Text

(Returned to DCD) Braidwood Station, Unit 1, Steam Generator Tube Inspection Report for Refueling Outage 15
	ML12251A359
Person / Time
Site:	Braidwood
Issue date:	08/17/2012
From:	Enright D; Exelon Generation Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
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ExelonGeneration+

3100 6agoi Ami &*o Sut 4

'mmmIIne, 3.UO?.61041901 August 17, 2012 BW 120080 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 2.0555-0001 Braidwood Station, Unit 1 Facility Operating License No. NPF 72 NRC Docket No. STN 50-456

Subject:

Braidwood Station, Unit 'i Steam Generator Tube Inspection Report for Refueling Outage 15 In accordance with Technical Specification 5.6.9, "Steam Generator (SG) Tube Inspection Report,"

Exelor, Generat'n Company, LLG is repc hatirg the results of the SG inspections that were completed '-r-ir j the ,raidwood Station, Unit 1 Refueling Outage 16 (Al R16). The att.ched report i.* a!so bl- ,2bmitted in accordance with the rtquirements of th3 American Society of Mechanical Enaoin 'E)ji Zz,'ler and Pressue Vessel Code, 2001 Edition through 2003 Add.enda, Section

>,"RP' Inse,.jice Inspection of Nuclear Power Plant Components," Article IWA-6000, "lec: . r Recports," and Paragraph 11-890.2.3, "Reporting" of ASME.Section V "Nondestructive 2xarinai,, , ,.-%rticle 8 - Appendix li, "Eddy Current Examination of Nonferromagnetic Heat Exchanger Tubing," 2001 Edition through 2003 Addenda.

If there are any questions regarding ;.his submittal, please contact Mr. Chris VanDenburgh, Regulatory Assurance Manager, .at (815) 417-2800.

Respectfully, Daniel J. En right Site Vice President Braidwood Station

Attachment:

Braidwood Station, Unit 1 Steam Generator Tube Inspection Report Sixteenth Refueling Outage (Al R1 6) cc: NRC Regional Administrator.- Region III NRC Senior Resident Inspector- Braidwood Station Illinois Emergency Management Agency - Division of Nuclear Safety

Exelon Nuclear BRAIDWOOD STATION UNIT 1 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: July 29, 1988 STEAM GENERATOR TUBE INSPECTION REPORT SIXTEENTH RIEFUEL!NG OUTAGE (Al R1 6)

April 2012 Exelon N!,:lear 430C Winfield Road Warronville, IL 60555 Document Completion Date: July 31, 2012

TABLE OF CONTENTS

1.0 INTRODUCTION

2.0

SUMMARY

3.0 CERTIFICATIONS 3.1 Procedures/Examinations/Equipment 3.2 Personnel 4.0 EXAMINATION TECHNIQUES AND EXAMINATION SCOPE 4.1 Examination Techniques 4.2 Steam Generator Inspection Scope 4.3 Recording of Examinat'or Data 4.4* Witness and Verification of Examination 5.0 EXAMINATION RESULTS 5.1 Edd;,, Currn" I, pection 5.2 Other ;nspeciion 3esuiLs 6.0 RESULTS OF CONDITION MONITORING

6. 1 Fan Bar Wear 6.2 Lattice Grid Wear 6.3 Foreign Object Wear 7.0 TUBE PLUGGING

SUMMARY

8.0 DOCUMENTATION 9.0 FIGURES/TABLES/ATTACHMENTS

1.0 INTRODUCTION

Braidwood Station Unit 1 operates with four Babcock & Wilcox Replacement Steam Generators (SGs) in the four loop pressurized water reactor system. The SGs each contain 6633 Thermally Treated Alloy 690 (A690TT) U-tubes that have a nominal diameter of 0.6875 inches and a nominal thickness of 0.040 inches. The tubes are supported by stainless steel lattice grid structures and fan bars. The tubes are hydraulically expanded into the full depth of the tubesheet. Main Feedwater enters the SGs above the tube bundle through a feedring and J-tubes. The SG configuration is shown in Figures A.1 and A.2. The replacement SGs were installed at the end of Cycle 7, in Fall 1998.

