ML20059H990
| ML20059H990 | |
| Person / Time | |
|---|---|
| Site: | Mcguire, McGuire  |
| Issue date: | 10/29/1993 |
| From: | Nerses V Office of Nuclear Reactor Regulation |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 9311100303 | |
| Download: ML20059H990 (43) | |
Text
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fl%[j (sy5
%, v p NUCLEAR REGULATORY COMMISSION WASHWGTON, D C. 20555M Octoter 29, 1993 Docket Nos. 50-369 and 50-370 LICENSEE: Duke Power Company FACILITY: McGuire Nuclear Station Units 1 and 2
SUBJECT:
SUMMARY
OF MEETING WITH DUKE POWER COMPANY On September 29, 1993, the NRC staff met with representatives of Duke Power Company (DPC) and Babcock & Wilcox (B&W) at NRC headquarters in Rockville, Maryland, to discuss the results of DPC's investigation into the Unit I steam generator tube leaks and DPC's action as a result of the findings from this investigation. .
Meeting attendees are listed in Enclosure 1. A copy of the non-proprietary handout available during the meeting is provided as Enclosure 2. Ted McHeekin, DPC, started the presentation by noting that Unit I had shut down on August 22, 1993, due to a 185 gallon per day primary to secondary leak in a steam generator (SG). Investigation of the problem found that there was a circumferential crack in a SG hot leg sleeved tube (39-72). Also, from SG tube inspections that were performed, it was found that there were hot leg weeping sleeves in A, B, and D SGs and a missed U-bend defect in B SG tube 41-43.
John Helmey, B&W, sumarized the B&W SG tube kinetic sleeving installation, ,.
the sleeve stress relief process, the sleeve non-destructive examination (eddy current and optional ultrasonic testing) and the sleeve qualification (by analyses and mechanical testing). Mr. Helmey also sumarized the 39-72 examination results. He concluded that failure was initiated on the inside tube diameter and the mechanism was primary water stress corrosion cracking (PWSCC). He concluded that the 39-72 material properties (the high yield strength in particular) indicated that the tube was highly susceptible to PWSCC and that the stress relief temperature (less than 1450*F) did not assure i long life for this tube.
Jim Begley, Packer Engineering, consultant to DPC, explained the development of a susceptibility ranking (SR) system to identify sleeved tubes with material and chemical properties that have a high susceptibility to PWSCC.
The SR system is intended to predict the life factor for other sleeved tubes ,
relative to the failed sleeved tube based on material factors such as yield ;
strenth and carbon content. The SR system was used as part of DPC's tube .
plugging criterion. The objective of the plugging criterion was to ensure :
that Unit I could safely operate to the end of Cycle 9. '
i 0500'a $M"!
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1 N 29,1993 DISTRIBUTION !
SGe attached page j Dan Mayes, DPC, summarized the McGuire Nuclear Station repair criterion and corrective action. The repair criterion for plugging sleeved tubes included:
. Sleeves that were dripping / weeping
. Sleeved tubes that were not axially restrained (there were 13 of them on the periphery of Unit 1)
= Sleeved tubes from the same heat as 39-72
= Sleeved tubes with protected life ranking of s 8.3 effective full power years Applying this criterion resulted in 98 sleeved tubes to be plugged. DPC noted that several planned corrective actions were being taken, namely:
= Qualify higher stress relief temperature
. Perform corrosion test to verify the expected effects of the higher stress relief temperature '
t
. Improve the non-destructive evaluation detection
. Have a repair plan in place for Unit 2 Bruce Hamilton, DPC, summarized the plant operating procedures and the trained personnel that are in place to contribute to reliable SG operation until the next refueling outage, and if the limits regarding SG tube leakage should be -
exceeded, the ability to respond to bring the plant down safely.
Following the presentation, DPC agreed to investigate potential enhancements to their primary-to-secondary leakage monitoring program for hot shutdown conditions and to have a conference call with the staff on the findings in Unit 2 (Unit 2 has B&W kinetically welded sleeves). In addition, the staff requested DPC to provide the technical report providing the basis for the susceptibility ranking system developed to predict the_ life factor of sleeved tubes.
