ML20033A600

Preliminary Rept of Structural Evaluation of Pilgrim Station Core Spray Sparger Based Upon Results from Oct 1981 Remote Visual Insp

ML20033A600
Person / Time
Site:	Pilgrim
Issue date:	11/17/1981
From:	Cipolla R, Hayward J, Sanders J APTECH ENGINEERING SERVICES
To:
Shared Package
ML20033A598	List: ML20033A597 ML20033A600
References
AES-81-10-83, NUDOCS 8111250611
Download: ML20033A600 (71)

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{{#Wiki_filter:_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ AES-81-10-83 APTECH engineering eervices,Inc ~ esclueeR,~c cOssuL1As1s 795 SAN ANTONIO ROAD. PALO ALTO. CAllFORNI A 94303 (415)853 2863 E I I PRELIMIfiARY REPORT STRUCTURAL EVALUAT10tl 0F THE PILGRIM I STAT 10tl CORE SPRAY SPARGER BASED UP0!4 RESULTS FROM Tile OCTOBER 1981 REMOTE VISUAL INSPECT 10ft I Prepared by: John A. Hayward Russell Cipolla Joseph Sanders Aptech Engineering Services, Inc. 795 San Antonio Road Palo Alto, CA 94303 l Prepared for; Boston Edison Company gj 800 Boylston Street Boston, MA 02199 Dr. Hugh O'Connor Mr. Frank fl. Famulari 8111250611 811117 PDR ADOCK 05000293 P PDR Services in Mecharsical and M etallurgical Engineering. Welding, Corrosion, Fracture Mechanics, Stress Analysis

E { TABLE OF CONTENTS [ 1) Introduction Pg 1 2)

Background

Pg 3 3) Sparger Eva.uation Techniques Pg 6 3.1 Inspection Plan Pg 6 3.2 1980 Reference Indications Pg 6 3.3 Sparger Indication Calibration Pg 7 3.4 Summary of Structural Integrity and Pg 3 Fracture Mechanics Analysis 4) Summary and Conclusions Pg 20 I S) Comparison of Photographs f rom 1980 and Pg 23 1981 Inspections References Pg M _ 1_ a _ _ _ ,~, I l l

_ _ _ _ _ - _ _ _ F L 1.0 INTRCDUCTION { r This report provides a summary of findings and conclusions f rom underwater L television camera inspection of the Pilgrin core spray sparger assetably conducted in October 1981. Visual examination included sparger pipes, junction box weld regions, nozzles, and attachrk.nt welds of all nozzles. ( Present inspection results were compared to areas previously identified as containing possible linear indications based upon a simi1 3r visual { inspection performed in January 1980. Comparisons of results from two inspections were made by exanination of photographs taken after computer { enhancement of selected frames from video tapes of each inspection. Principle subcontractors to Boston Edison Company (BECO) ar.d Pilgrim Station who were involved in the sparger inspection and evaluation, are listed below with designated responsibilities: [ e Mr. Robert Shinkus, Level 3 NDE Technical Consultant from Southwest Research Institute, San Antonio, TX, who was responsible for directing the inspection and interpreting inspection results fron video tapes and computer enhanced video ( tape franes. Mr. Shinkus provided Level 3 NDE interpretation of the 1980 sparger inspection video tapes. e CTS Consulting Personnel Services, Inc, BJldinsville, NY, which was responsible for operation of car. era rig and recording video tape records. e Aptech Engineering Services, Inc., Palo Alto, CA, which was s ( responsible for structural integrity evaluation, f ractu re mechanics analyses and fluid mechanics evaluations. AES f established calibratiori reference indications f rom 1980 video tapes. Aptech Imaging, Inc., Palo Alto, CA, which was responsible for on-site computer enhancet>:ent of areas identified as being suspect. AII had previously provided computer enhanced photographs of suspect areas frnn the 1980 video tapes. I t'I The 1981 sparger inspection results were recorded on 3/4 in. video tapes. The inspection file consists of ten video tape cartridges plus one i additional cartridge containing computer enhanced frames. i i I I !I 1 1il I >I il 4 I .I 4I I I I I

