ML20206H980

1987 Remote Visual Exam of Core Spray Sparger Sys of Pilgrim Nuclear Power Station,Unit 1,Final Rept, Performed Per IE Bulletin 80-13.Exam Revealed No Change in Known Indications & No Addl Concerns Identified

ML20206H980
Person / Time
Site:	Pilgrim
Issue date:	03/31/1987
From:	Flach W, Hageman J SOUTHWEST RESEARCH INSTITUTE
To:
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ML20206H549	List: BECO-87-058, Forwards 1987 Remote Visual Exam of Core Spray Sparger Sys of Pilgrim Nuclear Power Station,Unit 1,Final Rept, Performed Per IE Bulletin 80-13.Exam Revealed No Change in Known Indications & No Addl Concerns Identified ML20206H980
References
IEB-80-13, NUDOCS 8704150487
Download: ML20206H980 (46)

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1987 REMOTE VISUAL EXAMINATION OF THE CORE SPRAY SPARGER SYSTEM OF PILGRIM NUCLEAR POWER STATION, UNIT 1 FINAL REPORT SwRI Project 1470 Prepared for Boston Edison Company 800 Boylston Street Boston, Massachusetts 02199 March 1987

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SOUTHWEST RES E A RCH INSTITUTE l wA f// / SAN ANTONIO HOUSTON 8704150487 870410 PDR ADOCK 05000293 G PDR

1987. REMOTE VISUAL EXAMINATION OF THE CORE ~ SPRAY SPARGER SYSTEM OF PILGRIM NUCLEAR POWER STATION, UNIT l' FINAL REPORT SwRI Project 1470 Prepared for Boston Edison Company 800 Boylston Street Boston, Massachusetts 02199 f

March *1987 Prepared by Approv d by i

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Jo % P. Hageman 9 Wayn6T.//Flach Project Engineer Directop Inspection Engineering Section Department of Engineering Services Department of Engineering Services Nondestructive Evaluation Science and Technology Division

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ABSTRACT.

A remote visual (VT) examination of the core spray sparger system of the reac- ,

tor pressure vessel (RPV) of Boston Edison Company's Pilgrim Nuclear Power Sta- '

tion, Unit 1, was performed during refueling outage No. 7. This was the fourth examination of this type performed on the core spray sparger system and the second performed during the second 10 year interval of commercial operation.

This remote VT examination was performed using a high resolution video equipment and lighting, and allowed for a larger degree of _ freedom for viewing examination areas than was available in previous examinations. Also, the Level III examiner was present during the examination of the core spray spargers and could directly '

coordinate the remote camera viewing of all areas of interest. The combination

! of better equipment and direct Level III examiner involvement was especially important in examining the indication areas reported during previous examina-tions. The examination results were compared to indications reported during the previous examinations. This examination revealed no significant indications in the core spray sparger system.

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9 TABLE OF C01 CENTS P,, age, LIST OF ABBREVIATIONS ...'. . . .... . . . . . . . . . . . . . . . iv FINAL REPORT . . .. . . . . . . .. ..... . . . . . . . . . . . . ' 1 APPENDICES .

.A. Boston Edison Company Nondestructive

Testing Procedure B. Certificates of Personnel Qualifications C. Nuclear Regulatory Connaission Inspection j and Enforcement Bulletin No. 80-13 D .' Field Data i

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. LIST OF ABBREVIATIONS

'ASME -

American Society of Mechanical Engineers BEco- -

Boston Edison Company CNF -

. Customer Notification Form ISI .- Inservice Examination NDT~ --

Nondestructive Testing

.NRC -

Nuclear Regulatory Commission QA-Quality Assurance ..

RPV -

Reactor Pressure Vessel SwRI -

Southwest Research Institute VT -

Visual Examination i

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1987 REMOTE VISUAL EXAMINATION OF THE CORE SPRAY SPARGER SYSTEM OF PILGRIM NUCLEAR POWER STATION, UNIT 1-During refueling outage No. 7, Southwest. Research Institute' (SwRI) personnel performed remote visual examination (VT) of the. Core Spray Sparger system in.

Boston Edison Company's (BECo) Pilgrim Nuclear Power Station, Unit 1. This i examination was a follow-up to the January.1980, October 1981, and December 1984 examinations and was performed to meet the intent of the U.S. Nuclear Regulatory Commission (NRC) Inspection and Enforcement Bulletin No. 80-13, dated May 12, 1980.