'Jriginal signed by: l Victor Herses, Project Manager Project Directorate 11-3 Division of Reactor Projects - I/II Office of Nuclear Reactor Regulation
Enclosures:
- 1. List of Attendees
- 2. Handouts cc w/ enclosures: l See next page OFF LA:PD23: Dig PM:P.D23:DRPE AD F :DRPE KAME LBerry es:dt RHernanc.
DATE
\\ / \' /93 /0 / 1 4 /93 l'> / Sf /93 Document Name: MCGulRE/MCG.MTS
l >
i Duke Power Company McGuire Nuclear Station cc: l Mr. A. V. Carr, Esquire Mr. Dayne H. Brown, Director Duke Power Company Department of Environmental, 422 South Church Street Health and Natural Resources Charlotte, North Carolina 28242- Division of Radiation Protection 0001 P. O. Box 27687 Raleigh, North Carolina 27611-7687 County Manager of Mecklenberg County 720 East Fourth Street Mr. Alan R. Herdt, Chief ,
Charlotte, North Carolina 28202 Project Branch #3 U. S. Nuclear Regulatory Commission :
Mr. R. O. Sharpe 101 Marietta Street, NW. Suite 2900 2 Compliance Atlanta, Georgia 30323 Duke Power Company McGuire Nuclear Site Ms. Karen E. Long 12700 Hagers Ferry Road Assistant Attorney General ,
Huntersville, NC 28078-8985 North Carolina Department of Justice J. Michael McGarry, III, Esquire P. O. Box 629 Winston and Strawn Raleigh, North Carolina 27602 1400 L Street, NW. .;
Washington, DC 20005 Mr. G. A. Copp Licensing - EC050 ;
Senior Resident Inspector Duke Power Company c/o U. S. Nuclear Regulatory P. O. Box 1006 ,
Commission Charlotte, North Carolina 28201-12700 Hagers Ferry Road 1006 Huntersville, North Carolina 28078 Regional Administrator, Region II r Mr. T. Richard Puryear U.S. Nuclear Regulatory Commission Nuclear Technical Services Manager 101 Marietta Street, NW. Suite 2900 Westinghouse Electric Corporation Atlanta, Georgia 30323 Power Systems Field Sales 2709 Water Ridge Parkway, Suite 430 Mr. T. C. McMeekin Charlotte, North Carolina 28217 Vice President, McGuire Site '
Duke Power Company Dr. John M. Barry 12700 Hagers Ferry Road Mecklenberg County Huntersville, North Carolina 28078 ,
Department of Environmental i Protection 700 N. Tryon Street )
Charlotte, North Carolina 28202 f
I 1
1
i ENCLOSURE 1 September 29, 1993_ ;
McGuire Steam Generator Tube Leakage l Meeting Attendees Victor Nerses NRC/NRR ;
K. N. Jabbour NRC/NRR - Acting PD 2-3 .
T. C. McHeekin Duke Power /McGuire !
Tim Reed NRC/NRR Nick Economos NRC/RII l John Helmey BWNS ;
Sanford Hellman BWNS Jim Taylor BWNS Roy Kaye Duke / Catawba Bruce Hamilton Duke /McGuire Joe Donoghue NRR/DSSA/SRXB Gus Lainas NRC/NRR/AD/RII John Dosa Entergy/ANO Blake Lowery Duke Power / Nuclear Services i John S. Frice South Carolina Electric & Gas -
Greg Kammerdener Duquesne Light Company .
