ML20211L371
ML20211L371 | |
Person / Time | |
---|---|
Site: | Brunswick |
Issue date: | 05/10/1999 |
From: | Gore P, Wilton W CAROLINA POWER & LIGHT CO. |
To: | |
Shared Package | |
ML20211L365 | List: |
References | |
ESR-98-00333, ESR-98-00333-R00, NUDOCS 9909080226 | |
Download: ML20211L371 (30) | |
Text
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, ENCLOSURE 2 BRUNSWICK STEAM ELECTRIC PLANT, UNIT NO. 2 DOCKET NO. 50-324/ LICENSE NO. DPR-62 FEEDWATER SPARGER AND NO771E EXAMINATION RESULTS Engineerine Service Request 98-00333.
" Unit 2 Feedwater Sparger Evaluation Based On B214R1 IVVI Examination Results"
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l 9909080226 990901 PDR ADOCK 05000324 p PM
Page 1 of _
ENGINEERING SERVICE REQUEST j Form 1 ESR # - g800333 Rev # -o WR/JO # Other Documento (CR, OEF. etc.)
Plant / Unit BNP 2 1005 B21,B11 NUCLEAR BOILER (INC.RX VESSEL &
o Affected Title Originator / Phone l Unit 2 Invessel Feedwater Sparger Evaluation GORE, PHILLIP S /850-2318 Plant Customers (Print Name, Sign, Date) Engineering / Plant Programe (Print Name, Sign, Date) i Reviews (Print Name, Sign, Date)
Engineering Review [arryhnia 5///99 a oin., Reviews Rouireo o 'R M 6 cn.o Engineertrig Disciplines to) f Plant / System b.kk'(Print
.o b act.Name, Si '
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Response Type ENG EVAL ESR N/A M N 88 Team D Non-Q Due Date 05-15 99 APPROVALS le e 10CFR 50.59 Safety Review required per
- NAS Before Approval / Implementation (pient speelAc : _ ' ;)?
- NAS Before Closeout @ Yes @ Selety Screen ONLY
- PNSC Before Approval / Implementation gg o0 ";'*" '",'a***"*"
e,s,e o wA <Eneneerin wone > r Roopensible Engineer PHILLIP S GORE . C"4-- 8f8!9h ame,enomio mene.or m Neme.Sw oe ) (>J15LWu.m AJrR_W4w 5/,.Ie .
Plant General teenager (Print Name, Sign, Dete)
Pmcodure: Form EGR4MGC40051-9 DCM01e2a 07/08/98
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Form 1 ENGINEERING SERVICE REQUEST l
ESR # '
Rev # ) Title
-9800333 0 Unit 2 invessel Feedwater Sparger Evaluation Request:
Evaluate the results of the Unit 2 Feedwater sparger inspections to be performed during the Unit 2 B214R1 outage. This evaluation will be required to support the startup of Unit 2 following completion of the outage.
Response
The BNP-2 Feedwater spargers are " acceptable as is" for Operating Cycle 14.
Crack growth experienced during Cycle 13 was minimal and, in most cases, unobservable. The postulated crack lengths at the end of Cycle 14 will not reduce the structural margins below allowable values. Furthermore, the probability and consequences of loose parts have not changed and have been fully considered by previous analyses. Therefore, the condition of the Feedwater spargers does not impose any restrictions to BNP-2 operation during the next cycle (see attached evaluation).
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Procedure: Form EGR-NGGCN1-9 DCM03 03/28/96 )
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ESR No. 98-00333 Page No. 3 ESR Evaluation Revision No. 0 UNIT 2 FEEDWATER SPARGER EVALUATION BASED ON 8214R1 IVVI EXAMINATION RESULTS LIST OF EFFECTIVE PAGES Page No. Rev.No.