Applicable Documents j The examinations were performed in accordance with the following documents:

Section XI of the American Society of Mechanical Engineers (ASME) Boiler j and Pressure Vessel Code, " Rules for Inservice Inspection of Nuclear Power -

j Plant Components," 1980 Edition with Addenda through Winter 1980.

NRC Inspection and Enforcement Bulletin No. 80-13.

1 j Examination Areas All accessible portions of the core spray spargers and supply line piping were examined. The Level III examiner directly coordinated the remote camera view-ing of all areas of interest. Particular attention was given to examination

areas of concern during previous examinations. This included the areas near j the sparger B junction box on the 0-degree side to nozzle 258.

Summary of Examination Results j The remote VT examinations were conducted in accordance with BECo Nondestructive Testing (NDT) procedure TF86-215, Rev. O, which incorporated SwRI-NDT-900-7/6, written by SwRI to conform to the requirements of the applicable ASME Code and i

NRC Bulletin No. 80-13. A copy of BECo's procedure is included in Appendix A.

l The remota VT was performed by an SwRI Level III visual examiner qualified by j experience and written examination. The examination was also recorded on videotape for future reference. The resulting videotape data were reviewed by

} the Level III visual examiner as necessary to resolve the various types of j indications.

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} Improved equipment and lighting as compared to that available during previous j examinations and direct Level III examiner involvement, while performing the examination, allowed for a more thorough core spray sparger examination.

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l One specific area which includes the B junction box-to pipe weld on the 0-degree l

! side and extends to and includes the first spray nozzle -(No. 25B), was previ-ously reported to contain several indications. RDuring this examination, partic- l 4

ular emphasis was placed on these previously reported indications. The remote VT examination revealed no significant indications. The-indications observed ,

in the core spray sparger were compared with the videotape recording made during the previous ISIS. .This examination revealed no significant indications, and based on data comparisons there were no observable changes in the sparger condi-

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tion. No additional areas of concern were identified.

Examination personnel were certified in accordance with SwRI Nuclear Quality Assurance Procedure 11-2 which incorporates the guidelines of SNT-TC-1A of the' ,

American Society for Nondestructive Testing. A copy of each individual's certi-fication is included in Appendix B.

Appendix C contains a copy of the NRC Inspection and Enforcement Bulletin No. 80-13.

Equipment

A remote video system, with cameras and manipulation equipment provided by SwRI, was used for the VT examinations. This equipment had improved variable i lighting and allowed for a larger degree of freedom for viewing the examination

] areas than was available in previous examinations. The video camera was a Westinghouse high resolution miniature underwater television system (ETV-1250) with both adjustable internal and augmented lighting.

Radiation Exposure Radiation exposure encountered during the examinations was of fundamental con-cern to all SwRI personnel involved during the daily examination activities.

SwRI personnel took the necessary precautions in order to minimize overall expo-sure and consequently received the minimum dosage practicable while performing the examinations. The radiation level on the refueling crane, where the exami-nation personnel were primarily located, was approximately 2-10 mRea per hour.

Explanation of Field Data Records

The results of the examinations performed by SwRI personnel were recorded on SwRI Visual Examination Record Sheets. These completed documents constitute a i portion of this report and are found in Appendix D. The original records are

! retained in the SwRI Data Storage Facility, and copies are provided herein for completeness.

i The Visual Examination Record Sheets for each examination area are assembled into a package preceded by a Summary Sheet. The examination areas and summary sheet numbers correspond to .those listed in the Summary Table.

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Summary of Nondestructive Examinations Table The following section of this report is the Summary of Nondestructive Exami-nations Table (Summary Table). The Summary Table provides information and-results for the nondestructive examinations performed during this remote VT examination. See Figure 1 for an explanation of the Summary Table format.

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SEC al SEC Ms Pet 00E EMMBE E XAtt. $Ued REGAAR0[5 lited HO CAIGY AAIA I I ' pdQ)ILEV. $tgEEi psO. NO RECOIIDASLE WSIG800F 8CANI GEOBAE IR0C OTHER 1

h remarks column le used to deserthe any partiment feature et the esenteettee such as liettettomeg

- reportable reemIto, Cure, etc.

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Witrosonic celthrottee blocke ese 1 ' -  ?, " slee listed here.

1 W presence of ladicottene uhtcle are deemed reportable to the customer le in-dicated la this celumme.

m presence of ultreeenic indicottene elious to be the results of a geometric feature of the esami-matten eres to indicated la thlo column.

p The presence of meerelevant indicottees er ultresemic indicatione uhtch are equel to or greater then recording emplitude but lese then evaleotten level le indicated in thle celema.