Mike Markley NRR/RPEB Bonnie Beaver Duke Power /McGuire Robert Sharpe Duke Power /McGuire ,
Alex G. Panagos Commonwealth Edison Company Jay R. Smith Commonwealth Edison Company Jim Begley Packer Engineering ;
Robert Hall Duke Power /McGuire Enigneering ',
Charles England BWNS Mac Geddie Duke /McGuire Station Manager :
Dan Mayes Duke / Power Ken Karwoski NRR/DE/EMCB H. F. Conrad NRR/DE/ENCB i Jack Strosnider NRR/DE/EMCB Emmett Murphy NRC/NRR/EMCB J. T. Wiggins NRR/DE l W. T. Russell NRR/ADT R. C. Jones NRR/DSSA/SRXB l
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ENCLOSURE 2 l
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i DUKE POWER COMPANY i l
MEETING WITH THE NRC STAFF i l
f TO DISCUSS ,
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McGUIRE UNIT 1 S/G A TUBE 39-72 LEAK l ,
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DU1B POTGR AGENDA TIME TOPIC PRESENTER 10:00 INTRODUCTION DUKE /
TED McMEEKIN 10:10 SLEEVE DESCRIPTION BWNS / JOHN HELMEY AND QUALIFICATION 10:30 PULLED TUBE / SLEEVE BWNS / JOHN HELMEY EXAMINATION ,
11:00 SUSCEPTIBILITY PACKER ENGINEERING /
EVALUATION JIM BEGLEY 11:30 REPAIR CRITERIA AND DUKE / DAN MAYES '
CORRECTIVE ACTION i
11:40 UNIT 1 PLANT RESPONSE DUKE / BRUCE HAMILTON 11:55 CONCLUSION DUKE / TED McMEEKIN i
. BHNS
DUKE POiGR INTRODUCTION
- UNIT 1 SHUTDOWN 8/22/93 DUE TO 185 GPD PRIMARY TO SECONDARY LEAK IN A S/G
- STEAM GENERATOR INSPECTION IDENTIFIED: ,
- HOT LEG WEEPING SLEEVES IN A, B, AND D S/G'S
- A MISSED U-BEND DEFECT IN B S'G TUBE 41-43 i
e A CIRCUMFERENTIAL CRACK IN A S/G HOT LEG SLEEVED TUBE 39-72 1
- COMPLETED ROOT CAUSE INVESTIGATION AND CONCLUSIONS CONCERNING TUBE 39-72
- DEVELOPED SLEEVED TUBE REPAIR CRITERIA ,
- COMPLETED P2 PAIRS ON UNIT 1 P
- PLAN TO IMPLEMENT SLEEVED TUBE CRITERIA ON UNIT 2 ;
i
- INPO NOTIFICATIONS SENT OUT TO INDUSTRY CONCERNING UNIT 1 S/G TUBE LEAKS AND FOLLOW-UP ACTIONS i
BWNS i
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SLEEVE DESCRIPTION .!
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QUALIFICATION .
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DWG PC1GR KINETIC SLEEVE INSTALLATION NON DESTRUCTIVE EXAMINATION O EDDY CURRENT E -
SLEEVE AXIAL POSITION WELD AXIAL POSITION EXPANSION DIAMETERS VERIFY NO DEFECTS l
STRESS RELIEF VERIFICATION 0 I (HAZ LOCATION)
.I O ULTRASONIC TESTING (OPTIONAL)
WELD BOND QUALITY I
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- BTOIS
DUIG PONER BWNS 3/4 KINETIC SLEEVE .
