSPECTION RECOMMENDATIONS
( 1100 DAYS 1-WATER SPACB-(41501 *)
NOT LBAKING 28,000 HRS ALLOY 690 0 BOC 8 RBMAININQ (1995)
FROM 3-93 1100 DAYS 2-HATER SPACB (NX7630/7387-2)*
II PZR HTR SLBBVBS 30-SLBBVBS (VARIOUS HEATS III. RCS NOZZLBS 2-RV 0 RING LEAK MONITOR TUBBS 54318
- 5-HOT LBG RTD's (41501
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NOT LBAKING NOT LEAKING NO KNOWN LBAKS NOT LEAKING BEYOND PRBDICTION (NOTB 1)
LOW SUSCBPTIBILITY 97,000 HRS REMAINING FROM 3-93 ALLOY 690 0 BOC 8 (1995)
MONITOR NONE NON PRBSSURB APPLICATION MONITOR/RBPLACB c 1100 DAYS 1100 DAYS NORMAL B.A.
WALKDOWN 9-HOT LBG R%S's NX7630
NOT LEAKING NOT LBAKINQ NOT LBAKING NOT LBAKING x 40 YRS
> 40. YRS NO FAILURES)
) 40 YRS (NO FAILURBS)
~ 40 YRS NONB NONB NONE NONB
<< Indicates heats with ndustry failure history.
NOTB: 1) Based on 1992 failure data at other CB designed plants.
NORMAL B.A.
HALKDOWN NORMAL B.A.
HALKDOWN NORMAL B.A.
HALKDOWN NORMAL B.A.
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ST. LUCIE UNIT81 UNLATCHEDCONTROL ELEMENTASSEMBLY Back round:
~ May 29th, 1993 Low Power Physics Testing Indicated Anomaly With Rod Worth Associated With Dual CEDM ¹7
~ Additional Low Power Physics Tested Indicated That Only One Of The Two CEAs Was Coupled
~ Decision Was Made To Shutdown And Dissassemble The Reactor To Pursue Root Cause
~ Cross Functional Team Consisting Of Tech Staff/Operations/
Maintenance/Fuels/And Engineering Formed To Determine Root Cause J HUTCH/A414-1
Page GOof 50 ST. LUCIE UNIT 1 OPERATING PROCEDURE NO. 1110022, REVISION 12 COUPUNG AND UNCOUPUNG OF CEA EXTENSION SHAFTS Qae ss Qsr 38 Qso Oo BS 33:
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ST. LUCIE UNIT01 UNLATCHEDCONTROL ELEMENTASSEMBLY Short Term Actions
- 1. Core Physics Predictions Analyized To Verify Initial Conclusions
- 2. AllCEA Drive Shafts Reweighed &Pin Postion Verified
- 4. Performed Engineering Study By Use Qf Fault Tree To Examine Potential Root Causes
- 5. Performed Visual/Dimensional inspections To Verify As-Found Condition JHUTCH/A4164
ST. LUCIE UNITN UNLATCHEDCONTROL ELEMENTASSEMBLY Root Cause Ph sical Ins ection Results:
- 1. Inboard CEA N03 Found Unlatched From Dual Extension Shaft ¹7
- 2. Dual CEDM Shaft ¹7 Removed From Upper Guide Structure.