The sheence of ladiestfees equel to er greater then the reeerding level of the respective IIDT precedure to indlested in this column.

nf o celuen references the eneminaalen summary sheet whicts serves se a cover olieet for the data package and lists tine data record numbers, the essetnere, and any pertiment remasks.

This coluen lists the applicable IIDT procedure used for the exentastion.

N Iluf method assed during the enemimetten le listed in thle celuen.

sech eseatnetten eres le listed in this column.

The ASMg Sect tom It itsen nder and category of the eneminettee eres are listed in these columne.

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Figure 1. Explanation of Summary Table Format

PIlf, RIH NUCLFAR POWER STATION, UNIT I 1987 INSERVICE REMOTE VISUAL EXAMINATIONS REACTOR PRESSURE VESSEL ASME ASHE BECo Weld ' Indications Sec. XI Sec. XI Examination Exam. Procedure Exapl3 5um. Resarks Item No. Catcy. Area Identification Method No./Rev. Shbet No. No Recordable insignificant Geometric Other VESSEL INTERIOR B13.20 B-N-2 Core Spray Sparger VT-1 86-215/0 '308701 X Examination limited to Rings A, C, and D, the f ront side of the Nozzles and Junc- sparges due to core tion Boxes * /. sb oud interference.

"[" No]!g;ificant i sull-cu auns were observed.

B13.20 B-N-2 Core Spray Sparger Ring B, Nozzles and VT-1 86-215/0 308702 f

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'[ Examination limited to f ront side of the Junction Box sparger due to core i-shroud interference.

, Examination in the

, locattoo of prevtous indications observed on the 0-degree side on of the Junction Box B and associated with nozzle 255 revealed no significant indi-cations.

B13.20 B-N-2 Core Spray Sparger VT-1 86-215/0 308703 X Examination limited to Ring C Piping the front side of the sparger due to core shroud interference.

No significant indi-cations were observed.

B13.20 B-N-2 Core Spray Sparger VT-1 86-215/0 308704 X Examination limited to Rings A, B, and D the front side of the Piping sparger due to core shroud interference.

No significant Indi-cations were observed.

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cPILC IM NUCLEAR POWER STATION, UNIT !

1987 INSERVICE REMOTE VISUAL EKAMINATIONS REACTOR PRESSURE VESSEL (Cont'd)

ASME ASME SECo Weld Indications Sec. 11 Sec. 11 Examination Esas. Procedure Exam. Sun. Remarks Item No. Catay. Area Identificatfoe Method No./Rev. Sheet No. No Recordable Insignificant Geometric Other VESSEL INTERIOR (Cont'd) 813.20 5-N-2 Core Spray Sparger VT-1 86-215/0 108705 1 Ezanination limited Supply Lines A, B, due to core shroud.

C, and D. Supply ' Ma significant fedl-Lines and T Boxes cations vote observed.

813.20 5-N-2 iC ore Spray Sparger VT-1 86-21$/0 308706 1 No significant indt-Supply Lines A and .

cations were observed.

B (Pehind _*.*.toud) 813.20 B-N-2 Core Spray Sparger VT-1 86-215/0 308707 I No significant ind!-

Supply 2.tnes C and cations were observed.

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APPENDIX A BOSTON EDISON COMPANY NONDESTRUCTIVE TESTING PROCEDURE

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APPENDIX A BOSTON EDISON COMPANY t0NDESTRUCTIVE TESTING PROCEDURE Table of Contents Procedure No. Title TP86-215 Visual Examinaiton of Nuclear Reactors A-1

BOSTON EDISON

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NUCLEAR OPERATIONS DEPARTMENT PILGRIM NUCLEAR POWER STATION Temporary Procedure No. TP86-215 .

VISUAL EXAMINATION OF NUCLEAR REACTORS List of Effective Pages .

TP86-215-1 TP86-215-la ..

TP86-215-2 '

TP86-215-3 TP86-215-4 TP86-215-5  %

TP86-215-6 -

TP86-215 TP86-215-8 i'

List of Attachments ~ N"U None Approved Mc.7 n //jeg

,QA Managegi/ /

Approved W 4_r-- k LYLhtSAd ,

I Hudlear Opera tions Manager

,' Date  % %C.