QUALIFICATION
SUMMARY
- DESIGN CRITERIA ,
ASME CODE II, III, XI USNRC REG. GUIDES 9
- ANALYSES STRESS / FATIGUE FLOW INDUCED VIBRATION THERMAL / HYDRAULIC ,
PLUGGING CRITERIA L
- MECHANICAL TESTING LEAK TEST ,
f PRESSURE CYCLE FATIGUE CYCLE THERMAL CYCLE :
TENSILE TEST i
BHNS
DUIG PCTGR BWNS KINETIC SLEEVE INSTALLATION
SUMMARY
TS SLVE TS SLVE '
SINGLE DOUBLE ^
PLANT DATE WELD WELD TSP SLVE McGUIRE-1 90 JAN 400 0 0 McGUIRE-1 91 SEP 0 459 0 McGUIRE-2 90 OCT 482 0 0 ,
McGUIRE-2 92 JAN 0 138 5 l
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l SLEEVE EXAMINATION l
PULLED TUBE / l l +
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Dire POhTR PULLED TUBE / SLEEVE ,
EXAMINATION j O TS SLEEVES / TUBES PULLED r (S/G - A, HL)
TUBE 39-72 LEAKING CONFIRMED VISUALLY i WELD BOND UT ,
NO LEAK PATH ,
ECT XWOUND EXAM CIRC INDICATION IN EXPANSION MRPC EXAM CONFIRMED INDICATION i TUBE 07-78 NOT LEP. KING ,
WELD BOND UT NO LEA.K PATH ,
ECT XWOUND EXAM
" GEOMETRIC DISTORTION" l SAME EFPY AS 39-72 ;
HIGH YS TUBE (63 KSI)
O LAB EXAMINATION VISUAL , PT, LEAK MECHANICAL PROPERTIES CHEMISTRY METALLOGRAPHY FRACTOGRAPHY ;
- Bh21S i
DU1T FGTCR PULLED TUBE / SLEEVE :
EXAMINATION .
r TUBE 07-78 O VISUAL / PT / LEAK ,
HEAT TINT ON SLEEVE NO DEFECTS NO LEAKS L
O METALLOGRAPHY / FRACTOGRAPHY PARENT TUBE:
NO DEFECTS i
SLEEVE: '
NO DEFECTS TUBE MATERIAL: .
ASTM 9.5 - 10.0 !
MIX INTRA / INTER CARBIDES .
O MECHANICAL / CHEMISTRY CMTR MEASURED YS (KSI) 63.0 60.8 UTS (KSI) 106.0 108 ELONG (%) 36.0 40.7 ,
CARBON (%) 0.03 0.035 .
O EXPANSION DIMENSIONS: NOMINAL i
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ans ;
DUKE PChTR PULLED TUBE / SLEEVE EXAMINATION HARDNESS EVALUATION O OBJECTIVE EVALUATE STRESS RELIEF TEMPERATURE O BASIS HARDNESS DROPS WITH HIGH SR TEMPERATURE
-O KNOOP MICRO-HARDNESS AFTER 1300 F AS RECEIVED FURNACE SR WELD VIRGIN WELD APEX MATERIAL APEX 39-72 TUBE: 284 231 279 SLEEVE: 322 192 334 07-78 TUBE: 270 195 268 SLEEVE: 323 176 323 MOCKUP HDN-1 TUBE: 322 (NO SR) 290 SLEEVE: 345 332 MOCKUP HDN-2 TUBE: 210 (1445 SR)
SLEEVE: 237 O CONCLUSIONS 39-72 & 07-78 WERE STRESS RELIEVED SR TEMP < 1445 F SR TEMP MOST LIKELY 21300*F
- BhWS
DU1G POhTR PULLED TUBE / SLEEVE EXAMINATION O CONCLUSIONS SLEEVES / TUBES 39-72 & 07-78 WERE STRESS RELIEVED (T < 1450 F)
SLEEVES IN TUBES 39-72 & 07-78 INSTALLED PER PROCEDURE RECEIVED SAME STRESS RELIEF TUBE 39-72 FAILURE WAS ID INITIATED PWSCC TUBE HIGHLY SUSCEPTIBLE TO PWSCC .
STRESS RELIEF TEMP DID NOT ASSURE LONG LIFE FOR THIS TUBE i
- 1
. BkWS
I DUKE' PChTR 1
TUBE SUSCEPTIBILITY l EVALUATION ;
\
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O BASIS CONSISTENT SLEEVING PROCESS STRAIN LEVELS STRESS RELIEF TEMPERATURE 1
TUBE MATERIAL PROPERTIES VARY WITH HEAT O TUBE PROPERTIES AFFECTING PWSCC FACTORS '
1 YIELD STRENGTH ASTM GRAIN SIZE GRAIN BOUNDARY CARBIDES ANNEALING TEMP ,
CARBON l -
CHROMIUM YIELD STRENGTH OVERRIDING PARAMETER :
EXCESS CARBON A CONTRIBUTING FACTOR >
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DUKE POWER SLEEVE EVALUATION FACTORS CONSIDERED f l !
