IR 05000321/1987006

Insp Repts 50-321/87-06 & 50-366/87-06 on 870302-05.No Violations or Deviations Noted.Major Areas Inspected:Review of Actions Taken to Implement Generic Ltr 84-11 Re Insps of BWR Stainless Steel Piping

ML20214L064
Person / Time
Site:	Hatch
Issue date:	05/08/1987
From:	Berlinger C, Cortland P, Menning J NRC, Office of Nuclear Reactor Regulation
To:
Shared Package
ML20214L042	List: IR 05000321/1987006 ML20214L041 ML20214L051 ML20214L059
References
50-321-87-06, 50-321-87-6, 50-366-87-06, 50-366-87-6, GL-84-11, NUDOCS 8705290180
Download: ML20214L064 (10)

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orec oq UNITED STATES

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[( T c( [k 5{j /g j g NUCLEAR REGULATORY COMMISSION WASHINGTON, D. C. 20555

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Report Nos.: 50-321/87-06 and 50-366/87-06 Licensee: Georgia Power Company P. O. Box 4545 Atlanta, Georgia 30302

Docket Nos.: 50-321 and 50-366

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License Nos.: DPR-57 and NPF-5

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Facility: Edwin I. Hatch Nuclear Plant, Units 1 and ?

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Inspection Conducted: March 2-5, 1987

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Inspector: 8N Paul Cortland Date Signed-hny 7 ohn ning Date Signed SUMMARY P

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Scope: This routine announced inspection involved a review of actions taken to implement Generic Letter 84-11 concerning inspections of boiling i water reactor stain 1ers steel piping.

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Results: No viola ons or deviations were idedB fie Approved by: (24 U ^D I %- i h

Carl H. Berlinger, Cyf Date Sip 6ed

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Generic Comunications Branch Division of Operational Events Assessment Office of Nuclear Reactor Regulation G705290100 870526 1 PDR ADOCK 050

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REPORT DETAILS Persons Contacted Licensee Employees H. Nix, Plant Manager - Hatch

• T. L. Elton, Plant Engineering Supervisor D. S. Read, Manager, Plant Support

• R. L. Hayes, Independent Safety Evaluation Group Supervisor

• G. M. Creighton, Procedure Specialist

• T. Powers, Manager, Engineering Support

• Dedrickson, Assistant to Vice President

• T. Huckaby, Senior Plant Engineer Other licensee employees contacted included technicians, operators, mechanics, security force members, and office personnel Southern Company Services

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• G. Lofthus, lead Inspector

• G. R. Brinson, Engineer NRC Personnel I

• P. Holmes-Ray, Senior Resident Inspector - Hatch

• P. Cortland, Metallurgist, Office of Inspection and Enforcement l

• J. E. Menning, Reactor Inspector, Division of Reactor Safety

• Attended exit interview l Exit Interview The inspection scope and findings were sumarized on March 5,1987, with those persons indicated in paragraph I above. The inspectors described

~ the areas inspected and noted the preparation and cooperation of the licensee and Southern Company Services. No items of nonconformance or l deviations were identified. The licensee did not identify as proprietary any of the materials reviewed by the inspectors during this inspectio . Inspection Scope and Objectives Background Inspections conducted at several PWR facilities as a result of IE Pulle-tins 82-03, Revision 1, and 83-0? and the NRC August 76 1983 Orders revealed intergranular stress corrosion cracking (IGSCC$ in larae diameter recirculation and residual heat removal piping systems. The results of these inspections led to an ongoing program for sinflar inspections at all nperating BWRs. Repairs, analysis, and additional surveillance may be required to ensure the integrity of the susceptible piping in those areas where IGSCC is discovered or indicated by nondestructive examinatio I

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, Basic Requirements The items to be verified have been divided into several areas:

inspection program, competence of ultrasonic (UT) examiners, leak detection, performance of inspection and subsequent actions. GL 84-11 was issued on April 19, 1984, and while almost all of the affected operating BWP plants have an inspection proaram, the inspec-tions may not be complet Some licensees have replaced all or a portion of the piping suscepti-ble to IGSCC; some licensees did not install IGSCC susceptible material. Documentation of the inspection program and plans for subsequent activity should be limited to the remaining susceptible piping. Installation of the new pipe or examination of the remaining pipe or both should be used to verify the competence of UT examiners and performance of inspectio The inspection requirements are contained in NRC Temporary Instruc-tion 2515/89, " Inspection of Licensee's Actions Taken to Implement Generic letter 84-11: Inspections of Boiling Water Peactor Stainless Steel Piping."