In compliance with Braidwood Station Technical Specification (TS) 3.4.19, Steam Generator (SG) Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (B&PV)

Code Section Xl 2001 Edition through 2003 Addenda, IWB 2500-1, Examination Category B-Q, Item B16.20, SG eddy current examinations were performed during the Braidwood Station Unit 1 sixteenth refueling outage (Al R1 6).

The inspections were *'erformed consistent with the Electric Power Research Institute (EPRI) "PWR Steam Generator Examination Cuidelines," Revision 7, and Nuclear Energy Institute NEi 97-06, "Steam Ge.-;erator Progr.-m Guidelines," Revision 3. The inspections were conducted from April 21, 201? through April 28, 2012 by the Westinghouse Electric Company (Westii(jhouse). The Al Ri 6 refueling outage was completed on May 19, 2012. The following inspections were performed during this outage (TS 5.6.9.a).

Fu",-lenqth bobbin coil eddy current examination of all in-service tubes o +Point TM inspection of all. hot leg E,-rn. & Dings greater than 2.0 Volts o D.iagnostic -PointTM eddy current bas,.d on bobbin coil eddy current results Visual ,nrlpsction of all existing tube plugs V

Visua.l inspection of all newly installed tube plugs The Bra!dwood Unit 1 SGs are currently in the 144 Effective Full Power Month (EFPM) inspection period following SG replacement, per TS 5.5.9.d.2. The Braidwood Unit 1 SGs have operated 137.588 EFPM within the 144 EFPM inspection period at refueling outage 16. Refueling outage 16 was the inspection outage nearest the end-point of the 144 EFPM period. The mid-point inspection outage was conducted during refueling outage 12 (69.9 EFPM within the inspection period).

2.0

SUMMARY

The guidance in Revision 7 of the EPRI PWR Steam Generator Examination Guidelines (i.e., EPRI Guidelines and applicable interim guidance) was used during the inspection.

A degradation assessment was performed prior to the inspection to ensure the proper EPRI Guidelines Appendix H, "Performance Demonstration for Eddy Current Examination," or Appendix I, "NDE System Measurement Uncertainties for Tube Integrity Assessments," qualified inspection techniques were used to detect any existing and potential modes of degradation. Each technique was evaluated to ensure that the 1

detection and sizing capabilities are applicable to the Braidwood Station Unit 1 site-specific condition in accordance with the EPRI Guidelines.

All data analysts were qualified to Appendix G, "Qualification of Nondestructive Examination Personnel for Analysis of NDE Data," of the EPRI Guidelines (i.e., Qualified Data Analyst (QDA)). All data analyst and acquisition personnel satisfactorily completed site-specific training and testing prior to beginning examinations. An independent QDA process control review was employed to randomly sample the data to ensure that the analysis resolution process was properly performed and that the field calls were properly reported. An analysis feedback process was implemented that required the data analysts to review their missed calls and overcalls on a daily basis.

The modes of tube degradation found during Al Rf16 were fan bar wear, lattice grid wear and foreign object wear. Pursuant to EPRI Guideline Section 3.7, "Classification of Sample Plan Results," the results of the inspection were classified as inspection category C-1 for the 1A, 1B, 1C and 1D SGs. No additional scope expansion was required since 100% full-length bobbin eddy currsnt inspection was already being performed in all four SGs. There were no scanning limitations during the eddy current examinations.

As a result of the eddy current inspection of the SGs, only one tube was removed from service by mechanical tube plugging. The tube was removed from service due to having wear associated with secondary side foreign objects.

Table 2.1, "Equivalent Tube Plugging Level," provides the total tube plugging history and equivalent plugging levels to-date for the Braidwood Station, Unit 1 SGs. Table 2.2

'Tubes Plugged During Al R44," provides the total number of tubes plugged during the current ouiage by degradati'- mode.

Table 2.1 Equivalent Tu ,_jing Level (TS 3.6.9.f and 5.6.9.h)

I A I SG I SG C I SG D Total Tubes Plujged at Factory 1 2 0 0 3 Tubas Plugged in A1R08 1 0 0 0 1 Tubes Plugged in AIR10 8 10 3 0 21 Tubes Plugged in ARll 0 2 2 1 5 Tubes Plugged in AlR12 11 17 0 0 28 Tubes Plugged in AIR13 6 8 7 0 21 Tubes Plugged in A1R14 0 1 4 0 5 Tubes Plugced in Al R16 1 0 0 0 1 Total Tubes Plugged 28 40 16 1 85 Total Tubes Plugged (%) 0.42% 0.60% 0.24% 0.02% 0.32%

Note: Steam Generator Inspections Were Not Performed During Al R09 or Al R1 5.