Functionally, Dimensionally And Visually Checked-No Anomalies Noted
- 3. Inspection Of CEA Hubs N03 &¹98 Showed No Damage
- 4. Inspection Of Dual Shroud And Associated Area Above Fuel Found No Anomalies JHUTCH/A415-7
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ST. LUCIE UNIT01 UNLATCHEDCONTROL ELEMENTASSEMBLY Lon Term Actions
- 1. Enhance Coupling/Uncoupling Procedure By:
(a) Add Requirements To Measure Coupled Extension Shaft Height (b) Include Step To VerifyAdequate Slack Exists In Coupling Tool Suspension System
- 2. Human Factor Improvements To Improve Indicator Pin Verification (a) Supply Additional Lighting To Assist Position Indicator Pin Verification (b) lndependant Verification Of Position Indicator Pin Location
- 3. Improve Training Of Personnel On The Implementation Of The Coup1ing And Verification Procedure J HUTCH/A417%
ST. LUCI.E UNIT2 DROPPED CEA EVENT BACKGROUND
~ May 21, 1993
~ Reactor At 72% Power - Steady State; Water Box Cleaning In Progress
~ Seven CEAs Dropped Fully Into Core
~ Reactor Manually Tripped
~ Fuel Group Analysis Concluded:
- DNBR & PLHR Limits Not Exceeded
- SAFDLs Not Violated
- Event Bounded By Design Basis Analysis LAR/A424-1
ST. LUCIE UNIT2 DROPPED CEA EVENT ANALYSIS
~ Root Cause Team Formed
- Tech Staff Engineers
- l&CEngineers
- Site Design Engineers
- ABB-CE Design Engineers
- Containment Penetration Vendor Design Engineers
~ Numerous Inspections &Tests Performed
- CEDMCS System Component/Functional Test
- Meggered &Tested AllCEDM Penetrations For Grounds.
- Time Domain Reflectometer (TDR)
- Local Leak Rate Testing (LLRT)
- Visual Inspection Of Penetration With Vendor
~ Root Cause For Event
- Grounds In Containment Electrical Penetration
ST. LUCIE UNIT2 DROPPED CEA EVENT IMMEDIATECORRECTIVE ACTIONS
~ Meggered AllCEDMs From CEDMCS To Identify Grounds
~ Re-Routed Grounded Connections To Tested Spare Penetration Conductors
~ Monitored Output Of MGs Via Power Line Monitor LONG TERM CORRECTIVE ACTIONS
~ Perform Inspection Of Defective Penetration To Identify Failure Mechanism
~ Addition Of Ground Detection System To CEDMCS Bus
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St Lucle Unit2 LER NUMBER(6)
YEAR VISI MB PAGE
)
0500089 TEXT (JYmote space ls rrqoikad, use aNi5crtal NRC Form JSR4w)
(1
)
13-0070005 0
5 Qm Qm Qm0 I
NS output disconnect breakers C
3 C
240 YAG 3 phase I
I C
)
Trip CIrcuit Brokers CEA tvbgrovp fuses
~
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D 01 Containment Hectrlca/
Pdndtratlons CEA 8
coils CEA 54 coils GEA 60 coils CEA 61 coils CEA 63 coils GEA 66 coils
'GEA 67 coils FIGURE ONE-CEA POWER Dl TRIBU ION FPL Facstrrt tte ot NRC Form 385 (8-I)9) 8'd WQU 3IDITl I.S le MUSS:87 E6r 88 irIL'
ST. LUCIE PLANT PRESSURIZER CODE SAFETY VALVELEAKAGE PRIOR TO 'f992
~ Use Of Crosby Valve Company (OEM) For Overhaul Of Valves To Assure Consistency And Expert Workmanship