2.0 BACKGROUND

One of the scheduled tasks during the Reload 4 refueling and maintenance outage in January 1980 at the Pilgrim fluclear Power Station was the performance of a visual inspection of the Coic Spray Spargers using i underwater television cameras. This inspection was conducted as part of the 10 year Inst r dce Inspection Program at Pilgrim Station, and also as [ recommended by General Electric in Service afaimation Letter (SIL) 289 Q). Figure 2-1 shows the configuration and details of the core { spray spargers. During the inspection of e core spray spargers, linear indications were observed on the upper and lower sparger headers in the area adjacent to the juncture boxes in the beat affscted zone (HAZ) and remote from the HAZ. The discoverv of.hece indications was reported to the fiuclear Regulatory Commission (T:RC) on February 1, 1980 (2_;, followed by a meeting involving fiRC staff, BECO representatives and GE personnel on February 29, 1980 (3) and March 13, 1980 (4). Those meetings culminated with the submittal of a GE report (5) which documented the technical justification to support a proposed start-up plan and the technical basis used to establish continued structural I integrity of the core spray spargers f or all normal, transient and accident conditions. The report included discussion of the methods and issumptions used in the loss-of-Coolant Accident (LOCA) analysis to I determine the MAPLHGRs, assuaing no credit for core spray heat transfer, and a discussion of the possible consequent < of a potential loose piece from a broken sparger. In January 1981, Aptech Engineering Services Inc. (AES) was requested to perform an independent structural integrity and f racture mechanics evaluation based upon the assumption of linear crack indications established from video tapes from the 1980 inspection. The quality of the 1980 video tapes was generally poor and difficult to interpret due to video noise, camera motion and difficulty in focusing. Aptech Imaging, Inc., an affiliate of AES, provided image enhancement using d gital computer techniques to improve the quality and contrast of video tape frames of areas of concern. These combined effor+s in conjunction

.. ~.. M M M M M M M M M M M M M M l ( l SPARGERllALF I, l '\\ f 'y 7 k i / l \\ 3 ?)g(h% \\ 'M g O 1 ~ ( i l Al \\ Z j ,F,la-r t $I 1. ~ t L j l / 4 x j .\\_ ) ..'s -C l / ( 1 / / 1 l i s i / SP My ll0ZZLES i (total nur.ber 224) 5 in Sch40s 31" Sch40s OD = 6.625 in A312 TP304 j 280 in 00 = 4 in t = l t =.226 in 'j Bend Radius = 108.75 in i Figure 2-1 Core Spray Spargc' - Elevation View ) \\

, I with additional information about actual sparger material properties and I fabrication ruidual ttresses, resulted in a significantly improved understanding of the problem and enabled refined structural integrity analyses and predictions of crack propagation rates. 1 Results and conclusions of the APTECH work formed the basis for BECO to rt. vise ISI maintenance contingency plans for the October 1981 outage. A In July 1981, a meeting was held with the NRC staf f (6), ait :nded by GE, BECO, TES, and APTECll personnel, to present the results of recent analytical stuiie: and to propose sparger maintenance contingency options. At the request of tRC, BECO submitted an action plan (7), ins beting 2ccs ptance criteria f or maintenance options, schedule i estimates and ALARA estimates. l The core spray spargers were inspected during a five day period, ending October 9, 1981. On-site computer image enhancement was performed I during and irrediately af ter the inspection in order to enable prompt l level 3 t:DE review and interpretation, j At the request of the t!RC staff, a review meeting was held on October j 14, 1981 (8_). The meeting was attended by BECO and APTECH personnel. 1 j Preliminary results and conclusions were presented and computer enhanced j video tapes of areas of previous concern were reviewed. i Following the video tape presentation, BECO informed the staff that I findings based upon interpretation of the 1981 sparger inspection had indicated that the sparger is fully operational and no maintenance action l is required. fiRC staff requested docunentation of the work performed to support stated conclusions. This report provides a suonary of supporting i information. I I I I