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Table 2.2 Tubes Plugged During Al R16 (TS 5.6.9.b and TS 5.6.9.e)

Mode ofD gradation ::ISG:

ý. A SG B SG C SG D, Total Fan Bar Wear 0 0 0 0 0 Lattice Grid Wear 0 0 0 0 0 Foreign Object Wear 1 0 0 0 1 Total Tubes Plugged in A1 R16 1 0 0 0 1 3.0 CERTIFICATIONS 3.1 Procedures/Examinations/Equipment 3.1.1 The examination and evaluation procedures used during the eddy current inspection were approved by personnel qualified to Level III in accordance with the 1995 Edition of the American National Standards Institute (ANSI)/ASNT CP-1 89, "ASNT Standard for Qualification and Certification of Nondestructive Testing Personnel." For previously approved certifications, the 1991 edition of the American National Standards Institute (ANSI)/ASNT CP-1 89 and the 1984 Edition of the American Society fcr Nondestructive Testing (ASNT) Recommended Practice SNT-TC-1A, "Personnel Qualification and Certific'iton in Nondestructive Testing." Exelon Generation Company, LLC (EGC) procedure ER-AP-335-039, "Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing," Revision 6 and EGC 'rocedure ER-AP-335-040, "Evaluation of Eddy Current Data for Steam Gernerator Tubing," Revision 7, were used for data acquisition and analysis.

3.1.2 The examinatio, is, equipment and personnel were in compliance with the requirements of Exelon and Westinghouse Quality Assurance Programs for Inservice Inspection; Braidwood Station TS 5.5.9; 2001 Edition through 2003 Addenda of ASME Boiler and Pressure Vessel Code Section Xl, "Rules for Inservice Inspecticn of Nuclear power Plant Components," and Section V, "Nondestructive Examination"; EPRI PWR SG Examination Guidelines, Revision 7; and NEI 97-06, "Steam Generator Program Guidelines," Revision 3.

3.1.3 Certification packages for examiners, data analysts, and equipment are available at Braidwood Station. Tables A.1 and A.2 of Attachment A list all personnel who performed, supervised, or evaluated the data during this SG inservice inspection.

3.1.4 CoreStar International Corporation OMNI-200 MT Remote Data Acquisition Units (RDAUs) with Westinghouse SGPS 12.00.00 Rev., Version 5033 computer software were used to acquire the eddy current data. Primary and secondary analysis was performed with Westinghouse ANSER 12.00.00 Rev 11 Version 504 computer software.

3.1.5 The bobbin coil examinations of the SGs were performed with Westinghouse 0.560 inch diameter probes. For low row U-Bend tubing, a 3

0.540 inch diameter probe was utilized to achieve the complete full tube examination in tubes where there was difficulty using the 0.560 inch diameter probe.

3.1.6 The rotating coil examinations were performed with Zetec 0.560 inch diameter three coil +PointTM probes for straight section tubing. The coils within this probes were a 0.115 inch diameter pancake coil, a 0.080 inch diameter pancake coil and a standard +PointTM coil. For diagnostic evaluation of indications within the U-Bend tubing, a Zetec 0.520 inch diameter probe was used with a single standard +PointTM coil.

3.2 Personnel 3.2.1 The personnel who performed the SG eddy current inspections were qualified to Level I and Level IIcertification in accordance with the 2001 Edition through 2003 Addenda of ASME Section XI, IWA-2300. The Level I personnel performed the inspections under the direct supervision of Level II or Level III personnel. A list of the certified eddy current personnel who performed data acquisition for the examination is contained in Table A.1 of Attachment A.

3.2.2 The personnel who performed the SG eddy current data analysis were qualified to a minimum of Level II, with special analysis training (i.e., Level H*A) in accordance with the 2001 Edition through 2003 Addenda of ASME Se( 'on X;, IWA-2300. A list of the certified eddy current personnel who perft med data analysis for the examination is contained in Table A.2 of Attacnment A.