~ Revised Valve Testing Methodology To Test At NOP/NOT Conditions (AtWylie Test Labs) And Strengthen Acceptance Criteria For Leakage
~ Evaluated Nozzle Loads With Respect To Vendor Recommended Values
~ Converted To Rexi-Disc Design 0WOLF/A379-2
FLEXI-DISC CONVERSION Sggggggt9 DISC INSERT f FLEXI DISC INSERT pggVIOQS CROSBY
, eaaT COSrIOUNRTION
/
" HODIFIED SShT KtEh NICK ~PLSXIBLE TOOT
ST. LUCIE PLANT PRESSURIZER CODE SAFETY VALVELEAKAGE
'I992 LEAKAGEEVENTS Unit 1
~ Gradual Increase ln Leakage To Quench Tank
~ Operational Difficulties ln Maintaining Quench Tank Level &Temperature
~ Shutdown On Sept. 14th To Replace Valve V1202 IInstrumented Nozzles To Determine Loading Unit2
~ Gradual Increase In Leakage To Quench Tank
~ Operational Difficulties In Maintaining Quench Tank Level &Temperature
~ Shutdown On Nov 24, 1992 & Replaced Valves V't201 &V'1202
~ Optimized SRV Tailpipe Spring Can Support
NON-LEAKINGPLANTS WITH CROSBY SAFETY VALVES PLAMTSiIMFO PLANT <<I (TMo Units)
PLANT <<2 PLANt <<3
<tm Units)
PLANt <<4 Italo Units)
PLANT <<5 PLANT <<S SEAT LEAKAGE KO NO MO NO NININAL OR NONE
- NIKOR, IMPROVED VALVE/SIZE LOOP SEAL MSS 3-CROSBY 6H6 DRAINED MESI INGHtXJSE CROSBY 3kgS NONE MESTIMGHOUSE 400 NME 3.CROSBY 6HS 1.DRAIKED 2-HOT MESTINGHtXJSE 3 CROSBY 6MS DRAINED NEST INGMOUSE 2-CROSBY 4N,6 KONE SAM RUPTURE DISK CROSST SNS DRAINED QESTINGHOUSE VALVE TRIM FLEXI-DISC 2 MvsW tooohy el f1oRNc 1 wkh Cwelv ec Wtlo FLEXI-DISC 2 INSTALLfD 199D FLEXI-DISC 2 FLEXI-DISC 2 FLEXI-DISC 1 INSTALLED 1982 FLEXI.DISC 1
NAX NOZZLE LOADS (X OF CROSBY ALLOMASLES)
<<50X
<<100X
<<50X ADDED FLEX JOINT
<<50X OX TEE MlTH RUPTURE DISC
<100X SEAT LK TEST PRES.
(X OF LIFT) 95X ON SlN 93X ON STN 93X ON SIN 93X ON S'fN 94X ON STN SRV AMBIENT CONDITIONS (F) 120 140 145-155 i20-140 100 CNNENTS 1.
REDUCED NOZ. LOADS (eajor effort) 2.
ADDED FLEXI DISC 2 3.
REDUCED AMBIENT TEHPo ADDED HVAC DUCT 4.
IMPROVED NAINT. S TESTING
- 95X LK TEST ON STN - ZERO LK,
- OPtlCAL FLAIS AT 'I LIGHT SAR TEST AT MTLE CROSBY REP. SNIETINES 1.
REDUCED KOZ. LOADS (reeeved I ibid support, added snubbers) 2o ADDED FLEX( DISC 2
- 3. ANIENT TEMP REDUCTION KONE 4.
INCREASED TES'flNG REON'TS:
- 93X LK TEST OM StN - ZERO LK.
- OPTICAL FLAlS (optional)
- TEST At MEST. MITH CROSBY REP.
- 1. DRAINED LOOP SEALS, AMD LEAKAGE STARTED.
ADDED FLEXIBLE JOINT 2.
CHAXGED TO FLtXI-DISC 2 3.
TESTING AMD ININlt
- 93X LK TtST OM STN
- OP'f ICAL FLATS CHANGED TO NEST. (PRICE C SERV)
'1.
SRV SEAT LEAKAGE HAS KOT BEEN A.
PROBI.EN
- 2. MAINTENANCE ND TESTING:
- 93X LK TEST ON STEAN
- TEST Af QYLE IIITH CROSBY REP.
- 1. PIPE IKNS - REHOVED TAILPIPIKG, 1978 RENOVED LOOP SEALS AXD INSTALLED TEES MITH RUPTURE DISC ADDED FLtXI DISC 1
3o AINIENt TEMP REDUCllOM MONE 4o IKCREASED TESllNG REON TS
- 93X LK TEST ON SIN - ZERO LK.
- OPTICAL FLATS (optional)
'fESt AT MYLE USE IN HOUSE OINT.
- 1. IKOIFIED PIPE TO IMPROVE ALIGNMENT
- 2. SRV'S Sit ON PLATFORM PINKED TO PRESSURIZER 3
AMBIENT TEKP REDUCTION -
NOME 4.