. i 1I i 3.0 SPARGER EVALUAT10ft TECHitIQUES I i 3.1 Inspection Plan -l i Visual inspection of the core spray sparger assembly was performed using } two television rigs. The rotating fixed rig consisted of a horizontal rotating boom with a pivot point fixed at the center of the reactor I i vessel. Two TV cameras were fixed, one above the other, at the end of the boom close to the sparger. Lights were also attached at the end of the boom. This rig was used for horizontal and 45 vertical angle scanning of nozzles, nozzle welds, and top and bottom areas ( the sparger pipe and t j juncture boxes. These cameras were stationary. A hand operated TV camera rig was used for close-up inspection and for inspecting areas which required viewing from dif ferent angles. Details of the camera rigs and inspection procedure are Jiscussed in a separate report. g The camera rig was operated by CTS personnel located on the fuel loading IE floor in the reactor building. Video recording monitors, equipment and teleconnunications were located at the inspection control area one floor below. APTECH Imaging personnel, computer and imaging hardware were located in the same area. Imaging equipment was connected by a cable branch connector which enabled nonitoring and processing video signals directly f rom the TV cameras. Simultaneously, CTS personnel monitored and recorded video tapes of the inspection, fir. Shimkus directed the l inspection and reviewed results on video monitors located in the Ig inspection control area. m l I 3.2 Reference Indications Specific areas for 1981 exanination had been selected based upon SWRI l Level 3 f;DE interpretation of video tapes from the 1980 sparger inspection, and subsequent APTECH review and computer enhancement of suspect areas from inspection tapes. Photographs of those areas and a l

!3 !E i i video tape constructed from computer enhanced video tape frames provided a i j basis for assessing crack growth. During tne 1981 sparger inspection, video tape frames f rom the:,e areas and { other areas of interest were " grabbed" by computer processing equipment and stored on magnetic tape for computer image enhancement. As the inspection proceed;d, computer enhanced pictures were te,en from computer ( storage and displayed on a CRT screen for reviev by Mr. Shimkus to assist ft with intcrpretatian of suspert indications. Computer image enhancement 4 was used to provide more video information for the following reasons: ) o to demonstrate /isaal resolution of at least 0.001 in, based [ upon 1 mil vire gage. e to determine if original indicatf oris were actual cracks, l mechanical marks or shadows. to assess the details of newly discovered indications, e e to determine if the character of an indication had changed. l e to measure ano quantify crack propagation rates in the weld HAZ and areas remote f rom the welds.

I

{ l After completion of the sparger inspections, APTECH Imaging personnel enhanced all areas of concern identified by Mr. Shimkus. Final enhancements were recorded on video tape for ease of access for comparison to original inspection tapes and for records management purposes. A summary comparison of photographs of enhanced video tape frames f rom the 1900 and 1981 inspection is included in Section 5 of this report. I 3.3 Sparger Indication Calibratior! As discussed in (7_), reference enhanced video tape f rames provided a baseline 'or establishing crack growth rates when c.9mpared to similar images f roin the 1981 inspection. Obv'ously, it was not possible to i

p reproduce exactij the same camera angle, location, etc. during the 1981 inspection. For this reason, a calibration procedure was dcceloped, based Upon identification of distinctive landmarks in each 1980 photo. Distance i t between landmarks was measured and compared to the measured length of an i ndi c a t i, Gn. Identical procedures were applied to 1981 inspection results, except the ^easurements were taken directly f rom the CRT screen. This ratio scheme obviates the need for mathematical corrections otherwise l necessary to account for variables such as camera angle, camera distance f rom the sparger, etc., and permitted a reasonably accurate method for determining the present crack growth over the tir period between e inspections. The length of cn indication,vas de.ormiled based upon the same scaling technique by a ratio of indication length or landnark length to pipe dii %ter. 3.4 Summary of Structural Integrity and Fracture Mechanics Analysis Fracture mechanics analyses have been perf ormed by Aptech Engineerir.g i l Services, Inc. A bounding analysis approach was used to obtain conservative estimates of crack arrest length and rates of crack propagation. Parametric studies were performec assuming different values of sparger service stress in conjunction with rcsidual stress fields based upon theoretical and I empirical residual stress data. Crack growth rate data was taken f rom available IGSCC data for Type 304 stainless steel. Upper bound crack growth rates were developed f rom test data for furnace sensitized Type 304 in 8 ppm oxygenated water environment at 550 F. A second crack growth law was taken f rom the average of all as-welded Type 304 data. These values were used in "best estimate" evaluat,o of sparger weld regions and sparger pipe areas d remote from the weld heat affected zone for comparison with worst case crack growth predictions. Two separate fracture nechanics models were developed for sparger evaluation. The first model characterized the region in the weld heat affected zone with residual stress assumptions based upon pipe weld experimental data. The second model represented the pipe region away from