1 0 ;
2 0 3 0
]
4 0 5 0 6 0 7 0 8 0 9 0 10 0 Attachment 1 (19 pages) 0 Sasty Screen (4 pages) 0
ESR No. 98-00333 Page No. 4 ESR Evaluation Revision No. 0 TABLE OF CONTENTS l
ESRCoverpage.................................................................................................................1 List of Effective Pages........ .. ............ . ... ....................................................................3 Ta ble of Co n ten ts . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
1.0 Problem identification . .. . . .. ......... .. . .. . .. ... .. . . . . . .. .. .. . . . .... . .. . . .. . . . .. . ... . .. .. ... .. .. . . .. ...... . . ...... .. ...... 5 2.0 E S R Design Specification ... . . . .. ... . ..... .... ... ... . ... . .. . . ... . .. ... . . . . . . . . . .. . .. .. . ...... .. . .. .. ...... ...... .. . ... . 5 3.0 Evaluation..........................................................................................................................5 1
3.1 Background....................................................................................................................5 1 3.2 B ru nswic k U n it 2 Ex perience. . . . . ... . .. . .... .. . . .. ... ... ........... .. . .. .. . ... . .... .. . . . . . .. .. . . ... .. .. ... . .. .. .. .. . . 6 l
l 3.2.1 B210 R 1 Inspection Results..... .... . ................ ..... ... ...... ................. ....................... 6 ;
3.2.2 B21 1 R 1 Inspection Results............................................................. . . .... ......... ... . 6 3.2.3 B212 R 1 Inspection Results........ .... ......... ......................... ................ .. ..... . ....... .. 7 3.2.4 B213 R 1 I n spection R e s u lts. ... . .. . . . . . .. . . ... . . .. . .. . . . ... . ...... . .... ... .. .. . . .... .. .. . . .. .. ...... .. ....... . . 7 3.2.5 B214R1 Inspection Results (Current Outage)........................................................... 7 3.3 Previ o u s A n a ly ses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . .. . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. . . . . . . . . . .. .. . . . . 7 3.3.1 Leakage Analysis ... .. ... . . .... .... .. .. . . .... ... ... .... . .... ... ..... .. .. . . .. .. ............. .. .. . .... .. .... ... . .... . . 7 3.3.2 Structu ral Analysis... .. ... . .. . ...... . .. . .... ... .... ... ....... ..... . ....... . . ..... .... ... ... .. .. .... .. . ............... 8 3.3.3 Lost Pa rts Analysis.. . . . . .. .. .. . . . .. . . ... ... . . . .... .. ... ......... ... . ... . . . .. .. .... ... ....... ... .. .... ... ... .. .. ........ 8 3.4 Disposition of As-Found Condition ........... ........................... ............................ ........... 9 3.4.1 Circu mf erential Weld s. . . . ... .... . . .. .... .. . . . ... ......... .. .. . . ....... ....... . .... . .......... .......... ... ...... . . 9 3.4.2FlowHoles..............................................................................................................9 3.4. 3 Con cl u sion s .. . .. . . . . . . . . . . . . . .. . . . . . . . . . . . . . . .. . . .. . . .. . . . .... . .. .. . . .. . .. . . . . . . . .. . . . . . . . . . .. . . . . . . . .. . . . .. .. . . . .
3.5 Quality Class Determination................... ...... ................... ......................................... ........ 9
4.0 REFERENCES
.....................................................................................................................10 Attachment 1, Excerpt From Completed PT 90.1, Examination Checklist For Brunswick Unit 1 R14 IVVI Spring 1999 (19 pages)
Safety Analysis
l ESR No. 98-00333 Page No. 5 l ESR Evaluation Revision No. O I l
1.0 Problem identification
. This ESR Evaluation is required as part of CP&L's commitment to inspect Feedwater l Spargers in accc. dance with NUREG 0619 [4.2] and Generic Letter 81-11 [4.3]. As such, this evaluation accomplishes the following:
- 1) Documents the in-Vessel Visual Inspections (IVVI) performed on Unit 2 Feedwater Spargers during RFO B214R1.
- 2) Evaluates the current IVVI data relative to previous inspection results and analyses.-
- 3) Provides justification to use the Feedwater Spargers for another operating cycle in the as-found condition. (i.e. concludes that BNP-2 can safely operate in the present condition during the upcoming fuel cycle without any operational changes or restrictions).
2.0 ESR Desian Specification 2.1 Each of four feedwater spargers at BNP-2 has thirty-six (36) side drilled flow holes and three (3) circumferential butt welds. Each feedwater sparger tee has a horizontal welded seam which has four (4) flow holes located in it. Each sparger arm section is made from seamless bent pipe and contains sixteen (16) flow holes.
Two sparger arms and a thermal sleeve are welded to each tee with circumferential butt welds. The side drilled flow holes are of various sizes for balancing the flow distribution around the circumference of the reactor vessel. This flow distribution is important in order to maintain a uniform power distribution within ,
the reactor core.- 1 2.2 Each feedwater sparger is supported by the reactor vessel at three locations. At the center, there is a tee which has a stainless steel thermal sleeve attached to it.