Expiration Date ) 2, a 3 l -N Safety Evaluation =Reappbred/Not Required

.- TP86-215-1 Rev. 0

SOUTHWEST RESEARCH INSTITUTE SwRI-NDT-900-7 Revision 6 NUCLEAR PROJECTS -November 1983 l . -

OPERATING PROCEDURE Page 1 of 7 Time VISUAL EXAMINATION OF NUCLEAR REACTORS EFFECMVITY ANC AMRCVAl.

% 6 of mis ornamour, seenie egense, an 11-18-83. Cmer.-of me base desumentinov be effusme enerrentry.

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DL *NNtL0,, V.l a ig3 ,

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alsJhj b W of h cae . 6 cteurer cas ,

v =A' h, g,' i't;, fJ N f*W informenon me, se us e for c ,m, o ,,m,, nion;,n , ,,,,,,,,y, cevienen .s Cata L**annw h Sec=ent:s Affse ss Netss: i i

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l TP86-215-l a Rev. 0

SOUTHWEST RESEARCH INSTITUTE 8","I;"i-' -7

.( November 1983 NUCLEAR PROJECTS OPERATING PROCEDURE

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VISUAL EXAMINATION OF NUCLEAR REACTORS SwRI-NDT-900-7

1. PURPOSE This procedure provides the technical information and detailed steps required to ensure the proper visual examination of nuclear power plants in accordance with the applicable ASME Boiler and Pressure Vessel Codes.

2. SCOPE AND APPLICATION Direct and remote visual techniques shall be applied as specified for the examination of:

(1) Nuclear power plant components (2) Nuclear reactor internals 6g, -

(3) Support members and structures for piping, valves, and pumps

3. APPLICABLE DOCUMENTS (1) ASME Boiler and Pressure vessel Code,Section XI,1980 Edition with Addenda through Winter 1980, " Rules for Inservice Inspection of Nuclear Power Plant Components" (2) SwRI Nuclear Quality Assurance Program Manual (NQAPM) 3.1 Applicable Examination Record SwRI-NDTR Form No. 17-28, revision dated 07-30-80

4. RESPONSIBILITY (1) The Director of the Department of Engineering Services, Quality Assurance Systems and Engineering Division, shall be responsible for the preparation, review, approval, and control of this procedure.

(2) The Project Manager shall be responsible for the implementation of this procedure in accordance with the NQAPM specified in the appli-cable SwRI Project Plan.

TP86-215-2 Rev. O Swfu Form QA 3-2

SOUTHWEST RESEARCH INSTITUTE S""';%-l-7 t November 1983 NUCLEAR PROJECTS OPERATING PROCEDURE

/ Page 3 of 7 (3) The examiner shall be responsible for implementing the requirements of this procedure.

(4) The Manager of the Support and Administration Section, Quality Assurance Systems and Engineering Division shall be responsible for storage of records generated in accordance with this procedure.

5. PERSONNEL AND EQUIPMENT

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5.1 Personnel Certification Personnel performing examinations shall be certified in accordance with SwRI NQAP 11-2, " Procedure For Certifying Visual Examination Personnel."

5.2 Equipment The Visual Examination Acceptability Test Card shall be made from Kodak Neutral Test Card No. R-27 or an equivalent, with an 18% neutral grey p side having a 1/32-inch-wide black line across its center.

Commercially available equipment shall be used as required for the per-formance of examinations or operations by the techniques described in Parn-graphs 6.1, 6 2, 6 3, and 6.4.

6. EXAMINATION METHODS 6.1 VT-1 Examinations The examiner shall determine the condition of the hrt , component ,

or surface with respect to cracks, wear, corrosion, erosion, or physical damage to the surface of the part or component.

6.1.1 Direct Visual Direct visual examination shall be performed by placing the eye within 24 inches of the surface to be examined and at an angle no less than 30 degrees with the surface to be examined. Mirrors may be used to improve the angle of vision, and aids such as magnifying lenses may be used.

In addition to the general lighting, illumination of the area to be examined shall be provided at right and oblique angles to expose cracks or evioence of corrosion or erosion.

TP86-215-3 Rev. O SwQI Form QA 3 2

SOUTHWEST RESEARCH INSTITUTE S""Z-l-7

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November 1983 NUCLEAR PROJECTS OPERATING PROCEDURE

,,,,,_ Page 4 of 7 Resolution shall be considered adequate when the combination of access, lighting, and angles of vision, either unaided or corrected, can resolve a 1/32-inch-wide black line on an 18% neutral grey card placed on the

! surface to be examined.