\\ the weld region whece residual stresses are present due to cold work during j the rolling operation to form the pipe to the required radius of curvature. l The sparger assembly was not heat treated after rolling nor after welding. i l Linear elastic fracture mechanics (LEFM) concepts were used to evaluate I indications in the core spray sparger pipe. In the evaluation, the indications were assumed to be crack-like and LEFM models were developed to f predict crack extension and final crack lengths associated with crack arrest. 1 I ihe effect of stress level and naterial crack growth rate on the calculated 1 l flaw length are shown in Figure 3 '. These results are applicable to flaw l indications located on the front side of the sparger pipe away from any 1 l weld joints. Based on these computations, crack arrest is expected for an l applied stress level, in addition to the residual stresses due to pipe fabrication, of 10 ksi or less. The residual stress distribution used in l this analysis is the theoretical distribution based on beam theory as shown in Figure 3-2. Experimental results f. rom strain gage analysis performed on similar curved pipe segments formed on the same equipment used to f abricate the actual sparger pipe, are also shown in Figure 3-2. I In the analysis for crack growth, two material conditions were assumed. 1) Worst case condition where data from tests performed on furnace sensitized material in 8ppn 0 water at 550 F, and 2

2) A best estimate condition where the mean crack growth data was used typical of as-welded condition, in the same environment.

A su: mary of the analysis assumptions is given in Table 3-1. A similar analysis was perforned on a flaw postulated to exist near a i sparger pipe weld connection. T e residual stress distribution was assumed to have a sinusoidal shape along the pipe circumference having a peak stress of vield strength level and a periud equal to pipe perimeter length. ) Tiis stress distribution is consistent with measured surface stresses 1 performed on 4-inch pipe circumferential welds. The results for this analysis are given in Figure 3-3. .n

-m__ , I The predictec' crack growth for an 18 month period based upon observed reference indications, are shown in Figures 3-4 and ?-5. Figure 3-4 gives the predicted growth for a flaw en the intrados (front-side) of the sparger away from any welds, anc Figure 3-5 gives the results For a weld-related j flaw. These computations assume an upperbound or worst case material crack growth rate behavior except for the weld flaw model (Figure 3-5) where both upper bound nean crack growth rate results are plotted for comparison. These graphs can be used to estimate conservatively the expected crack extension for 18 months of operation for an observed flaw indication. As an example, Table 3-2 illustrates the predicted crack growth for a 3-inch flaw indication. For the potential of flawi initiating and growing on the back-side of the I sparger pipe, Table 3-3 gives summary of the predicted time for cracking assuming upper bound crack growth rate behavior. It the measured tensile stresses on back-side (see Figure 3-2) are ari indication of a local surf ace stress effect, then the theoretical stress distribution would be more representative for long flaws. This model predicts crach growth arrest U when the crack becomes visible (~210 ). However, a conservative assessment { of the tensile stresses "as measured" on the back-side does not predict crack arrest. It should be noted that the limited test data shown in Figure 3-2 shows considerable data scatter, particularly on the backside of the pipe. Because " hand jacking" was used for final pipe curvature adjustments, it is believed that non-uniforn ard highly loc.alized stresses may exist in the sparger pipe. Table 3-4 gives a detail time-scale for U cracking beyond 180 at which point the back-side crack just becomes visible from the front side. I I

. _.. I 1 ) l l-TABLE 3-1 lg SUtif1ARY OF ANALYSIS ASSUtiPTIONS 1. Linear elastic fracture mechanics is applicable for predicting subcritical grack growth I 2. Flaw growth cracking mechanism is IGSCC y 3. Flaw model assurms center-cracked flat plate geometry under l general varying stress conditions l 4. Crack crowth predictions are primarily based on upper bound da/dt hehavior (i.e. furnace sensitized Type 304 in 8 ppm 0 l-at 550 F) 2 I 5. Crack arrest is assumed wher crack driving force, i.e. maximum stress intensity factor K vanishes (V 0) = mn y l 6. flaximum stress level limited to yield strength at 550 F (a = 23.7 ksi) I I I