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4 Inspection Program Hatch Nuclear Plant, Unit 2 replaced their susceptible piping in 1984 and this portion of the inspection does not appl The licensee program should require the inspection of 20% of the welds not inspected previously (four minimum) for each pipe siz Letter NED-84-506 to NRC from Georgia Power Company (GPC) dated September 26, 1964, sutject: Response to NRC Recuest for Additional Information on 1984 Refueling Outage Inspection Program listed the welds to be examined. For example, there are forty 12 in, recircu-lation line welds and 21 were examined in 1982. 20% of the remaining 19 would be four welds and GPC decided to inspect six. The program requirements were satisfied for all sizes, Tb,e licensee program should require the inspection of 20% of the weldspreviouslyinspectedandfoundnottocontaincracks(two minimum) for each pipe siz Letter NED-84-506 lists the welds to be reexamined. For example, there were twenty-one 12 in, recirculation line welds examined in 1982. 20% percent of these would be 4.2 and GPC decided to inspect five. The program requirements were satisfied for all size The licensee program should require the inspection of all unrepaired welds previously found to contain cracks or indications of crack Letter NED-84-506 identified one 22 in, recirculation line weld with an existing crack to be examined. The weld number was IB31-1RC-22AM-IPC-1, a pipe to branch connection. The inspection on November 17, 1984 indicated that the most severe crack was about 18%

of the pipe wall thickness and this was subsequently accepted by GPC after analysi .

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- The licensee program should require the inspection of all weld overlays on top of welds containing cracks or indications or cracks l longer than 10% of the circumferenc Letter NED-84-506 identified six welds with overlay to be examined, The licensee program should require the inspection of all welds treated by the induction heating stress improvement (IHST) technique l and not previously examined after IHSI treatmen i There was not any IHSI perfonned prior to the 1984 outage. Letter SL-461 2572N dated March 10, 1986, sub.iect: Hatch Unit 1, Inservice Inspection of Class 1 Stainless Steel Piping and Components - 1985 Maintenance / Refueling Outage reported that 107 welds were given the IHSI treatment during the 1985 outage and subsequently examine % The licensee program should require a visual examination for leakage of the reactor coolant piping during each plant outage in which the containment is deinerte The procedure data package HNP-6901-7 completed January 10, 1985 shows pressure and leakage testing with satisfactory result Finding No items of nonconformance or deviations were identifie . Competence of Ultrasonic Testing (UT) Examiners The licensee program should require qualification by a formal perfor- ,

mance capability demonstration test such as that being conducted at the Electric Power Research Institute (EPRI) Nondestructive Examina-tion (NDE) Cente Letter NED-84-506 indicates that the Level II and III inspection personnel who will perform data evaluation have been qualified in the detection of IGSCC by the EPRI NDE Center. NDE personnel under

! contract to the inservice inspection group, Southern Company Ser-

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vices, who have qualified at the EPRI NDE Center in the detection and interpretation of IGSCC may also perform examinations and evalua-tions, as appropriate. In addition, Southern Company Services has several Level II and III personnel qualified through the EPRI NDE Center for the sizing of cracks. Those personnel and any subcontrac-tor personnel similarly qualified can be used for sizing of IGSCC indication depth should reportable indications be observe The licensee program should require personnel who are perfonning as SNT-TC NDT Level I examiners to demonstrate field performance capa-bility. As an alternate, document that Level I examiners work only with or under the direct supervision of Level II or III personne The Level I examiners at Units 1 and ? worked under the direct supervision of Level II and III personnel. The Level I examiners did not work independentl ;

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. Finding No items of nonconformance or deviations wera identifie . Leak Detection and Leakage Limits

, The technical specifications should require a plant shutdown for

inspection and corrective action when any leakage detection systen indicates, within any period of 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, an increase in the rate of unidentified leakage in excess of 2 gpm or its eouivalent.