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! MATERIAL FACTORS t l
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- YIELD STRENGTH !
- %C !
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PROCESS FACTORS i
- EXPANDED DIAMETER z
- HAZ-APEX DISTANCE !
- HEATER POWER VARIABLES l l
SERVICE FACTORS l l
- TIME IN SERVICE l l
- PRESENCE OF TSP DENT SIGNAL t CONCLUSIONS :
- THE ONLY DISTINGUISHING-VARIABLES'FOUND !
FOR 39-72 ARE HIGH YIELD STRENGTH, 72.5 .!
ksi, AND HIGH CARBON LEVEL, 0.05%.
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BNNS l-l -
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l DYJKB PO1GR 4
s SLEEVE JOINT EVALUATION FACTOR APPROACH .
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YIELD STRENGTH AND CARBON FACTORS ARE !
INDICATORS OF:
i PWSCC RESISTANCE i
RESPONSE TO STRESS RELIEF TREATMENT i
i 1
LIFE FACTOR = 1.19 x ;
a STRENGTH FACTOR x !
CARBON FACTOR 1.19 = EFPY FOR SLEEVE JOINT 39-72 EACH FACTOR IS NORMALIZED TO 1.0 FOR 39-72.
l i
THE LIFE FACTOR RANKS SLEEVE JOINTS RELATIVE !
TO 39-72 swns
. . _ . -. . - . .- .. - . . . = ._ a . ...
DUE PChTR TUBE SUSCEPTIBILITY EVALUATION O STUDSVIK CORROSION DATA PARAMETRIC STUDY OF TUBE PROPERTIES CORROSION TEST ALLOY 600 RUBS 689 F, HIGH PURITY WATER WITH HYDROGEN 25,000 HOURS TIME TO CRACK INITIATION ,
RESULTS YIELD STRENGTH: R2 = 0.93 YIELD STRENGTH, EXCESS CARBON, CHROME:
2 R = 0.95 (CHROME HAS MINOR EFFECT)
O APPLICATION TO SLEEVED TUBES STUDSVIK DATA NORMALIZE TO 39-72 PROPERTIES (72.5 KSI, 0.051%C, 15.37% Cr - 1.19 EFPY) 3 CURVE FITS YIELD STRENGTH VS EFPY: LINEAR YS, CARBON, CHROME VS EFPY: LINEAR <
YIELD STRENGTH, CARBON VS EFPY: SEMI-LOG (ACCOUNT FOR STRAIN LEVEL)
O CONCLUSIONS RUB TEST DATA OF NORRING ET.AL. SHOW i STRONG CORRELATION OF SCC LIFE IN HIGH 4 TEMPERATURE WATER WITH YIELD STRENGTH l
BkWS }
j
DUiG FOiGR TIME TO CRACKING VERSUS YlELD STRENGTH f 3/4" RUB SPECIMENS,365 C WATER 12000 1
r 10000 --
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E000 -
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s a 1 g 6000 - \
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p SEMILOG FIT \
4000 -
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2000 -
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0 , l l l l , l l 35 40 45 50 55 60 65 70 75 YlELD STRENGTH, KSI
~
BWNS
DUiG POhER STRENGTH FACTOR VERSUS YlELD STRENGTH ,
FROM 3/4" RUB DATA,365 C WATER 10
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g __
8 --
7 -
LINEAR FIT, INTERCEPT ADJUSTED e 6 -
o A G '
$ xN 55 -- I E
e 5 4 -,-
3 -
SEMILOG FIT, SCALE NORMAllZED j 2 -
1 -- SEMILOG FIT, STRESSES IN SLEEVE JOINTS INCLUDED l l 0 ,
, l l l
55 60 65 70 75 50 YlELD STRENGTH. KSI BWNS
DTTAE POhTR STRESS STRAIN HISTORY IN A HEAT TREATED SLEEVE JOINT 75* F g SPRING BACK YIELDING g AT 1300
- F M
TIME DEPENDENT RELAXATION AT 1300
- F STRAIN QUALIFICATION AND SERVICE PERFOMRANCE SHOW STRESS RELIEF TO BE MORE EFFECTIVE FOR LOWER STRENGTH SLEEVE JOINTS
- 4 4
BWNS
i DLTE POiGR CARBON FACTOR VERSUS % CARBON 2.5 1
LINEAR FIT 2 -
F
- 1. 5 - 4 5
o z
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U 1 - SEMILOG FIT 0.5 -
o . . . . . .