. _.._ w :..a. u..,..x=; a.., s../ - ;;;:.2 :.:, 2 g n m - TABLE 3-2 I PILGRIM CORE SPPAY SPtscR irem! !Np !!SrfU'__ I i PREDICTED CRACK LENGTH S 0 I A'.REA I $Hjf _ !O'-?i. I {;UClj ja.35 [MAY FRC:1 UEL11 -3.2 in 3,lt in UELD FN. b. '.). IM 7 l, 'y i n \\ w ___.1 I FRACTURE MEcunNica ANALYSIS o I CRACK ARREST SW hWM ME! D "I O l :H. CRACK ARREST i,f WELD llA/- 10 In. O [, UASED UPc.'15 Ksr SERVICE Sm=ss H u. i' s!rra S ASSU:'ED CLACK LU1GiH OF i IN. n I N.T,s t 4 1130

2. UcLD DATA - AS MELDED (I'IEArd '4P 1

3. FURNACE SENSITIZED Duf.

GIVF.7~ l'11a (UPPER HOUND) I k

E lI i i i TABLE 3-3 i i SUlifiARY OF CRACK GROWTil PREDICTI0!iS FOR BACK-SIDE FLAW l l TIltE (DAYS) t II) l CRACK GROWTH AS-l1EASURED THEORETICAL ca o OilLY a +5Ksi o ONLY a +5Ksi r r r r _ 2) s10 to 180 1880 260 -(2) ( 180 to 360 2440 al Arresgs Arresgs 0 204 0 226 1 I T See Figure 2 for assumed stress distribution. IE 2 l T.1eoretical distribution gives negative stress on back-side so cracking is wi!! not initiate. Theoretical stress assumption is good if local t J tensile surface stresses exist as indicated in Figure 2. i i FLAW 110 DEL j i Back' Fi t 'N side s ~- h % {l ' -- +, 9 ..s y j 2a \\ ,i *1 { %L/ ) i i 1 1 4

.. TABLE 3-4 1 COT PUTED RE!MINItiG TII:E FOR BACK-SIDE FLAW If1DICATI0il JtJST VISIBLE REIMINING tit!E (l!0tJRS) II) AS-fiEASURED THEOP'.TICAL CRACK ANGLE RESIDUAL RESIDUAL. RESIDUAI.< RESIDUAL 2a OfiLY _ +5Ksi ._ OfiLY +5Ksi 180 58630 1130 160 1180 U 183 58610 1120 193 1129 204 0 (Arrest) 218 58190 980 226 0 259 53830 670 U 308 440 200 I e 360 0 0 (tio Arrest) (No Arrest) I See Figure 2 for stress distribution. FLAW 110 DEL I $ - [ Back Front side side 3, y.g / (' ; c(1 I ? \\, lI 2 I r l l i I i j t l. g .9.. I ~

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-2G-4.0 SUFNARY AND CONCLUSIONS A photographic comparison of video tape frames of identical areas from 1980 and 1981 inspections is provided in Section 5 of this report. These photographs represent a summary of numerous areas inspected, i.e. 224 I nozzles, approximately 115 feet of sparger pipe, and 4 juncture boxes. A discussion of examination results and conclusions is contained in the preliminary "ep 't (91 prepared by Mr. Robert Shimkus of SWRI. A copy of that report. ovided in Appendix A. Conclusions taken from Mr. Shimkus's report are is follows: O Six of the indications from the 1980 examination have been resolved as not significant. Two were determined to be heavy grinding, one was determined to be a mechanical mark, and two of the indications could not be relocated (found). o One area, "B" header to pipe weld and the area to nozzle 25B was I determined to have undergone no change since the 1980 examination. Cracks appear in the upper quadrant. This area has stabilized with regard to crack propagation and further area degradation is not anticipated. I Cracks identified as being present in the sparger pipe adjacent to the B juncture box are shown on Figuret 5-10 to 5-19. This area is shown sketched on Figure 4-1 to assist the reader with locating crack orientation with respect to the pipe and junction box. I The principle crack can be seen on Figure 5-16 in the upper quadrant of the pipe. The crack travels through a dark wire brush mark (away from weld HAZ) and travels downward, curving towards the weld HAZ and then veers in a dog leg fashion away from the HAZ. Scaling calibration calculations indicate this crack is about 1 inch long and 0.002 inches wide, from the bottom of the brush mark to the crack tip. The length of the dog leg portion is approximately 0.3 inches. A very faint line suggests possible branching at the dog leg. Figure 5-19 shows a 1981 enhancement of the same area after I cleaning. A branch crack, approximately 0.9 inches long, eminates from the dog leg joint, travels into the HAZ, along the toe of the weld and veers