, For Unit 1, the leakage limits appear in the technical specifications '

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in paragraph 3.6.G.I.b and the shutdown requirements are in 3.6.G.3, per amendment 9 For Unit 2, the leakage limits appear in the technical specifications in paragraph 3.4.3.2.d. per the Confinnatory O Mer of July 8, 1983. Paragraph 3.4.3.1 contains the shutdown g requirements for Unit The technical specifications should reoufre that at least one of the

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leakage measurement instruments associated with each sump shall be operable. The outage time for inoperable instruments shall be

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limited to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> or the licensee shall immediately initiate an orderly shutdow For Unit-1, statements concerning instruments are found in paragraphs 3.6.G.2a and 3.6.G.3 of the technical specification. For Unit 2, paragraph 3.03 of the technical specification contains the shutdown requirement ' Findings.

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No items of nonconformance or deviations were identifie . Performance of Inspection Tra inspection should check three or more pipe sizes to verify that i i

the welds have been inspected by the licensee according to their j program.

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The inspectors reviewed documentation to verify that, as a minimum, welds had been reinspected in accordance with the guidance of Generic Letter 84-11. Welds in the 22 in, recirculation system, 20 in.

i residual heat removal system, and 6 in, reactor water cleanup-system lines were selected for this review.

(1) Enclosure 1 to letter NED-84-605 Inspectioa of Hatch Unit 1 l Recirculation, RHR, and RWCU Piping Welds - 1984 Maintenance /

Refueling Outage was initially reviewed to d0termine what welds j had been reinspected in the piping sizes selected for revie This review revealed that 100% of these welds bad been rein-

spected and they are identified below:

(a) Welds in the 22 in. Recirculation System Lines.

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, Veld Identification Weld Type IB31-IRC-22AM-1 Cap to Pipe IB31-1RC-22AM-1BC-1 Pipe to Branch Connection IB31-1RC-22AM-1BC-2 Pipe to Branch Connection IP31-1RC-22AM-2LU Longitudinal Seam Weld 1831-1RC-22AM-2 Pipe to Cross IB31-1RC-22AM-3 Cross to Pipe IB31-1RC-22AM-3BC-1 Pipe to Branch Connection 1831-IRC-22AM-3BC-2 Pipe to Branch Connection 1831-IRC-22AM d Pipe to Cap 1831-1RC-22BM-1 Cap to Pipe 1831-1RC-22BM-1BC-1 Pipe to Branch Connection IP31-IPC-22BM-1BC-2 Pipe to Branch Connection 1831-1RC-22BM-2 Pipe to Cross IB31-1RC-22BM-3 Cross to Pipe g 1831-IRC-22BM-3BC-1 Pipe to Branch Connection Pipe to Branch Connection

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1B31-1RC-22BM-3BC-2 IB31-1RC-22BM-4 Pipe to Cap (b) Welds in the 20 in. Residual Heat Removal System Lines

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Veld Identification Weld Type 1E11-IRPR-20B-D-1 Tee to Pipe 1E11-1PHR-20B-D-1BC Pipe to Branch Connection IE11-1RHR-208-D-2 Pipe to Elbow IE11-1RHR-208-D-3 , Elbow to Pipe IE11-1RHR-208-D d Pipe to Pipe 1E11-IRHR-208-D-5 Pipe to Valve (c) Welds in the 6 in. Reactor Water Cleanup System Lines Weld Identification Weld Type 1G31-1RWCU-6-D-1 Branch Connection to Pipe 1G31-1RWCU-6-D-2 Pipe to Elbow IG31-IRWCU-6-D-3 Elbow to Pipe IG31-1RWCU-6-D-4 Pipe to Valve IG31-IRWCU-6-D-5 Valve to Elbow 1G31-IRWCU-6-D-6 Elbow to Pipe 1G31-1RWCU-6-D-6BC Pipe to Branch Connection IG31-1RWCU-6-D-7 Pipe to Elbow

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1G31-1RWCU-6-D-8 Elbow to Pipe 1G31-1RWCU-6-D-9 Pipe to Elbow l 1G31-1RWCU-6-D-10 Elbow to Pipe IG31-1RWCU-6-D-11 Pipe to Elbow IG31-1RWCU-6-D-12 Elbow to Pipe 1G31-IRWCV-6-D-13 Pipe to Elbow 1G31-1RWCU-6-D-14 Elbow to Pipe 1G31-1RWCU-6-D-15A Valve to Penetration 1G31-1RWCU-6-D-16 Penetration to Pipe 1G31-IRWCU-6-D-17 Pipe to Elbow 1G31-1RFCU-6-D-18 Elbow to Pipe .