3.2.3 All SG eddy current data analysts were qualified in accordance with EPRI Appendix G for Qualified Data Analysts (QDAs). In addition, all data analysts were trained and tested in accordance with a site specific performance demonstration program in both the bobbin coil and +PointTM inspection data analysis. Resolution analysts were also trained and tested specifically for the performance of data resolution. All analysts were required to achieve a minimum score of 80% probability of detection with a 90% confidence level on the practical examination, and a minimum score of 80% on the written examination prior to analyzing data.

3.2.4 All SG eddy current data acquisition personnel were trained and tested in accordance with a site specific performance demonstration program. The data acquisition operators were required to achieve a written test score of 80% or greater prior to acquiring data.

3.2.5 The SG eddy current analysis was subject to two independent analyses.

Primary analysis was performed by an automated data screening analysis system as described in the EPRI Guidelines, Revision 7. The analysis system was operated in the interactive mode and had successfully passed the EPRI Automated Analysis Performance Demonstration Database (AAPDD). Automated analysis was also required to successfully pass the site specific performance demonstration practical examination prior to analyzing field data. Secondary analysis was 4

performed manually. Discrepancies between the two parties required Level III concurrence between both parties for final resolution.

3.2.6 Two independent SG eddy current Level III QDAs who were not part of the resolution team were employed to serve as a process control reviewers, in accordance with EPRI Guidelines. The Independent Level III QDAs randomly sampled the data to ensure the resolution process was properly performed and that the field calls were properly reported. The Independent Level III QDAs also provided data acquisition oversight to ensure that the data collection process was in compliance with appropriate procedures, that all essential variables were set in accordance with the applicable Examination Technique Specification Sheet (ETSS) and to provid6 a data quality check of acquired data. The Independent Level III QDAs reported directly to the EGC Nondestructive Examination Level Ill.

3.2.7 Personnel from Mistras, N.D.E. Technology, INC., Tricen Technologies, Infineddy, LLC, Mainternance arnd Inspection Services, INC., and Westinghouse performed data analysis.

3.2.8 Per'onnel from System One and Westinghouse performed data acquisition.

3.2.9 Personnel qualified as data analysts performed real time data quality verifi.ations.

4.0 EXAMINATIO. I TECHiQUES AND EXAMINATION SCOPE Ali )ddy current examination techniques used were qualified in accordance with 1 x H or Appendix I of the EPRI PWR SO Examination Guidelines. Each Apper,u examination technique was eva:uatec to be applicable to the tubing and conditions of the Braidwood St:,'.on Unit 1 SGs.

4.1 Examinitcn Techniques (TS 5.6.9.c) 4.1.1 The bobbin coil examinations were performed with a 0.560 inch diameter probe as described in Section 3.1.5 of this report. For low row U-Bend regions where there was difficulty using the 0.560 inch diameter probe, a 0.540 inch diameter probe was utilized to achieve the full tube inspection.

Nominal probe inspection speed was 40 inches per second for tubes in row 9 and higher and 24 inches per second for low row tubes. Sufficient sampling rates were used to maintain a minimum digitizing rate of 33 samples per inch. The bobbin probes were operated in both the differential and absolute modes at frequencies of 650 kHz, 320 kHz, 160 kHz, and 35 kHz. The following suppression mixes were used to enhance the inspection: 650/160 kHz differential mix, 320/160 kHz absolute mix, 650/320 kHz differential mix and a 650/320/160 kHz differential mix.

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4.1.2 Inspections of non-quantifiable bobbin coil indications and hot leg dents/dings greater than 2.0 volts as detected by the bobbin coil examination, were performed utilizing +PointTM probes as described in Section 3.1.6. Maximum axial probe inspection speed was 0.8 inches per second for straight tubing, 0.33 inches per second for U-bend region of the tubing and 0.15 inches per second at dents and dings. Sample rates and rotation speeds were used to maintain a minimum digitizing rate of 30 samples per inch (i.e., 25 samples per inch for the axial direction and 30 samples per inch for the circumferential direction). The rotating probes for straight section tubing and dents/ding inspections were operated in the absolute test mode at frequencies of 300 kHz, 200 kHz, 100 kHz and 20 kHz. The rotating probes for U-bend section inspections were operated in the absolute test mode at frequencies of 400 kHz, 300 kHz, 100 kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display axial indications in the positive trace.