6.1.2 Remote Visual Technique Remote visual examination may be used where conditions exist that do not permit direct visual examination. Remote visual examination may include visual aids such as telescopes, periscopes, borescopes, fiber optics, or video cameras and monitoring systems, with or without attachments for permanent recording. Remote techniques shall demonstrate the ability to provide a reso-lution at least equivalent to that obtainable by direct visual examination.

Mirrors, movable lights, or rotating optics, or any combination thereof, may be employed to display cracks, surface scratches, or evidence of corrosion, ero-sion, misalignment, or movement. Scanning parameters, if required, for the remote visual examination shall be included in the applicable SwRI Scan Plan.

,, Resolution shall be considered adequate when the combination of

({p access, lighting, and angles of vision, either unaided or corrected, can resolve a 1/32-inch-wide black line on an 18% neutral grey card placed on the surface to be examined or in a situation similar to the area to be visually examined.

6.2 VT-2 Examinations The examiner shall locate evidence of leakage from pressure-retaining components, or abnormal leakage from components with or without leak-age collection systems as required during system pressure or functional tests.

6.2.1 Noninsulated Components The accessible external exposed surfaces of pressure retaining components shall be examined for evidence of leakage.

Examination of the surrounding area, including the floor or equipment located underneath the component, shall be required for components with inaccessible external surfaces.

6.2.2 Insulated Components Examinations may be conducted without the removal of insulation by examining the accessible exposed surfaces and joints of the insulation.

Vertical surfaces of insulation need to be examined only at the lowest eleva-tion where leakage may be detectable. Horizontal surfaces of insulation shall be examined at each insulation joint.

TP86-215-4 Rev. 0 SwRI Form QA 3-2

SOUTHWEST RESEARCH INSTITUTE g"I;$f-7 q November 1983 NUCLEAR PROJECTS OPERATING PROCEDURE t Page 5 of 7 Inaccessible piping and components shall require an examination for evidence of leakage on the surrounding floor areas, equipment surfaces located underneath the component, or other areas where leakage may be channeled.

• Discoloration or residue on surfaces examined shall be given particular attention to detect possible boric acid accumulations from borated reactor coolant leakage.

6.3 VT-3 Examinations The examiner shall determine the general mechanical and structural conditions of components and their supports, such as the presence of loose parts, debris or abnormal corrosion products , wear , cracks , erosion, corrosion, and the loss of integrity at bolted or welded connections.

6.3.1 Vessel Internals The areas to be examined shall include major load-bearing elements

[,, of the reactor internals which are relied upon to retain the core structure in position; the lateral, vertical, and torsional restraints within the reactor vessel; the locking and bolting devices whose failure could adversely affect the structural integrity of the internals; surfaces that are known to be or may become contact surfaces during operation; critical locations on reactor inter-nal components as identified from the vibration analyses; and the interior of the reactor vessel for evidence of loose parts or foreign material.

6.4 VT-4 Examinations This examinatien shall be performed to determine conditions relat-ing to the operability of components or devices such as mechanical and hydrau-lic a nubbers, component supports, pumps, valves, spring-loaded hangers and cons'. ant supports. Functional adequacy, verification of settings, or freedom of rocion shall be determined.

The support settings of constant and variable spring-type hangers, F ubbers, and shock absorbers shall be recorded in the REMARKS section of the

$wRI Visual Examination Record.

The scale reading of hangers having calibrated load indicators shall be recorded in the REMARKS section of the SwRI Visual Examination Record.

TP86-215-5 Rev. O SwQI Form QA 3-2

SOUTHWEST RESEARCH INSTITUTE S"'I-""J'-7 ge

-November 1983 q NUCLEAR PROJECTS OPERATING PROCEDURE Page 6 of 7 Hydraulic snubbers shall be examined for signs of fluid leakage at chaft seals, joints, and couplings. Shaft extensions shall be examined for scratches, cuts, and gouges.

Hanger springs shall be examined for integrity to ensure that cprings have not sheared.

Pipe clamps and U-bolts shall be examined to ensure that they are cecurely attached to the pipe.

7. Examination l

7.1 Surface Cleanina Visual examinations which require clean surfaces or decontamina-tion for valid interpretation of results shall be preceded by appropriate cleaning processes.

Examinations may be required where the surface is painted or has h other types of coatings. This shall be. permitted if it is determined that such coatings do not interfere with valid interpretation of results.

7.2 Examination Areas l

Components, parts, and areas to be examined shall be as specified in the applicable SwRI Examination Plan. Remote visual examinations utilizing ,

techanized scanning devices shall be as specified in the applicable Scan Plan. I Scanning parameters, if required, for the remote visual examination, shall be included in the applicable SwRI Scan Plan.