IKCREASED LEAK TEST PRESS TO 94X ON NITROGEN MITH 10 BUB/NIN 5.
TESTING LOC. - MYLE LASS MITH REP,
ST. LUCIE PLANT PRESSURIZER CODE SAFETY VALVELEAKAGE LONG TERM ACTIONS
~ hllaintenance/Engineering/Staff Component Specialist Cross Functional Team Formed To Focus On Resolution
~ Industry Analysis
- 1. Six Utilities (Crosby Valves) Identified With Successful Results
- 2. Identified Common Aspects Associated With Leakage Reduction
- Consistent Maintenance &Testing Requirements
- Flxi-DiisValve Trim
- Stable Valve Ambient Temperatures
- Nozzle Loads c Crosby Allowable DWOLF/A3tt14
ST. LUCIE UNIT 1 PRESSURIZER SAFETY VALVE PIPE NODIFICATION SPRAY LI PRESSURIZER CUBICLE V-1200 PRESSURIZER V-1202 V-1201 0
QUENCH TANK NEW HANGER
ST. LUClE PLANT PRESSURlZER CODE SAFETY VALVELEAKAGE ACTlON PLAN
~ More Stringent Leak Test Acceptance Criteria
~ Remove Tailpipe Cold Spring And ModifySupports To Reduce Valve Nozzle Loads Unit 1 - 3993 Refueling Outage'nit 2 - 1994 Refueling Outage
~ ModifyLocal Insulation To Reduce Adverse Temperature Effects ("Chimney Effects'} On SRVs Unit 1 - 1993 Refueling Outage Unit 2 - 1994 Refueling Outage
~ Review Results Of The Above Actions DWOLF/A382-5
ST. LUCIE LESSONS LEARNED
~ Team Remains Strong
~ Plant Performance Remains Strong
~ Plant Work Is Proactive 5 Conservative JGB/A428%
ENGINEERING PROCESS & PRODUCT IMPROVEMENT
~ 6/92 A/E Independence Complete
~ 70- 80% Engineering Manhours By FPL
~ Transitioning To Operations/Maintenance Products
& Direct Support
~ Meaning
- People's Attitudes Must Change On Their Accountabilities & Products
- Management Needs To Change Training Emphasis
ENGINEERING PROCESS 8c PRODUCT IMPROVEMENT PEOPLE EMPHASIS Onsite Outage Package Implementation Supplement Site Engineering
& Maintenance During Outages Onsite Leadership
- Problem Solving
- Assistant Outage Directors Shift Training Emphasis From Design To Plant Operations Juno PEGs All Juno Engineering Juno & Site Engineering Engineering Management 10-15 People Each Site 10-15 People Each Site
- Unlatched CEA
- 4 Outage Directors
- ESI Role
- 4 SRO Complete
-2 to 4SRO
'93
- System Training
- New Grad Training
- Accountability
- Feedback
- Direct Plant Support
- People Development
- Technical Leadership
- Plant Knowledge JBH/A256
ENGINEERING PROCESS 8c PRODUCT IMPROVEMENT
,PRODUCT EMPHASIS i~4%~k'"-&it" ~- 14+iN!kxa.r. K ~ii@lR~ce""'4>A" NW%:."aW4 Maintenance Operations PSL Custom Vendor Manuals Setpoint Document Maintenance Specificatio'ns Engineering Basis For PMs PTN Split & Enhance P&IDs PTN As Built Drawing Backlog DBDs
- Plant Change/Modification Packages (PCMs) 3 New Design Output Products:
~ IEE
~ MEP
~ DCR 50 Complete PSL Complete 12/93 Both Sites 16 Complete Both Sites Start 7/93 Both Sites PTN,Complete.
PTN Complete
- PTN Complete 15/40 PSL Complete
- Improved Troubleshooting & PMs
- Defined Basis
- One Document
- Independent Maintenance Action Within Design Basis
- Better PMs
- Legibility
- Accuracy
- Improved Drawings, Quality
- Problem Solving
- Operation Training
- Improved Responsiveness JBHtA258