ML19224C588
| ML19224C588 | |
| Person / Time | |
|---|---|
| Site: | Brunswick  |
| Issue date: | 05/21/1979 |
| From: | Hannon J Office of Nuclear Reactor Regulation |
| To: | Ippolito T Office of Nuclear Reactor Regulation |
| References | |
| NUDOCS 7907030051 | |
| Download: ML19224C588 (12) | |
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UNITED STATES
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%...<. 4 y May 21, 1979 Docket flos. 50-324 and 50-325 ME!!ORAflDUM FOR:
Thomas A. Ippolito, Chief, ORB #3, DCR FROM:
John fl. Hannon, Project Managar, ORB #3, D0R
SUBJECT:
MEETIriG SUDiARY A meeting was held with representatives from Carolina Power and Light Company (CP&m), General Electric (GE), and United Engineers and Constructors (UE&C) in Bethesda, flaryland on May 16, 1979.
The purpose of the meeting was to dis-cuss the results of seismic piping stress reanalysis done for Brunswick Steam Electric Plant (BSEP) Units 1 and 2 in connection with IE Bulletin 79-07.
A list of meeting attendees and a ~ copy of the CP&L slide presentation are attached.
CP&L indicated that there were approx.imately 350 concrete expansion anchors at BSEP, with approximately 165 associated with 2 1/2" or larger size lines.
CP&L stated that approximately 35% of the piping was 21/2" or greater in size.
Ali but two of the baseplates had been tested on lines >21/2", with less than a 55 failure rate. Analysis of the base plates was iii progress as required by IE Bulletin 79-02.
CP&L indicated that all safety systems at BSEP had been analyzed using algebraic summation techniques. A total of 206 isometric piping problems had been identified that were used by UESC in the analyses.
Of these 206, 10 piping problems had been reanclyzed by UE&C using c modified version of ADL PIPE (ADL PIPE II).
Code verification was in progress for ADL PIPE II.
Five of six benchmark programs had been completed with no deviations identified.
The original pipe stress analysis performed by GE for piping in their scope of supply utilized DAPS.
This code was reporteoly used on 3 domestic reactors (Brunswick Units 1 and 2 and Pilgrin) and two foreign reactors.
GE had reanaly7.ed the BSEP piping in their scope of supply using PISYS.
Code verification was also in progress for PISYS.
UE&C and GE both thought the new codes had been inout with as-built data, and thus would represent actual plant conditions.
CP&L stated that to their Know-ledge the piping drawings used to input the stress analyses represer.ted actual plant layouts.
CP&L indicated that for example, there were roughly 250 enubbers it side each drywell, and before system turnover, each line was verified by QA/QC checks to be accurately represented on as-built drawings.
272 M 3 7907osooS/3 i
T. A. Ippolito At the conclusion of the meeting the fiRC indicatec that sufficient information to make an informed judgement en the status of BSEP 1 and 2 had not been pro-vided.
The staff stated that toe following infomation should be providei by Monday, May 21, E79 at a meeting to be held at 1 P.M. in the same location.
- A narrative discussion explaining why the 10 runs that have been completed by UE&C should be considered representative of the entire population of 206.
- A breakdown of the 206 piping problems by size and system.
- A listing of the seismic strcss contribution corrpared with allowable stresses, (both original and reanalyzed) for as many of the 206 piping problems as possible.
- A schedule for completing any remaining piping problems.
- A plot of SSE/0DE floor response spectra within the frequency range of intere;t.
- A discussion of pipe support design relative to the new loading calculations.
- A discussion of the benefits of a 2D analysis vs. 3D relative to the algebraic summation questior,.
- A PI5YS lir. ting.
- A confirmatiao that changes in peak stress locations as a result of the reanalyses will have no advtrse effect on the high energy pipe break criteria.