8. RECORDING CRITERIA Indications shall be recorded in accordance with the techniques outlined in the applicable revision of SwRI Nuclear Projects Operating Procedure IX-FE-ll6 for direct visual examinations. Indications detected in remote visual examinations shall be recorded in accordance with the customer's

sp' ecifications, ' remote equipment manufacturer's specifications, or the SwRI Scan Plan, if applicable.

Visual abnormalities shall be recorded on the SwRI Visual Examination Record and reported to the customer. I i

TP86-215-6 Rev. O SwAl Form QA 3 2

SOUTHWEST RESEARCH INSTITUTE SwRI-NDT-900-7 Revision 6 l -

November 1983 q NUCLEAR PROJECTS OPERATING PROCEDURE

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9. EVALUATION Evaluation of reportable indications shall be the responsibility of the customer, or the customer's representative, and shall be conducted in accor-dance with Article IWA-3000,Section XI, of the applicable ASME Boiler and Pressure Vessel Code.

10. RECORDS The customer shall receive copies of documents generated in accordance with this procedure in the examination report.

Documents generated in accordance with this procedure shall form a part of the examination report which shall be stored by the Manager of the Support and Administration Section, Quality Assurance Systems and Engineering Division, in the Data Storage Facility for the period specified by the contractual agreeme'nt with the customer.

TF86-215-7 Rev. O SwRI Form QA 3-2

PROCEDURE DEVIATION Page 1 of 1 Pages Procedure Rwisen DwMon

{ SwRI NDT-900-7 .

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The followeg examination areas are affected by this devotion:

Remote visual examinations of the reactor core spray spargers and the segment of piping betwaen the inlet nozzle and vessel shroud shall be affected by this deviation.

THIS DEVIATION SUPERCEDES DEVIATION 3 The following paragraphs shall be deviated from as itxhcated.

Change the form under 3.1 to read as follows:

SwRI-NDTR Form No. 17-29, revision dated 07-31-75 Add the following to 3.

(3) Nuclear Regulatory Commission (NRC) IE Bulletin No. 80-13 dated May 12, 1980.

Change the second paragraph of 6.1.2 to read as follows:

ca U. Resolution shall be considered adequate' when the combination of access, lighting, and angles of vision can resolve a .'001 inch diameter wire placed adjacent to the examination area.

Rationale for deviation:

This change is necessary to incorporate the technical requirments of NRC IE Bulletin No. 80-13, and to provide the examiner with the appropriate data form for this examination.

APPROVALS Technical Reyww:

SA /~ M D -

Date:4fe #

T~) y Sg.k !kAwh>

f 9 33 Verbal Approval Given? O Yes 3 No A Manager of Q.A.: Date: Cognikant Director: Date:

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SwRI FORM FE45 ff 1 t s'. ) f. i IP86-215-8 Rev. O 4

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APPENDIX B CERTIFICATES OF PERSONNEL QUALIFICATIONS

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APPENDIX B-CERTIFICATES OF PERSONNEL QUALIFICATIONS Table of Contents I Personnel VT Pge Avalon, R. II B-1 Heineaeier, W. III B-2 Morton, V. II B-3 B-1 m

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. SOUTHWEST RESEARCH INSTITUTE

.., y NONDESTRUCTIVE EXAMINATION g~ STATEMENT OF CERTIFICATION The onesear of me ossemnene et angmeanne servesse, ouemy As wanee s,semme one angmeanng osamen. carense me Ronald Avalon  ;, m . t,,, II in vie,se reenig iv73. , ,me VT-1. VT-2.

VT-3. VT-4 i.e,,,,,,,se,,, me,esueemenes et swas Nueteer Quadey As wanee Preseewe 11-2 Menmen 2.

ce,en,,,,,y,,me,s, Certifica lion valid only while employed by SwRI h > >n .,

-- usesser, n w1, fs'ayw n,i 1 3fnL t1M wr"~~ '-

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sousTioN. TnA NesG ANo exPenisNcs nesTonY EDUCATION: NAASE YEAAs DEGRgg TRAINING (2h memos one level:

,*gn seneet Hinh1mada H.S. (Tx) 4 GRAD oess w . 8/14/81; 11/1/84 l 4 San Antonio College 2 NO Newe: 12: taeos. SwRI userriensetsw Premed Also: Memphis State University 2 NO I

oensenenvesmys ni: 09/24/79 p,e. eve Nos e,senense sie osse ver ou.n eeni:

rneine-musinesmeanasemmeune l.4 __menesseesserieneeinime mean man .nin.e ev e.enomen. som.w on n., n goo, C" *

• noen eserves amuseenseuss, wie emer Nos mamees see ines asu wenio mis meshoel.