This thermal sleeve has an interference fit connection to the nozzle safe end. The other two connections are at the ends of the sparger where the sparger end ;
brackets are pinned to the reactor vessel fesowater support brackets. The sparger i brackets have slotted holes to allow for thermal movement.
3.0 Fvaluation
3.1 Background
The BNP-2 feedwater spargers have exponenced two distinct types of cracking, as categorized below:
A. Radial Flow Hole Cracks: Radial cracks in random directions which appear as
" sunburst"_ pattoms centered around sparger flow holes.
The root cause of the cracks around the flow holes is believed to be high-cycle thermal fatigue. Crack extension is thought to be govemed primarily by intergranular stress corrosion cracking (IGSCC), possibly exacerbated by the creviced ,
environment created by the crack surfaces. Flow hole cracks were first observed in 1982 by visual inspection. Detailed mapping and measurements were
ESR No. 98-00333 '
Page No. 6 ESR Evaluation Revision No. 0 accomplished by liquid penetrant (LP) examination of selected flow holes during Refueling Outage (RFO) B208R1 in 1988 to create a baseline for future reference.
LP exams were performed again during the 1989/1990 Refueling Outage and indicated no significant changes.
B.
Heat Affected Zone (HAZ) Cracks: Cracks in the heat affected zone (HAZ) of the longitudinal welds in the sparger tee and in the HAZ of the circumferential welds attaching the sparger arms to the tee.
The root cause of the cracks in the weld HAZ regions is believed to be high cycle thermal fatigue, with crack extension primarily driven by IGSCC.
3.2 Brunswick Unit 2 Experience 3.2.1 B210R1 Inspection Results The feedwater spargers were visually inspected (VT-3) prior to the liquid penetrant examination for gross cracking. This examination resulted in a total of 55 of 144 flow holes being inspected by the liquid penetrant method. The flow holes had linear indications.
The twelve (12) Feedwater tee box circumferential welds were first LP examined to determine cracking extending from the flow holes and to determine the OD lengths.
Five (5) of the eight (8) tee box to sparger arm circumferential welds were ultrasonically examined to determine ID lengths. Due to the configuration of the flow holes in relation to the cracking, only two (2) of the circumferential weld cracks were ID sized. The largest circumferential weld indication was determined to be two inches (2") on the right side of the tee box of the 135 sparger (~14(f). This crack did not show significant growth from the LP examination performed during B209R1.
The thermal sleeve to sparger circumferential welds were deemed acceptable.
3.2.2 B211R1 Inspection Results The feedwater spargers were visually examined using a high resolution, remote underwater camera. The spargers were examined for gross defects and missing fragments. All of the flow holes were inspected for cracking and the results were recorded for each hole. The circumferential welds were inspected to the extent possible with the remote camera. The video tapes were compared to the photographs of the LP examination performed during the previous outage.
The flow holes showed no significant changes from the previous examinations. The flow holes continued to show slow crack growth though some new cracking was observed around the flow holes. However, the new cracks were not as long as the existing cracks. Four (4) flow hole cracks were sized during this examination.
The circumferential weld cracks vtere in the same condition as those sized during B210RI. There was no appreciable change in crack length or number of cracks since the previous inspection. B211 R1 inspection results were evaluated in EER 94-0182.
ESR No. 98-00333 Page No. "
ESR Evaluation Revision No. 0 3.2.3 B212R1 Inspection Results The feedwater spargers were visually examined (VT-1NT-3) using a high resolution, remote underwater camera. The spargers were examined for gross defects and missing fragments. All flow holes were inspected for cracking and documented on video tape. Four (4) flow holes were selected for crack growth measurement (the same holes selected in B211 R1). The circumferential welds were inspected to the extent possible with the remote camera. 8212R1 inspection results were evaluated in ESR 96-00155.
During the VT-3 examination of the sparger pipe, no relevant indications were found though it was noted that there were relevant indications around the flow holes which were identified during VT-1 examinations. Also, no loose parts were discovered.
The circumferential weld cracks were in the same condition as those sized during 8210R1. There was no appreciable change in crack length or number of cracks since the previous inspection.