The flRC stated that in the meantime, ISE would perform a sampling inspection to verify as-built drawings cere utilized in the reanalysis, and ilRR wculd continue code ver:fication efforts for ADL PIPE II and PISYS.
The flRC will attempt to reach an informed decision on the continued operation of BSEP 1 and 2 at the conclusion of the Manday meeting.
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' John f[!Hannon, Project Manager Operating Reactors Branch #3 Division of Operating Reactors
Enclosure:
1.
Attendsnce list 2.
Slides 272 M4 GPUNSWICK NEETING May 16, 1979 GE R. Gridley W. Sinba J. Ki l ty L. Zull C. Paone J. Thompson BOST0ft EDISON CO.
C. Ondash UE&C H. Kreider B. Huselton G. Risamonti CP&L D. Waters W. Kincaid B. Furr P. Howe C. Bohanan D. Bensinger NRC J. Hannon W. Russell H. Wong M. Hartzmar J. Glynn A. Igne V. Rooney A. Lee K. Wichman K. Herring R. LaGrange V. floonan A. Connor D. Eisenhut 272 31-D CAROLINA POWER S LIGHT COMPAllY BRUtiSWICK STEAM ELECTRIC PLAtlT NRC MEETING MAY 16, 1979 AGEllDA IrlTRODUCTI0il HOWE OBJECTIVES WATEPS PIPIllG SYSTEM IE BULLETINS WATERS RECIRC LIllE AtlALYSIS - GE THOMPS001 TEN SYSTEMS ANALYSIS - UE8C KRIEDER FUTURE PROGRAM WATERS C0ilCLUSIO!1S v"TERS/ HOWE 272 316
OBJECTIVES:
PRESEilT DETAIL OF REAtlALYSES OF PIPIflG COMPLETED TO DATE SHOW ACCEPTABILITY OF AtlALYTICAL RESULTS --
COMPARED TO ALLOWABLES DESCRIBE PROGRAM FOR FUTURE PIPIflG AilALYSES SHOW THAT C0ilTIflUED OPERATI0il 0F BSEP UtilTS 1 AND 2 DURIi1G REAilALYSIS PROGRAM IS WARRAilTED 272 317
PIPING _ SlSJEELLE_1UlJ_ETINS 79-02 C0t1 CRETE EXPANSI0li AI1CHORS TESTIf1G COMPLETED - UllITS 1 t.no 2 ANALYSIS OF BASE PLATES III PROGRESS SCHEDULE COMPLETION IN COMPLIANCE WITH BULLETI!1 FIRST OF JULY TO DATE, fl0 CONCERilS DISCOVERED 79- 014 VELAtl VALVES CP&L RESPONSE DATED APRIL 30, 1979
[10 3" OR GREATER VELAtt VAL"ES INSTALLED AT BSEP (CATEGORY D 272 318
79-07 SEISMIC PIPE STRESS CP8L RESP 0ilSE DATED APRIL 20 1979 ALGEBRAIC SUMMATIONS USED IN ORIGINAL SEISMIC DESIGN CALCULATIONS REAtlALYSIS OF SOME PIPIrlG Ill MAJOR SAFELY SYSTEi1S REANALYSIS RESULTS WITillfi CODE ALLOWABLES COMMITTED TO REAilALYZE ALL SAFETY SYSTEM PiPlilG WITHIfl 13 WEEKS OF flRC ACCEPTANCE OF CRITERIA CONCLUDED THAT RESULTS OF LIMITEL REANALYSES GIVES SUFFICIENT ASSURANCE THAT CONTIflUED OPERATI0tl WOULD NOT
~
Et1 DANGER PUBLIC HEALTH AND SAFETY 272 319
CD N
A CP&L DRUNSWICR UNITS 1 AND 2 N
PIPE STRESS SU.'OtARY*
PSI iso.