VISUAL ACUITY ANo Colom PERCEPT 1oM The mehneuelle sameWe of resuling Jaeger Number 1 lessere et 12 inches, one le cemette of reading sneden Numter 30 lettere et e oestense of 20 feet. In et least one eye (useng corresolve lensee if seessnee below). and een sleeinguson ene diNoreneste contreet benseen ceters useo en trHe memes Cerr. Carr.

Deen mee. Verones by asse Reg. Ventlee av 10/25/84 No HeidiGutierrezlla 09/24/85 No Heidi Cutierrez ///

9/24/86 No Heidi Gutierrez/ W n-MosT RECENT EXAMINATION GRAots CERTiplCATIoM history! THis LEVEL seeres Wagne cate oen 80.00 .33-1/3 in,em Camaceeen: 08/24/81 see no: 96.00 .33-1/3 n e,,,neseen 11/06/84 p, een. 94.00 .33-1/3 n ,,n,e,,en.

Como ene. 90.00 1.00 noe neseen mm.enesten oe., 11/01/84 4,Nsv / 9sN/ n oe,,,,,e,,,n.

gemeenenee t,,ei ne:

E.H. RussCher 82ltfM ek atuanas s ni p.m QA-42 0 B-1

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SOUTHWESTRESEARCH INSTITUTE NONOESTRUCTIVE EXAMINATION l STATEMENTOF CERTIFICATION l The vene rvesMme. Omahy Asamenes Sysemes and Oluisium.sendhemat William Heinemeier ingmasand eu tsusimin visedTeesselvf), essnesses -1. VT-2. VT-3. VT-4 h assadamen unh to sagtuneessef Sedu Nasisar Gismer Asmannes Pessnese 113.

casenessun w s Certification valid oniv while -loved by SwRI aghedem osen _ 02/15/28 m,ise //

osass 1Ill*

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NUCLEAR REGULATORY COMMISSION INSPECTION AND ENFORCEMENT BULLETIN NO. 80-13 '

( . . . . _ . .

SSINS No.: 6820 Accession No.:

UNITED STATES 8002280661 NUCLEAR REGULATORY CDP 9tISSION -

OFFICE OF INSPECTION AND ENFORCEMENT WASHINGTON, D.C. 20555 May 12,1980 IE Bulletin No. 80 CRACKING IN CORE SPRAY SPARGERS Description of Circumstances: ,

Instances of cracking in core spray spargers have occurred at two SWR facilities.

This trend indicates a need for more intensive inspection of these components during subsequent refueling outages.

Oyster Creek Nuclear Generatina Station Jersey Central Power and Light Company notified the NRC on October 18, 1978, that a crack had been found in Core Spray Sparger System II during remote visual inservice inspection at their Oyster Creek Nuclear Generating Station. .

The crack was located at 208' azimuth and extended at least 180* circumferen- l tially around the sparger. An evaluation of the event by the licensee postu-lated that deformation of the sparger had occurred during fabrication and installation which led to cracking by Intergranular Stress Corrosion Cracking (IGSCC) during service in the GWR environment. A temporary repair was effected l by installing a clamp assembly over the crack. The licensee's analysis indicated that the crack had relieved the. stresses present and therefore precluded further cracking. The NRC safaty evaluation permitted operation until the next refueling outage and required inspection of the sparger at that time.

The NRC was informed by the Jersey Central Power and Light Company on January 16, 1980 that further cracking was discovered in the core spray spargers during an inservice inspection conducted in conjunction with the refueling outage. A total of twnty-eight cracks 0.001 to 0.002 inches in width and of varying lengths wre identified in both core spray spargers. The licensee stated that they believed the majority of additional cracks were present earlier and not discovered during the 1978 inspection due. to inspection equipment limitations. Near term repair consisted of the application of nine additional clamp assemblies in areas of the spargers where cracks were visually observed on the accessible portion of the sparger and UT indications were present in the inaccessible portion of the sparger and in the junction box region. The licensee analyzed the flow characteristics of the spargers and determined that adequate flow distribution would be maintained if thru wall cracking .005 inches wide and 180* in length were present. The licensee stated that the installation of the clamps would assure the sparger would maintain its physical integrity and remain in place.