4.1.3 The eddy current calibration standards used for the bobbin coil and

+PointTM inspections met the requirements of the EPRI Guidelines, Revision 7, and Sections V and Xl of the ASME Code, 2001 Edition through 2003 Addenda.

4.1.4 The SG eddy current examination techniques used during this inspection were equivalent to the EPRI Guidelines Appendix H or Appendix I techniques 'isted in Table 4.1. Each ETSS was evaluated and determined to be applicable to site conditions.

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Table 4.1 EPRI Appendix H and Appendix I chniques EPRI.ý

. Location

. ... .. . . .. M o d e ::.. *

Orientation Degradaton ;: : EPRI ETSS ETSS .. . Probe..

Mode Rev.

Fan Bar & Lattice Grid Wear Vol 96004.3 13 Bobbin 96004.3 13 4

Bobbin

+oin Foreign Object/Freespan Wear Vol 998.1 21998.1 4 +Point US Sludge Pile, (Detection) 3 +Point ODSCC Axial 128425 Freespan Regions, Support Structures (Sizing) 2 +Point 128432 (Detection) 3 +Point 128424 (Siing ____

Sludge Pile Region ODSCC Axial (Sizing) 2 +Point 128431 TTS Expansion ODSCC Circ 21410.1 6 +Point TTS Expansion PWSCC Axial 20511.1 8 +Point TTS Expans~jn PWSCC C1i'c 20510.1 7 +Point Dents/Dings FWSCC Axial 96703.1 17 +Point Dents/Dings PWSCC Circ 20510.1 7 +Point (Detection) 3 +Point 128425 (i n2+

n Dents/Dings < 2 Volts ODSCC Axial (Sizing) 2 +Point 128432 Dents/Dings > 2 Volts ODSCC Axial 22401.1 4 +Point Dents/Dings ODSCC Circ 21410.1 6 +Point Tube Support Plate , GA/ODSCC Axial (Detection) 3 Bobbin Sludge Pile 128413 96004.3 13 0

Bobbin

+oin Tube-to-Tube Proximity Wear Vol 908.2 10908.2 0 +Point Freespan MBMs Vol 96010.1 7 Bobbin IGA - Intergranular Attack MBM - Manufacturing Burnish Mark ODSCC - Outside Diameter Stress Corrosion Cracking PWSCC - Primary Water Stress Corrosion Cracking TTS - Top of Tubesheet 4.2 Steam Generator Inspection Scope (TS 5.6.9.a) 4.2.1 100% of the in service tubes in all SGs were inspected full-length with a bobbin probe as described in Section 4.1.1.

4.2.2 Diagnostic examinations were performed on all non-quantifiable indications, locations of foreign object wear, and hot leg dents/dings 7

greater than 2.0 volts that were detected by the bobbin coil examination.

Diagnostic examinations were also conducted in the vicinity of potential foreign objects to determine the extent of tubes potentially affected by the objects. These special examinations were performed with the three coil

+PointTM probe described in Section 4.1.2 above. See Section 5.1 and Attachment B.3 for further detail.

4.2.3 See Attachment B for tubesheet maps detailing the inspection scope for each SG.

4.3 Recording of Examination Data Results of the SG eddy current data analysis were recorded on optical disks.

The data was then loaded into a Westinghouse Eddy Current Data Management System, "STMax"' version, 1.28.08. The system was used to track the completion of the examinations and was used to generate the final SG eddy current report summaries.

4.4 Witness and Verification of Examination SG eddy current inspections were witnessed and/or verified by the Authorized Nuclear Irservice Inspector3, Mr. L. Malabanan of the Hartford Steam Boiler Inspection and Insurance Company of Hartford Connecticut, Chicago Branch, 2443 Warrenville Road, Suite 500, Lisle, Illinois 60532-9871.

5.0 EXADJINATlON RESULTS 5.1 Edcdy Current Inspection (TS 5.6.9.b *dn TS 5.6.9.d)

Full-length bobbin coil examination of elI inservice tubes was performed in all SGs.