0 0.01 0.02 0.03 0.04 0.05 0.0S :
% CARBON -
EliNS
- ~.
DUAT POhTR s
LIFE FACTOR CONCLUSIONS -
- STRENGTH FACTOR INDICATES PWSCC LIFE RELATIVE TO A MATERIAL WITH A YIELD ,
STRENGTH EQUAL TO THAT OF 39.72
(>72. 5 ksi)
- CARBON FACTOR INDICATES AN INCREASE IN PWSCC LIFE BY ABOUT A FACTOR OF 2 AS %C RANGES FROM 0.05% TO 0.02%
- LIFE FACTOR = 1.19 x STRENGTH FACTOR i x CARBON FACTOR
- LIFE FACTOR = RELATIVE RANK OF SLEEVE JOINT COMPARED TO 39-72
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DUIG POhTR CONSIDERATION OF PULLED TUBE !
YIELD STRENGTH VS CMTR VALUE t
- MEASURED YIELD STRENGTH OF PULLED TUBES IS AN AVERAGE OF 1.066 TIMES CMTR VALUE 7
- A BOUNDING VALUE OF 1.13 TIMES CMTR YIELD STRENGTH IS NOT CONSISTENT WITH PWSCC i PERFORMANCE TO DATE i
t i
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BHNS
i DUKE' POhTR ;
l LIFE FACTOR PREDICTION SENSITIVITIES VERSUS PERFORMARCE TO DATE )
f ACTUAL SEMILOG YIELD 6 FAILURES 1 .
LINEAR CARBON ,
9 SEMILOG YIELD 6 FAILURES SEMILOG CARBON l 4
SEMILOG YIELD
- 1.066 7 FAILURES LINEAR CARBON ,
SEMILOG YIELD
- 1.066 17 FAILURES SEMILOG CARBON i SEMILOG YIELD
- 1.13 75 FAILURES LINEAR CARBON '
L SEMILOG YIELD
- 1.13 113 FAILURES SEMILOG CARBON
+
- BWNS l
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-1 REPAIR CRITERIA 1 t
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CORRECTIVE ACTION l
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DUKE POWER .
MNS REPAIR CRITERION l
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- SLEEVES THAT WERE DRIPPING q j
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- SLEEVED TUBES THAT WERE NOT AXIALLY /!
RESTRAINED 1 i
- SLEEVED TUBES OF SAME HEAT AS 39-72 i 1
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- SLEEVED TUBES WITH PREDICTED LIFE < 8.3 d EFPY's j
- 98 SLEEVED TUBES PLUGGED l
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- BHNS I
i DUKE POWER McGUIRE UNIT 1 MINIMUM REMAINING '
LIFE FACTOR i i
S/G AT EOC-9 YIELD YIELD -
A 3.06 8.3 4.5 B 3.06 8.3 4.5 C 3.06 9.3 5.0 l D 3.06 9.3 5.0 i
3 F
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i DUIG POhER PLANNED CORRECTIVE ACTIONS
- QUALIFY HIGHER STRESS RELIEF TEMPERATURE
- PERFORM CORROSION TEST TO VERIFY
- IMPROVE NDE DETECTION t
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UNIT 1 PLANT RESPONSE !
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l DUiG POhTR UNIT 1 PLANT RESPONSE l McGUIRE TECHNICAL SPECIFICATION 3.4.6.2 LIMITS REGARDING S/G TUBE LEAKAGE .i i
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J LIMITING CONDITION FOR OPERATION .
b
.i 1 GPM TOTAL PRIMARY-TO-SECONDARY LEAKAGE THROUGH ALL STEAM GENERATORS !