f _ _ _ _ i l i i i I l e-Reference Brush "crk from 1980 l 1 fl j ozzle # 25 l 5 in. Juncture Box \\ l e\\-s,M' ' Spray flozzle Fillet i j y ',% Weld I p( ' 'N*~ /} 4elded end plate N- ~- 31 in. Spr.rger P1pe p E + i i - 1980 Principal Reference Crack Fishhook Mechanical fiark l Figure 4-1 Sketch showino location of cracks in the sparger pipe adjacent to the I "B" Juncture Box (see Fioures 5-16 and 5-19). ~ l

- I out of the HAZ in a path approximately parallel to the dog leg portion of the principal crack. Note on Figure 5-16, (from the 1980 inspection) an indication below the dog leg and parallel to the dog leg. Subsequent review of the 1980 inspection video tapes revealed that indication to be the same branch indication shown on Figure 5-19. The quality cf video tape records did not permit further enhancement of that specific area. Visual inspection indicates that the character of the branch crack has not changed. i Crack growtn rate predictions surrmarized in Section 3.4 indicate a conservative crack growth of 0.2 inches over the time period since the 1980 inspection. This prediction was based upon maximum growth of an existing 3 in. crack away from the weld. As seen on the photos, the ends of the crack are located in an area outside the weld HAZ where a predicted crack growth rate of less than 0.2 in. would be applicable. Video tape resolution l did not permit complete crack growth calibration accuracy within the predicted limit; however, calibration of the dog leg portion of the crack showed no significant growth since the 1980 inspection. I Based upon available video tape information, it is concluded by APTECH personnel that no significant changes are apparent and that crack propagation rates would be expected to be low due to the fact that the I cracks are propagating in an area where pipe fabrication residual stresses control. There remains a question of detail resolution of the branch crack; however, that question is somewhat academic since the 1981 inspection results show the indication is propagating away from the weld. I It was not possible to obtain close-up pictures of the top of the pipe due to interference from protruding nozzle ends. However, a close inspection of the pipe midsection and lower cuadrant revealed no relevant indications. Mr. Shimkus prepared his inspection report on site immediately af ter reviewing inspection tapes and computer enhanced tape frames of areas of concern. Subsequen+1y, APTECH reviewed the 1981 video tapes and " fine-tuned" computer enhancement of suspect areas for photographic documentation contained in Section 5 of this report. In the course of this effort, several additional suspect indications were found and enhanced for further evaluatior.. I

I,I Photographs of those areas were forwarded to BECO and SWRI for aview and interpretation. Mr. Shimkus concluded that one indication was relevant. l He identified a find crack indication located in the lower quadrant of the sparger pipe near the toe of the weld at the "A" sparger junction box. This indication is s;.own on Figures 5-39 to 5-42. The crack appears from a lI mechanical mark or arc strike at approximately the 5 o' clock position as i i } shown on Figure 5-41 and travels to a position near 3 o' clock as shcwn on f Figure 5-42. Calibration techniques indicate a crack length of approximately i 1.75 inches and an estimated width of approximately 0.002 inches, il l Unfortunately, computer inage processing from 1980 intpection tapes of this region was not possible; therefore, reference calibration information is not available. However, insignificant crack growth determined from 1981 inspection ( and calibration of cracks away from the weld HAZ suggests that the use of I average weld crack growth data provides 6 conservative prediction for sparger l crack growth. Therefore, our best estimate of crack arowth is less than 1 inch over the next 18 month full cycle. 1 l It is concluded, based upon interpretations and structural integrity evaluations contained herein, that the linear crack indications in the upper quadrant near the B _ junction box and in the lower quadrant of the A junction box fall within established structura, integrity criteria (7),and clamping is not required. I Early during the inspection, crack growth calibration talculations were performed for reference indications away from the weld HAZ (see Figure 5-29 and 5-31). Those calculations showed no significant differences in indication length. Subsequently, af ter computer enhancement, those areas were determined to be non-relevant indications as reported in Appendix A. I I I