5.1.1 Fan Bar Wear - A total of 67 indications of tube wear at the Fan Bar intersections were identified during Al R1 6. The largest indication of Fan Bar wear was 15% Through Wall (TW) as measured by the eddy current technique. The EPRI Appendix H bobbin coil technique 96004.3 was utilized in this inspection for depth sizing of all Fan Bar wear. Refer to Attachment B.4 for detailed locations and sizing for all Fan Bar wear.

5.1.2 Lattice Grid Wear - A total of nine indications of tube wear at the Lattice Grid intersections were identified during Al R1 6. The largest indication of Lattice Grid wear was 9% TW as measured by the eddy current technique. The EPRI Appendix H bobbin coil technique 96004.3 was utilized in this inspection for depth sizing of all Lattice Grid wear. Refer to Attachment B.5 for detailed locations and sizing for all Lattice Grid wear.

5.1.3 Foreign Obiect Wear - A total of seven indications of secondary side foreign object wear were identified during AlR16. The EPRI Appendix H

+PointTM technique 21988.1 was utilized in this inspection for depth sizing of all foreign object wear.

8

Of the seven indications identified during Al R1 6, four indications were identified during a previous SG inspection (Al R12) and were allowed to remain in service since they were below the TS plugging criteria of greater than or equal to 40% TW, and secondary side visual inspection confirmed that the objects that caused the tube wear were no longer present. Re-inspection of these indications during Al R13, A1 R14, and Al R1 6 confirmed that the associated wear had not changed since first identified during A1R12. Therefore these indications were allowed to remain in service.

Three tubes contained secondary side foreign object wear that was newly identified during Al R1 6.

In the 1A SG, Tube Row 19 Col 138 had a 39% TW foreign object wear indication, as measured by eddy current technique 21988.1, which was 0.30" above the hot leg top of tubesheet intersection. The inservice tubes surrounding the area of wear were inspected with +PointTM. Tube Row 17 Col 138 had a 25% TW foreign object wear indication, which was 0.09" above the hot leg top of tubesheet intersection, and Tube Row 20 Col 139 had a 13% TW foreign object wear indication, which was 0.16" above the hot leg top of tubesheet intersection, as measured by eddy current technique 21988.1 for both indications. Secondary side video inspection of the region as performed during Al R1G did not identify any foreign object(s) in 4Lha vicinity of the wear indications. Although Tube Row 19 Col 133, containing t,,e 39% TW ind;cation, was below the TS plugging criteria, it was conservativel7 removed from service via plugging. Since the other two nev/wndications were associated with relative:y smal!

amounts of tube wear (13% TW and 25% TW), were below the TS plugging criteria of greater than or equal to 40% TW, and secondary side visual inspection ccnfirmed that the object(s) that caused the tube wear were no longer present., the indications were allowed to remain in service.

Refer 'toAttachment B.2 for detailed locations and sizing for all Foreign Object wear indications.

5.1.4 Attachment B contains tube lists with axial elevations of all imperfections that contain measurable through wall depth that were found during the Al R1 6 eddy current inspection.

5.2 Other Inspection Results 5.2.1 Hot Lea Dent/ Ding Inspection: During refueling outage A1R16, 100% of the hot leg dents / dings greater than 2.0 volts were inspected with

+PointTM. A total of two tubes contained dings that met the inspection criteria and were inspected. No degradation was identified as a result of these inspections.

5.2.2 Visual Inspection of Installed Tube Plugs - All previously installed tube plugs were visually inspected for signs of degradation and leakage. In addition, all plugs installed during Al R16 were also visually inspected and the installation parameters were reviewed for acceptable installation. No 9

anomalies were found. Additionally, the two newly installed tube plugs were visually inspected and the plug installation parameters were verified and found to be acceptable.

5.2.3 Tube-to-Tube Proximity - The condition of tubes being in close proximity was monitored as part of the full-length bobbin coil inspection of all in service tubes in all four SGs during Al R16. The inspection results, including historical data related to tube-to-tube proximity is provided in the Table 5.2.3 below. No tube degradation was identified associated with tube-to-tube proximity. This condition will continue to be monitored during future scheduled SG inspections.

Table 5.2.3 Tube-to-Tube Proximity Summary Numnber of Tubes Pre-Servico Ai, lO: 1:: I..I .. ::R,6 Inspection AIRO8 .. AR12 A1R113.A1R14 Noe~Note 2 Note 3 Note 4 Total 508 186 132 139 1 188 1196 204 1249 Note 1: !G inspection performed wh~le the SGs were in a horizontal position.