U
_ nset Condition Emergency Condition Line ID Original New Allowable Ori ginal New Allowable Main Steam MS-ISB 8,753 8,711 18,000 10,724 10,640 27,000 Safety / Relief Valve SRVL-121 16,484 16,320 18,000 22,237 21,910 27,000 Safety / Relief Valve SRVL-122 14,933 17,763 18,000 18,778 24,439 27,000 Safety / Relief Valve SRVL-237 13,799 15,728 18,000 19,170 23,028 27,000 Safety / Relief Valve SRVL-125 17,596 l'.,232 18,000 24,270 23,002 27,000 Feedwater FW-16 11,797 13,330 18,000 18,007 20,028 27,000 Residual lleat Removal RIIR-6 12,615 9,234 18,000 19,406 12,644 27,000 Core Spray CS-24 11,914 10,621 18,000 16,952 14;366 27,000 High Pressure Cooling Injection IIPCI S-17 8,977 9,128 18,000 12,200 12,502 27,000 liigh Pressure Cooling Injection HPCIS-510 8,007 8,051 18,000 12,004 12,092 27,000
- S t re s.;e s shown are maximum values of combined loading conditions.
CAROLII;A PC'JER & LIGHT COMPA!;Y BRC;S'JICK STEAM ELECTRIC PLA!!T PIPE STRESS A!;ALYSIS GE!;ERAL ELECTRIC /J;ALYSIS Stress Ratio
- De sc rip t :i;on lio.
DAPS PISYS Loop A Discharge ;ozzle Safe End A18 0.83 0.90 Loop A Discharge !;ozzle Safe End A17 0.70 0.75 RHR Suction Tee Branch S10E 0.67 0.72 Calculated Stress
- Stress Ratio = Allowable Stress i
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272 321
EU.llEE PROGRAMS.
Ill PROGRESS ASSUMED CRITERIA ACCEPTABLE T0 flRC FOLLOWIilr LItiES TO BE REAi!ALYZED FIRST 2
HPCI STEAM SUPPLY TO TURBlilE RC1C
^ TEAM SUPPLY TO TURBINE RHR PUMP SUCTION C0tlTAli1MEi1T SPRAY HEAT EXCHANGER SUPPLY AIID DISCHARGE HEAR SPRAY LINE FEEDWATER (SECOND LINE)
FSiAINING MAlti fTEAM LIllES (INSIDE CONTAli1 MENT)
PRIORITY CRITERI A FOR REMAINIilG LIi1ES INTERIM REPORTS T0 ilRC SlAFF NOTIF! CATI 0il 0F i1RC WITHIll 24 HOURS IF AtlY STRES2 Ii1 SAFETY SYSTEM EXCEEDS ALLOWABLE 327-
REANALYSIS PRIORITY CRITERIA The following is the criteria to be used to establish the priority for the analyses of the remaining lines:
1.
Other pressure boundary lines 2b" and larger.
2.
Other core standby cooling system lines 2h" and larger.
3.
Other RCIC lines 2 and larger.
Service water lines 2 and larger.
5.
Pressure boundary, CSCS, RCIC lines 2
and smaller.
6.
Other support systems (standby gas treatment, diesel generator fuel oil and cooling water, fuel pool cooling line to RHR, containment atmosphere control system, noninterruptible air).
272 32[LJ
C0ilCLUELQIE fi0 SIGilIFICAilT PIPIT!G PROBLE.'iS REAtlALYSIS Oil SCHEDULE COMPLETE BY MID-AUGUST EARLY RESULTS SHOW MARGIll TO CODE ALLOWABLES
[10 REAS0!1 TO EXPECT Ally DIFFEREliT C0iiCLUS10ilS FOR OTHER LlilES REAilALYSIS PROGRAM AtlD SCHEDULE IS BElilG C0tlDUCTED EXPEDITIOUSLY WITHOUT UilDUE RISK TO PUBLIC HEALTH AilD SAFETY BSEP IS SAFE FOR C0ilTIllUED OPERATIO:1 272 324