AND l t
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500 GALLONS PER DAY (0. 3472 GPM) THROUGH ANY f ONE STEAM GENERATOR !
.l ACTION l 1
REDUCE THE LEAKAGE RATE TO WITHIN LIMITS '
WITHIN 4 HOURS OR BE IN AT LEAST HOT STANDBY WITHIN THE NEXT 6 HOURS AND IN COLD SHUTDOWN WITHIN THE FOLLOWING 30 HOURS.
BWNS
DU1B POhTR l
UNIT 1 PLANT RESPONSE McGUIRE ADMINISTRATIVE LIMITS REGARDING S/G TUBE LEAKAGE f
Ah M CIATOR RESPONSE PROCEDURE FOR N-16 SODIUM '
IODIDE DETECTORS ON EACH MAIN STEAM LINE
- SETPOINT APPROXIMATELY 50 GPD (.03472 GPM) ;
- IMMEDIATE ACTION - REQUEST CHEMISTRY TO VERIFY LEAK RATE. ,
- IF LEAKRATE IS GREATER THAN 50 GPD (.03472 i GPM) FROM ANY ONE S/G, THEN ENSURE UNIT IS IN MODE 3 WITHIN 12 HOURS.
- IF LEAKRATE INCREASES BY 50 GPD ( . 03472 GPM)
IN ANY ONE S/G IN LESS THAN 1 HOUR, THEN ENSURE UNIT IN MODE 3 WITHIN 6 HOURS.
BNNS
~
DUKE POhTR UNIT 1 PLANT RESPONSE LESSONS LEARNED FROM JANUARY 1992 UNIT 1 STEAM GENERATOR TUBE LEAK
- MOVED EMF-33 (CONDENSER AIR STEAM EJECTOR MONITOR) SAMPLE POINT TO MORE ACCURATELY REFLECT OFF GAS ACTIVITY.
- ESTABLISHED ADMINISTRATIVE LIMITS REQUIRING SHUTDOWN WITH STEAM GENERATOR TUBE LEAKAGE
> 50 GPD FROM ANY ONE STEAM GENERATOR AND CHANGED PROCEDURES ACCORDINGLY.
l BWNS
DUIG POTGR UNIT 1 PLANT RESPONSE "A" S/G TUBE LEAK SEQUENCE OF EVENTS
'DATE TIME EVENT 07/06/93 CHEMISTRY ANALYSIS INDICATES THROUGH APPROXIIGTELY 15 GPD PRIMARY 08/21/93 TO SECONDARY LEAKAGE.
ANALYSIS PERFORMED ONCE PER '
WEEK IN ACCORDANCE WITH CHEMISTRY PROGRAM.
P 08/21/93 2249 - 1DE-71 (A S/G N16 MONITOR) 2250 ALARM OCCURRED FIRST. IT WAS CLOSELY FOLLOWED BY OTHER N16 MONITORS IN THIS ORDER:
1DE-7 4 (D S/G N16 MONITOR) ,
IDE-72 (B S/G N16 MONITOR) AND l 1 EMF-73 (C S/G N16 MONITOR) .
APPROXIMATELY l MINUTE LATER 1 DE-33 (CONDENSER AIR STEAM EJECTOR MONITOR) ALARMED.
2250 CONTROL ROOM PERSONNEL CONTACTED CHD4ISTRY TO VERIFY :
PRIMARY TO SECONDARY LEAKRATES l AS REQUIRED BY PROCEDURE. l 1
2250 CONTROL ROOM PERSONNEL CHECKED FOR OTHER SYMPTOMS OF A PRIMARY TO SECONDARY LEAK AND REFERRED i TO AP/10, " REACTOR COOLANT !
SYSTD4 LEAKAGE WITHIN {
CAPABILITY OF BOTH CENTRIFUGAL i CHARGING PUMPS".