'IE Bu11 tin No. 80- 13 M y l'2, 1980

Page 2 of 3 '

The repair measures proposed were determined by the NRC to be adequate until the following refueling' outage. The NRC evaluation stated that actions should b3 taken to develop and install an improved replacement system at the following refueling outage.

• I i Pilaria Nuclear Power Station i .

1 On January 31, 1980 the Boston Edison Company (BEco) informed the NRC that

• 3 five indications in the upper core spray sparger and two indications on the lower core spray sparger at the Pilgrim Nuclear Power Station were identified during remote visual inservice inspections. The indications were confirmed as 1

cracks after hydrolasing and brush cleaning. The licensees. evaluation indicated 4

that the sparger will retain structural integrity throughout the next cycle, although core spray flow distribution may be affected due to through-wall

] cracks. However, core spray flow delivery to the shroud interior would not be 4 expected to decrease. A loose parts analysis was presented which addressed

{ (1) corrosion, (2) flow blockage, and (3) control rod interference.

1 To support power operation in Cycle 5 with the core spray sparger in its

{ present condition, SEco.has reanalyzed ECCS taking credit only for core spray

reflood, taking no credit for core spray heat transfer. The submission by j BEco is currently under review by the staff. The analysis is expected to j cover a full spectrum of core spray failures. It is expected that the limiting condition will be the failure of recirculation suction line. A MAPLHGR limit I' reduction will likely be imposed during Cycle 5 to compensate for the assump-i tion of no core spray heat transfer.

J ,

i Based on results from other sparger inspections and previous pipe cracking I J experience, cold work and sensitization during fabrication and installation stresses are considered to be the major factors in causing the observed cracks j at the Pilgrim Station. The cracks are hypothesized to be initiated and j propagated by intergranular stress corrosion (IGSCC).

t i A meeting was held with representatives from GE in Bethesda, Maryland on M:rch 13, 1980 to discuss core spray spirger cracking at BWRs. At the meeting i

GE provided the following information:

1

, 1. In February 1979, GE issued to BWR licensees Service Information Letter

] (SIL) No. 289 that recommended inspection of the core spray spargers for '

i visual indications of cracking. To date,19 of 21 plants inspected have i no observed cracking. Cracks have been found at 2 facilities (Pilgrim j and Oyster Creek).

. 2. The key contributors to IGSCC vary from plant-to plant, although stresses i from cold work and sensitization during fabrication and installation are l considered prime factors leading to IGSCC at Pilgrim and Oyster Creek.

8ecause the cause of cracking is not yet confirmed by metallurgical analysis, GE is developing tooling to extract sparger samples to verify

{ the postulated cracking mechanism.

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Enclosure 1 IE Bulletin No. 80-13 Date: May 12, 1980 Page 3 of 3

3. GE is evaluating methods of improv'ing the sparger inspection techniques, and is considering a modification to the SIL, if warranted.

The staff agreed that improved inspection techniques should be developed and .

metallurgical examinations should be performed to determine the mode of failure.

The staff asked GE to keep them informed of progress in these areas.

Actions to be Taken by Licensees:

For all boiling water power reactor facilities with an operating license:

1. At the next scheduled and each following refueling outage until further notice, perform a visual inspection of the Core Spray Spargers'and the -

segment of piping between the inlet nozzle and the vessel shroud. Remote underwater TV examinations are acceptable if adequate resolution can be demonstrated. The viewing in situ of 0.001 in, diameter fine wires is n- considered as an acceptable means of demonstrating suitable resolution of the TV examinations. Such techniques as the use of oblique lighting, and 3

the ability to light from each side independently are considered useful

• _, in enhancing the image of cracks to facilitate detection.

. 2. In the event cracks are identified during examination of the core spray sparger system, the location and extent of the indications shall be recorded and reported to the NRC. Supplementary examinations using volumetric methods may be performed to aid in characterizing the extent of cracking in nonvisible locations. An evaluation shall be submitted to

z. NRR for review and approval prior to return to operation.

o 3. Any cracking identified in the core spray cooling system shall be reported M

to the Director of the appropriate NRC Regional Office within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of identification.

~ *

4. A written report of the results of the examinations including any corrective 3 measures taken shall be submitted within 30 days of the completion of the examination to the Director of the NRC Regional Office with a copy to the NRC Office of Inspection and Enforcement, Division of Reactor Operations Inspection, Washington, D. C. 20555.

Approved by GAO, B180225 (R0072); clearance expires 7-31-80. Approval was given under a blanket clearance specifically for identified generic problems.

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