3.2.4 B213R1 Inspection Results The feedwater spargers were visually examined (VT-1NT-3) using a high resolution, remote underwater camera. The spargers were examined for gross defects and missing fragments. All flow holes were inspected for cracking. The four (4) flow holes previously selected for crack growth measurement in B211R1 and B212R1 were measured again during this outage. The circumferential welds were inspected to the extent possible with the remote camera. The inspections concluded that there were no significant changes from the previous inspection results. Additionally, a VT-3 examination of the feedwater spargers confirmed the structural integrity of the spargers, i.e., no missing parts. The B213R1 inspection results were evaluated in ESR 97-00033.
3.2.5 B214R1 Inspection Results (Current Outage)
During the current refueling outage (8214R1), the feedwater spargers were visually examined (VT-1NT-3) using a high resolution, remote underwater camera. The spargers were examined for gross defects and missing fragments. The four (4) flow holes selected for crack growth measurement in previous outages (hole #4 of the 45* degree sparger, hole #6 of the 135* degree sparger, hole #26 of the 225*
degree sparger, and hole #28 of the 315 degree sparger) were measured again during this outage. The circumferential welds were inspected to the extent possible with the remote camera. The inspections concluded that there was no appreciable growth in the existing cracks and no new cracks were noted. Additionally, the VT-3 examination of the feedwater spargers confirmed the structuralintegrity of the spargers, i.e., no missing parts.
3.3 Previous Analyses
~
3.3.1 Leakage Analysis Leakage has been addressed in GE-NE-523-112-1191 [4.6) and RDE 42-1289 [4.7].
Two (2) types of leakage are addressed. The first case considered flow through a
ESR No. 98-00333 Pago No. 8 ESR Evaluation Revision No. 0 lost segment between two adjacent flow holes. An additional flow area created by a lost segment in the 315 sparger tee section was also considered for this case.
This will cause more flow to exit at the tee region. This scenario was evaluated and found to be in compliance with the design requirement to maintain the core inlet enthaipy uniform withiniO.2% of the average enthalpy. The second case is the scenario involving full circumferential cracking of a header pipe which is not a probable near term event. In this case, flow distribution will be significantly affected and would be detected by the core instrumentation. There is also the potential for flow impinging on the reactor pressure vessel (inner blend radius of the feedwater nozzle) which could result in crack initiation. An analysis was performed to predict the consequences of this unlikely event and showed that the maximum expected crack depth, in one 18-month cycle of operation, due to sparger leakage onto the nozzle is 0.9", which is less than the 1.0" crack depth allowed in NUREG-0619 (4.2].
Conservatively updating this value for two 18-month cycles of operation (which bounds a 24 month cycle) yields a value of 0.95" which is still less than the NUREG-0619 allowable depth of 1.0".
3.3.2 StructuralAnalysis The feedwater sparger is not a safety related component. The most likely near term event, due to the observed cracking, is the loss of small fragments of pipe material.
In this case, the structuralintegrity of the feedwater sparger header pipe will not be adversely affected [4.7]. The stresses in the feedwater sparger are primarily produced by hydraulic loads, pressure differential loads and thermal gradients.
Losing a segment of material between the flow holes weakens the cross section; however, this alone will not affect structural integrity. An analysis was also performed to determine the critical crack size for the circumferential tee weld [4.6].
This critical crack size is 14.1" on the outside surface (244 ). The predicted crack growth due to IGSCC could be as large as 3.16" per cycle (4.6], so the allowable inspected flaw size is 10.9" on the outside surface (189 ). The GE analysis assumes an eighteen month operating cycle. Updating these values for a 24 month cycle yields an IGSCC growth of 3.95" and an allowable flaw size of 10.15".
3.3.3 Lost Parts Analysis There are two types of potential lost parts. The first is segments of material from between the flow holes. The second is the complete separation of a sparger arm at the tee box weld. Two sizes of segments from between flow holes were analyzed
[4.7], a 2" x 1" x 0.3" rectangular piece and a 3/8 " x 3/8" x 1/3" triangular piece 0.3" thick. These pieues, which could separate from the sparger, are likely to end up resting on the shroud support shelf. It would also be possible, but unlikely, for small pieces to enter the jet pump or the recirculation suction nozzle. Fragments entering the recirculation piping from the suction nozzle would pass through the recirculation pump and , depending on size, would either get caught in the jet pump inlet mixer nozzle or reach the vessel bottom head. In either case, the lost part would not become a safety concera and no_pignificant damage to other components should occur. Blocking of a jet pump inlet mixer, an unlikely event, would cause a change in the pressure reading on the jet pump instrumentation. BWR plants which have had flow blockages have been able to remove the foreign object with no damage being observed.