2333 BEGAN A CALCULATION OF REACTOR COOLANT SYSTEM LEAK RATE.
BHNS
l DUKE POWER DATE TIME EVENT 08/22/93 0033 REACTOR COOLANT SYSTEM LEAK RATE CALCULATION COMPLETE.
RESULTS: UNIDENTIFIED LEAKAGE
= .087 GPM.
0036 NOTIFIED BY CHEMISTRY THAT TOTAL S/G TUBE LEAKAGE IS 200 GPD (0.139 GPM). ,
0036 BASED ON CONFIRMATION BY CHEMISTRY, ENTERED AP/10 AND BEGAN SHUTDOWN TO MODE 3 WITHIN 6 HOURS.
0128 NOTIFIED BY CHEMISTRY THAT "A" S/G IS THE LOCATION OF THE LEAK.
0510 UNIT OFF LINE. BEGAN EMERGENCY BORATION PER AP/10.
0521 ENTERED MODE 3.
0635 BEGAN COOLDOWN AND DEPRESSURIZATION TO EQUALIZE PRIMARY PRESSURE AND "A" S/G SECONDARY PRESSURE. i l
0745 PRIMARY PRESSURE AND "A" S/G SECONDARY PRESSURE EQUALIZED.
e !
BHNS
DUKE POWER _
DATE TIME EVENT 08/22/93 1230 COMPLETED AP/10 AND ENTERED EP/4.3, "SG TUBE RUPTURE i COOLDOWN USING BLOWDOWN".
CONCURRENTLY RAN UNIT SHUTDOWN PROCEDURE. ;
1330 ENTERED MODE 4.
1815 PLACED RESIDUAL HEAT REMOVAL SYSTEM IN SERVICE.
08/23/93 0148 ENTERED MODE 5.
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BWNS
. _ . _ . . - _ _ _ . ~ . . _ .
,, l DU1B ^ POWER .
i UNIT 1 PLANT RESPONSE l CHEMISTRY PRIMARY TO SECONDARY j LEAKRATE CALCULATION FREQUENCY r IF TOTAL LEAKRATE THEN ,
i l
1
< 25 GPD CALCULATE TOTAL LEAKRATE -l WEEKLY ~!
1 i
i 25 GPD < LEAKRATE < 50 GPD CALCULATE TOTAL LEAKRATE f DAILY j i
l t
> 50 GPD CALCULATE TOTAL LEAKRATE BUT < 50 GPD FOR ANY l S/G ONCE PER 12 HOURS o h
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BWNS !
i t
.. .o i DUKE POWER E
CONCLUSIONS:
- ROOT CAUSE INVESTIGATION INTO UNIT 1 S/G TUBE LEAKS COMPLETE
- REPAIR CRITERIA IDENTIFIED AND REPAIRS COMPLETED ON UNIT 1
- REPAIR PLAN IN PLACE FOR UNIT 2 :
- REPAIR CRITERIA SHOULD ENSURE RELIABLE S/G OPERATION UNTIL THE NEXT REFUELING OUTAGES i
- IMPLEMENTED IMPROVEMENTS WERE BENEFICIAL N-16 SODIUM IODIDE DETECTORS j RELOCATED CONDENSER AIR STEAM EJECTOR !
MONITORS LOWER ADMINISTRATIVE LIMITS FOR S/G TUBE LEAKAGE BWNS
s
- Meetina Summary. Memoranda for Trio Reoorts or Site Visits i
Enclosure 1 and 2 Docket File NRC & Local PDRs PD# 23 Reading V. Nerses E. Merschoff RII Enclosure 1 T. Murley/F. Miraglia 12-G-18 .
J. Partlow 12-G-18' l S. Varga G. Lainas R. Hermann K. Jabbour T. Reed 14-B-20 V. Economos RII M. Markley 10-A-19 K. Karwoski 7-D-4 H. Conrad 7-D-4 J. Strosnider 7-D-4 E. Murphy 7-D-4 J. Wiggins 7-D-26 W. Russell 12-G-18 R. Jones 8-E-23 L. Berry OGC E. Jordan ACRS (10)
L. Plisco, EDO Region 11 cc: Licensee & Service List I