Note 2: During A".R10 the ;A SG received 100% full-length eddy current insoection and the 1B, 1C and 1D SGs received 54% full-length inspection.

Notc 3- Only the 1B SG received 100o ,lu~l-length inspection through the area of interest during Al R1 1.

Note 4: Due to the heighted sensitivity to the potential for tube-to-tube contact wear that was recently identified at Three Mile Island, ANO and San Onofre Unit 3, enhanced training was provided to all eddy current analysts prior to the Al R1 6 inspections.

6.0 RESULTS OF CONDITION MONITORIN -1(TS 5.6.9.g)

A condition monitoring assessment was performed for each inservice degradation mechanism found during the Al R1 6 inspection. The condition monitoring assessment was performed in accordance with TS 5.5.9.a and NEI 97-06 using the EPRI Steam Generator Integrity Assessment Guidelines, Revision 3. For each identified degradation mechanism, the as-found condition was compared to the appropriate performance criteria for tube structural integrity, accident induced leakage and operational leakage as defined in TS 5.5.9.b. For each damage mechanism a tube structural limit was determined to ensure that SG tube integrity would be maintained over the full range of normal operating conditions and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary to secondary pressure differential and a safety factor of 1.4 against burst under the limiting design basis accident pressure differential.

For Braidwood Station Unit 1, the limiting case is 3 times operating differential pressure, which is significantly higher than 1.4 times the most limiting accident condition (steam line break). The structural limit of 60% through wall used was based upon 360-degree uniform wall thinning for infinite length assuming ASME Code minimum material properties. The structural limits provided are conservative in that the limits assume 360 10

degree uniform wall thinning for the entire length of the tube and use conservative lower reactor coolant temperatures. Satisfying the structural limit ensures that the SG tube integrity performance criteria for structural integrity, accident induced leakage and operational leakage was maintained.

The as-found condition of each degradation mechanism found during Al R1 6 was shown to meet the appropriate limiting structural integrity performance parameter with a probability of 0.95 at 50% confidence, including consideration of relevant uncertainties.

No tube pulls or in-site pressure testing was performed or required during Al R1 6.

Sections 6.1 through 6.3 provide a summary of the condition monitoring assessment for each degradation mechanism.

6.1 Fan Bar Wear The largest Fan Bar wear indication found during the Al R1 6 inspection was 15%

TW as measured by the EPRI Appendix H qualified technique 96004.3.

Considering technique and analyst uncertainties, the largest AVB wear indication found is corrected to 24.3% TW with a 0.95 probability at 50% confidence. This is well below the conservative Fan Bar wear conservative low Reactor Coolant Temperature Average (Tavg) structural limit of 60% TW.

6.2 LA-tice Grid Wen"

-*. 'ý-gest Lattice Grid wear indication found during the Al R16 inspection was 9% ,fW as measured by the EPRI Appendix H qualified technique 96004.3.

Considering technique and analyst uncertainties, the largest AVB wear indication found is corrected to 19.5% TIW with a C.95 probability at 50% confidence. This is well below the conservative Lattice Grid wear conservative low Tavg structural Ilmit of 60% TW.

6.3 Foreign Z"bjeet Wear The largest Foreign Object wear indication found during the Al R1 6 inspection was 39% TIN as measured by the EPRI Appendix H qualified technique 21998.1.

Considering technique and analyst uncertainties, the largest Foreign Object wear indication found is corrected to 57.14% TW with a 0.95 probability at 50%

confidence. This is below the conservative low Tavg Foreign Object wear structural limit of 60% TW.

7.0 TUBE PLUGGING

SUMMARY

(TS 5.6.9.1)

Tube plugging was conducted in accordance with ASME Section XI, 2001 Edition through 2003 Addenda. All tube plugging was performed by Westinghouse using an Alloy 690 mechanical tube plugging process in accordance with ASME Section XI IWA-4713, "Heat Exchanger Tube Plugging by Expansion." All tube plugging was performed in accordance with Westinghouse approved procedures. Table 7.0 summarizes the repairs performed during Al R1 6.