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Reference:

Par. 3.1.1 and Figure 1 in Appendix A. l i u.. a

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4 Figure 5-4 1981 Computer Enhancement of Figure 5.-5 1981 Computer Enhancement of flozzle 403. Approximately 45 flozzle 408. Camera Viewing Camera Viewing Angir. Angle is fiearly Verticle. Shows Enhancement Shows Flechanical klide flechanical flarks from Weld ildrks from Weld Grinding. Grinding.

Reference:

Par. 3.1.1 an Figure 1 in Appendix A.

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Reference:

Par. 3.1.2 and Figure 2 in Appendix A. t i I

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Reference:

Par. 3.1.2 and Figure 2 in Appendix A. L

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Reference:

Par. 3.1.3 and Figure 3 in Appendix A.

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Reference:

Par. 3.1.3 and Figure 3 in Appendix A.

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Reference:

Par. 3.1.4 and Figure 4 in Appendix A.

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Reference:

Par. 3.1.4 and Figure 4 in Appendix A.

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Reference:

Par. 3.2.1 and Figure 5 in Appendix A.

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Reference:

Par. 3.2.1 and Figure 5 of Appendix A. f 4

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Reference:

Par. 3.2.3 and Figure 7 in Reference A.

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Reference:

Par. 3.2.3 and Figure 7 in Appendix A. 4

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.. ~. _. jg !E !'l References l 1) Inspection of Core Spray Spargers, General Electric Service information Letter (SIL) No. 289, dated January 19P). l

2) Licensing Event Report (LER)lio. 80-004/023-0, dated February 1, 1980.

l l

3) Boston Edison Company meeting with the NRC, Bethesda, MD, February l

29, 1980. l

4) Boston Edison Company meeting with the tiRC, Bethesda, MD, March 13, 1980.

)

5) Supplement 1 Reload Licensing Submittal for P 'gim Nuclear Power I

Station Unit 1 Reload 4, NED0-24224-1, supplement 1 dated March 1980. i

6) Boston Edison Company meeting with the NRC, Bethesda, MD, July 30, 1981.

l

7) Boston Edison Company letter to NRC, Septeniber 9, 1981

8) Boston Edison Company meeting with the NRC, Bethesda, MD, October 1

14, 1981 i

9) Preliminary Report of 1981 Remote Visual Examination of the Pilgrim Nuclear Reactor Core Spray Piping and Spargers.

R.P. Shimkus, SL'RI, j October 9, 1981. I t 'I I i I

[ E [ I I APPENDIX A I I I I I I I I I l

JAl-/ l l- /0 -t 4/-8 / NKC/6fCO A//?~2 MEMORANDDI I TO: Frr.h Faculari Boston Edison Company Pilgrim Station DATE: October 9, 1981 FROM: R. P. Shirkus S.!J. R. I. SU3 JECT: Preliminary Report of 1981 Remote Visual Examination of the Pilgrim Nuclear Reactor Core Spray Piping and Spargers 1.0 SCOPE Perform a remote visual examination of the subject reactor component. The examination is to meet ASME Sectica XI, Item Bl.1 and category B-N-1. In addit: on, the examination is to address the NRC Bulletin 80-13 requirement for a visual resolution of a 1 mil. wire placed in the examination area. I 2.0 EXMIINATION The examination was performed in accordance with the Southw_st Research Institute (SWRI) Examination Plan prepared for project 17-6676 (61-BEC-PPS-1-1-0) approved by Boston Edison Company (BECo). The resulting data was evaluated by the writer, a Level III risual examiner, qualified by experience and written examination. Re-examination and surface cleaning was accomp-lished as considered necessary for indication resolution. l 3.0 EXAMINATION RESULTS 3.1 Resolution of 1980 examination indications on lower spsrger. 3.1.1 "B" sparger, nozzle 40B - 1980 examination showed GZ linear indications, see figure 1. The 1981 examination resolved these as resulting from grinding to remove weld undercut, see tape 10. The 1980 examination equipment did not permit view of i.he Udications from the nearly vertical position. The rest:lting oblique linhting cast a sharp narrow shadow (line:r indication).