ESR No. 98-00333 Page No. 9 ESR Evaluation Revision No. 0 Complete separation of a sparger arm was analyzed in Reference 4.6. It was found that complete separation of the sparger arm at the Tee Box weld would not overstress the bracket connection. Also, such a separation would be detected by the operator, so there is no concern for this scenario.
3.4 Disposition of As-Found Condition 3.4.1 Circumferential Welds There were no significant changes in the observed indications from the previous inspection. No discemible change was noted in the largest previously measured circumferential crack (measured at 2" in length and located on the right side weld of the 135'sparger). There have been no observed changes in this indication for five operating cycles. This 2" indication is still bounded by the analyses discussed in Section 3.4. Reference 4.6 indicates an IGSCC crack growth rate of 3.16"over an 18 month operating cycle. Adjusting this value for a 24 month cycle yields a value of 3.95". Application of this growth rate to the longest observed crack (2") yields a value of 5.95" at the end of the operating cycle, which is well below the previously determined 14.1" allowable flaw size. The current maximum flaw size remains bounded by previous analyses. Even when utilizing this conservative crack growth rate, the longest existing crack will not reach the critical flaw size during the next two (2) operating cycles.
3.4.2 Flow Holes There are no significant changes in observed indications from the previots examinations. Any potential for loose fragments is bounded by previous analyses.
It is acceptable to operate for an additional cycle with the flow hole crack lng found during B214R1.
3 4.3 Condusions The BNP-2 Feedwater spargers are " acceptable as is' for Operating Cycle 14.
Crack growth experienced during Cycle 13 was unobservable. The postulated crack lengths at the end of Cycle 14 will not reduce the stmetural margins below allowable values. Furthermore, the probability and consequences of loose parts have not changed and have been fully considered by previous analyses. Therefore, the condition of the Feedwater spargers does not impose any restiictions to BNP-2 operation during the next cycle.
3.5 Quality Class Determination The feedwater spargem were reclassified as "Non-Q" component by EER 85-0182
[4.1].
. - . . g _ _ _ - _ _ - .
m ESR No. 98-00333 Page No.10 ESR Evaluation : Revision No. 0 4.0 References 4.1 . EER 85-0182, Rev. 0, " Reclassification of Feedwater Spargers from 'O' to 'Non-Q' Status", June 27,1985 4.2 NUREG 0619, ~BWR Feedwater Nozzle and Control Rod Drive Retum Line Nozzle Cracking", November 13,1980
~
4.3 USNRC Generic Letter 81-11, February 20,1981 4.4 - Letter NRC-B96-0043, From: ' D. Trimble (NRC) To: W. Campbell (CPL), Dated January 18,1996,
Subject:
" Approval of Revised Plans for Replacement of Feedwater Sparger, 1 and Deferment of Feedwater Nozzle Examinations - Brunswick Steam Electric Plant, Unit l
2" i l
4.5 EER 94-00182, Rev. O, " Unit 2 Feedwater Sparger Evaluation Following IWI j Examinations,"May 27,1994, Evaluation of Refuel Outage B211R1 Examination Results 4.6 General Electric Company Report No. 9E-NE-523112-1191 (DRF 137-010),*Feedwater Sparger Circumferential for Brunswick r hits 1 and2,' November,1991 4.7 General Electric Company Report No. RDE 42-1289 (DRF B13-10487), Rev.1, l
"Feedwater Sparger Crack Growth Safety Evaluation," February,1990 4.8 Competed OPT-90.1 for the B214R1 Outage "VesselIntemal Component Remote Examinations, April,1999 4.9 ESR 96-00155, U2 Feedwater Sparger B212R1 Inspection Evaluatiort Rev. O. Dated March 3,1996 4.10 Letter from D.B. Drendel (GE) to Rick Ramsey (GE) dated 10/6/97," Brunswick Unit 2 -
Loose Feedwater Sparger Jack Bolt Bearing Bars" 4.11 Brunswick Steam Electnc Plant Updated Final Safety Analysis Report (UFSAR).
- 4.12 ESR 97-00033, " Unit 2 Feedwater Sparger Evaluation Based On B213R1 IWI ,
Examination Results" Rev. O Dated October 11,1997. i
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