1G31-1RWCU-6-D-18A Pipe to Pipe l 1G31-1RWCU-6-D-19 Pipe to Elbow !

IG31-IRWCU-6-D-20 Elbow to Valve i 5 i

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(2) Individual ultrasonic examination report sheets for one half of the welds . listed in (1) above were subsecuently reviewed to further verify that welds had been examined as reported. The reviewed ultrasonic reports are listed below:

Examination Weld Identification Report Number Date of Report IP31-IRC-22AM-1BC-1 S84H10423 October 31, 1984 S84H10599 November 15, 1984 1831-1RC-22AM-2LU S84H1U132 October 11, 1984 1R31-1RC-22AM-3 S84H1U196 October 17, 1984 S84H10201 October 18, 1984 1R31-1RC-22AM-3RC-2 S84H1U438 November 2, 1984 S84H1U426 October 31, 1984 1R31-1RC-22BM-1 S84H10111 October 10, 1984 s ~ S84H10023 October 6, 1984 S84H10054 October 7, 1984 S84HIU141 October 10, 1984 1831-1RC-22BM-1 S84H10498 November 4, 1984

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1R31-IRC-22BM-IPC-2 S84H10440 November 2, 1984 S84H1U420 November 1, 1984 IP31-1RC-22BM-3 S84H1U110 October 10, 1984 S84H1UO78 October 8, 1984 584H1U115 October 10, 1984 IB31-IRC-22BM-3BC-2 S84H10442 November 2, 1984 S84H10422 November 1, 1984 1E11-1RHR-208-D-1 S84H1U374 October 27, 1984 S84H1U346 October 25, 1984 IE11-IRHR-20B-D-2 S84H1U322 October 24, 1984 584H10321 October 24, 1984 IE11-1RHR-208-D-4 584H10275 October 23, 1984 S84H10535 November 4, 1984 1G31-1RWCU-6-D-1 S84H10305 October 24, 1984 584H10302 October 24, 1984 IG31-1RWCU-6-D-4 S84H10014 October 5, 1984 S84H10037 October 5, 1984 584H10053 October 6, 1984 IG31-IRWCU-6-D-6 S84H10306 October 24, 1984 IG31-IRWCU-6-D-7 584H1U307- October 24, 1984 1G31-IRWCU-6-D-9 584H10342 October 25, 1984 IG31-1RWCU-6-D-11 584H1UO44 October 6, 1984 1G31-1RWCU-6-D-13 584H1U387 October 29, 1984 IG31-1RWCU-6-D-15A S84H10454 November 2, 1984 S84H10389 October 29, 1984 SPAH1U395 October 29, 1984 IG31-IRWCV-6-D-17 584H1U444 October 31, 1984 584H10449 October 31, 1984 584H1U433 November 1, 1984 1G31-IRWCU-6-D-18A S84H10446 October 31, 1984 584H1U451 October 31, 1984 584H1U435 November 1, 1984 1G31-IRWCU-6-D-20 S84H10443 October 31, 1984 584H1U401 October 30, 1984 584H10432 November 1, 1984

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. In addition, an elbow to pump weld IB31-1RC-28A-10 was reexamine Using procedure UT-H-400 Rev. 5 dated September 20, 1984, " Manual Ultrasonic Examination of Full Penetration Welds (Greater than 0.400 in.)", a 34% through-wall indication was identified in report S84H10521 on November 2, 1984 The flaw was sized by the amplitude method and the weld was repaired by overlay cladding. Using proce-dure UT-H-403 Rev. I dated September 20, 1984, " Ultrasonic Examina-tion of Weld Deposited Overlay Cladding", on December 13, 1984, the licensee verified that the weld was acceptabl Unit 2 replaced susceptible piping in the 1984 outage up to the inboard isolation valve. Approximately 230 stainless steel velds were ultrasonically examined after the piping replacemen The inspection should check that at least six of the UT examiners demonstrated their competence prior to examining welds using the 1, essential parameters of their qualified procedure The inspectors reviewed qualification records for UT examiners to determine if all had demonstrated competence prior to examining welds for IGSCC during the Hatch Unit 1 outage that commenced in October