3.1.2 "B" sparger, nozzle 41B, see figure 2. Same as 3.1.1. { 3.1.3 3450 Header-to-sparger pipe weld and area out to nozzle 25 on the "B" system. The 1980 examination shcwed many linear indications, see figure 3. The 1981 examination exhibits the same characteristics as in 1980, see tape 8 count 330-413 and tapes 9 and 10. There is no contir.uous crack like indication extending f rom over the top of { the sparger piping to underneath the same pipe. A fine line appears on the hcader-to-sparger weld, but because the weld is thicker than the sparger pipe wall it would not normally be considered significant (a crack). -A 3.1.4 1650 Header, "D" Sparger, to pipe weld. The linear indicar. ion found during the 1980, see figure 4, examination is no longer visible. I The 1980 indicator is believed to have been a shadow. 3.2 Upper Sparger 3.2.1 150 Header, "A" Sparger, Header to pipe weld linear indication observed during the 1980 exanination, see figure 5, is no longer visible. It appears to have resulted f rom some residual weld undercut not completely removed by grinding. 3.2.2 The transverse indication pipe 8" - 12" towards 2700 from the "A" sparger header observed during the 19"3 examination, see figure 6, has been resolved as not significant, see tape 8, count 413-453. This indication has been shown to have no depth when viewed close I up normal to the pipe. 3.2.3 195 Header, "C" Sparger, 1" to 1" f rom header to sparger weld on the 2 pipe. The 1980 examination, see figure 7, showed a linear indication, extending vertically downward from an arc strike. No linear indication could be found during the 1981 examination. The area was wire brushed and re-examined, see tape 10 No linear indication could be resolved.

4.0 CONCLUSION

i Six of the indications from the 1980 examination have been resolved as i l not significant. Two were deteret,e.? to be heavy grinding, one was determined to be a mechanical mark, and two of the indications could not be relocated (found). 'I I One area, "B" header to pipe weld and the area to nozzle 25B was deter =inc-d to have undergone no change since the 1980 examination. Cracles = appear in the uppet quadrant. This area has stabilized with regard tc crack propagatic;, and fu:ther aren degradation is not anticipated. 1 I i k R. P. Shicius !g Technical Consul

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Index Tape #11 EXCEPETS FROM 1980 & 198_1 TAPES Tape Footage Description 0-20 Leader 20-32 1800 side C Junct. Box Upper Portion 32-61 180 side C Junct. Box Upper Portion af ter cleaning 1981 view 61-67 1 Mil Wire 18Co side C. Junction Iox 1981 View 67-76 Oo Side B Junct. Box 1980 View 76-83 00 Side B Junct. Box 1981 View t i 83-91 0 Side B Junct. Box 1981 View Computer enhanced. i 91-100 00 Side B Junct. Box after cleaning 1981 View. I 100-112 Computer Enhaaced View of Heat Affected Zone (HAZ) between Nozzle 25B and B Junct. Box, 1981 View 112-120 Expanded View (Corp. enhanced) of HAZ between B Junct. Box and Nozzle 25B, 1981 View. 120-127 HAZ Nozzle 25B, Computer enhanced, 1981 View. 127-138 HAZ Nozzle 408, 1981 View 138-145 HAZ Nozzle 40B, 1981 View 145-153 HAZ Nozzle 413, 1981 View 153-159 HAZ Nozzle 40B, 1981 View enhr. aced 159-167 HAZ Nozzle 40B, 1981 View enhanced 167-175 HAZ Nozzle 41B, 1981 View enhanced 175-185 2700 Side D Junct. Box 1980 View 185-195 270 Side D Junct. Box 1981 enhanced 195-203 Area of Interest above Nozzle 32A, 1981 203-206 Area of Interest above Nozzle 32A, 1981 206-218 Enhanced View of Area above Nozzle 32A, 1981 218-225 Cal. Standard adjacent to Nozzle 32A 225-240 2700 Side of A Junction Box 1981 240-245 Cal. St 'd. Check at A Junct. Box, 2700 Side

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