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Table 7.0 Summary of AIR16 Tube Plug ging Repairs SG 1A SG 1B SG 1C SG 1D TOTAL Performed Tubes 1 0 0 0 1 Plugged Tubes 0 0 0 0 Stabilized 0 I I I _ I Refer to Attachment B for detailed locations and sizing of indications in tubes that were plugged during Al R1 6.

8.0 DOCUMENTATION All original data stored on hard drives have been provided to EGC and are maintained at Braidwood Station. The final data sheets and pertinent tube sheet plots are contained in the Westinghouse Outage Report for Braidwood Unit 1, Sixteenth Refueling Outage, and are also maintained at Braidwood Station.

NOTE: The Braidwood Unit 1 Sixteenth Refueling Outage Steam Generator Repair/Replacement activities are contained in a separate transmittal: the "Braidwood Station, Unit 1 Inservice Inspection Summary Report."

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9.0 FIG URES/TABLES/ATTACHM ENTS Attachment A Contents Table A.1 Data Acquisition Personnel Certification List Table A.2 Data Analysis Personnel Certification List Figure A.1 Babcock & Wilcox Replacement Steam Generator Braidwood Unit 1 Configuration Figure A.2 Babcock & Wilcox Replacement Steam Generator Braidwood Unit 1 Tubesheet Configuration Attachment B Contents Attachment B.1 As-tested Bobbin Inspection Maps Attachment B.2 As-tested +PointTM Special Interest Inspection Maps Attachment B.3 Tubes Damaged by Secondary Side Foreign Objects Attachment B.4 Tubes Containing Fan Bar WLar Attachment B.5 Tubes Containing Lattice Grid Wear Attachment B.6 Tubes Repaired During A1 R1 6 13

Attachment A Personnel Certifications

TABLE A.1 A1R16 Data Acquisition Personnel Certifications No.

Name Compan Level QDA (Y IN )

1 Hammon, M System One I No 2 Herold, CC System One II No 3 Lopez, PA System One I No 4 Bradley, GD West II No 5 Fore, SK West II No 6 Gault, WH West II No 7 Hopper, JM West II No 8 Labieniec, JP West II No 9 Mantich, SM West I No 10 Parris, JR West II No 11 Patton, BB West II No 12 Permuka, JD Wet II No 13 Schachte, DM West II No 14 Scott, AW West II No 15 Taylor, AW West I No 16 Thompson, KVW West II No 17 Whalen. DJ West III No

- .Vpe D I Wet-

TABLE A.2 A1R16 Data Analysis Personnel Certifications No.

____Y______ Name Company

_____________ Level (YIN ODA 1 Hill, J Infin III Y 2 Rush, S Infin III Y 3 Holden, TA M&IS III Y 4 Carlson, C Mistras IIA Y 5 Gomez, A Mistras IIA Y 6 Welch, L Mistras IliA Y 7 Anderson,, DA NDE IIA Y 8* Black, CR NDE lilA Y 9 Brown Mike W NDE lilA Y 10* Brown, ME NDE lilA Y 11 Causby, GW NDE lilA Y 12 Drumm, RL NDE IliA Y 13 Dye, JE NDE IIA Y 14, Grant, BM NDE lilA Y IU Johinson, JC NDE IIA Y 10 Kova! asky, T NDE IIA Y I,- Lewis, CL NDE IIA Y 18 Lewis, DA NDE IliA Y 19 Lynn, V NDE lilA Y 23 McLeod, EJ NDE IIA Y 21 Richmond, MA NDE lilA Y 22 Schmitz, KJ NDE lilA Y Sj Shek.-n, JT NDE IliA Y 24 Siegel, RA NDE IliA Y 2S Thompson, KA NDE IIA Y 26 Owens, S Tricen Tech IIA Y 27 Stokke, T Tricen Tech lilA Y 28 Beehner, SJ West III Y 29 Ericson, ER West III Y 30 Lynch, DE West III Y 31 Maurer, RS West III Y 32 Pocratsky, RJ West III Y 33 Popovich, RA West III Y 34 Ripple, GB West IIA Y 35 Skirpan, JR West III Y 36 Spence, WJ West III Y 37 Terning, GA West III Y

Independent Qualified Data Analyst

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ML12251A359

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1.0 INTRODUCTION

SUMMARY

SUMMARY

1.0 INTRODUCTION

SUMMARY

SUMMARY

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