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1984. Review of records for six UT examiners revealed that all had been qualified for IGSCC detection at the EPPI NDE Center and two had been qualified for planar flaw sizing at the Center as shown belo EPRI IGSCC EPRI Planar UT Examiner Company Detection Qua Flaw Sizing Qua J. Southern Company Services July 1, 1983 December 1, 1983 K. Southern Company Services March 23, 1984 R. Sonic Systems International August 23, 1984 Sonic Systems International November 8, 1983 Sonic Systems International November 8, 1983 Nuclear Energy Services August 12, 1983 August 16, 1984 Finding No items of nonconformance or deviations were identifie . Subsequent Activity The licensee program should provide for scope expansion and additional ,

inspection when new cracks are found or existing cracks grow to an unac- l ceptable siz '

Letter NED-84-280 from GPC to NRC dated May 31, 1984, sub,iect: Hatch Nuclear Plant Unit 1 Inspection Program - 1984 Refueling Outage, indicated that if additional IGSCC was detected in the samples represent- 1 ing the welds not previously inspected or the previously inspected welds not found to contain IGSCC, the sample size would be increased in accor-dance with ASME Section XI, IWB-2430 as defined in NRC Bulletin 83-0 i Subsequently, letter NED-84-605 from GPC to NRC dated December 10, 1984, I subject: Hatch Unit 1, Inservice Inspection of Stainless Steel Piping -

1984 Refueling Outage, noted that reportable crack-like indications were observed in several of the stainless steel piping welds in the recircula- ,

tion and residual heat removal system Consequently, the scope of the i

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examinations was expanded to include the examination of 100% of the 109 circumferential and branch cornections in these system An example of scope expansion is contained in "NDE of Selected Class 1 and 2 Components, Hatch Unit 1 Fall 1984 Refueling Outage Examination Report."

Weld IB31-1RC-28A-2 was ultrasonically examined and found to have a reportable indication. After an91ysis, the indication was accepted provided that this weld be examined during the next three inspection period No items of nonconformance or deviations were identifie . Documents Reviewed Correspondence from Georgia Power Company to Nuclear Reculatory Comission

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Southern Company Services Baseline Examination Plan for Hatch Unit Replacement Piping dated May 21, 1984

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NED-84-280 dated May 31, 1984, subject: Hatch Unit 1. Inspection Program - 1984 Refueling Outage NED-8a-506 dated September 26, 1984, sub.iect: Hatch Unit 1 Response to NRC Request for Additional Information on 1984 Refueling Outage Inspection Program NED-84-605 dated December 10, 1984 Hatch Unit 1 Inservice Inspection of Stainless Steel Piping - 1984 Refueling Outage Enclosure I to NED-84-605 Inspection of Hatch Unit 1 Recirculation, RHR, and RWCU Piping Welds - 1984 Maintenance / Refueling Outage Nondestructive Exemination of Selected Class 1 and 2 Component Including Baseline Examination of Replacement Piping for Edwin Hatch Nuclear Plant Unit 2 SL-461 2572N dated March 10, 1986, subject: Hatch Unit 1. Inservice

. inspection of Class 1 Stainless Steel Piping and Components - 1985 Maintenance / Refueling Outage Edwin I. Hatch Nuclear Plant Procedures HNP-6907-1 Procedure Data Package for 1831 and IE11 completed January 10, 1985 UT-H-400 Rev. 5 dated September 20, 1984, " Manual Ultrasonic Examination of Full-Penetration Welds (Greater than 0.400in.)"

UT-H-401 Rev. 4 dated September 20, 1984, " Manual Ultrasonic Examination of Full Penetration Welds (0.2 - 0.4 in.)"

UT-H-403 Rev. I dated September 20, 1984, " Ultrasonic Examination of Weld Deposited Overlay Cladding"

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, UT-H-450 Rev. O dated September 20, 1984, "0ualification of Manual Ultrasonic Instruments" UT-H-460 Rev. O dateo September 70,1984, " Ultrasonic Thickness Examination Procedure" ,

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UT-H-470 Rev. O dated September 2, 1984, " Planar Flaw Sizing

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Procedure"

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c. Miscellaneous Coordination Plan for NRC/EPRI/BWROG Training and Qualification Activities of NDE Personnel dated June 22, 1984 EPRI Registry of Qualified Personnel for UT of IGSCC lg EPRI Certificates of Manual. Qualification for IGSCC Detection i

EPRI Certificates of Manual Qualification for Planar Flaw Sizing

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