Text

Thirteenth Refueling Outage Steam Generator Inservice Inspection Summary Report
	ML080180437
Person / Time
Site:	Braidwood
Issue date:	01/18/2008
From:	Coutu T; Exelon Corp, Exelon Generation Co, Exelon Nuclear
To:	; Office of Nuclear Reactor Regulation
References
	BW080003
	Download: ML080180437 (74)
	v • d • e

January 18, 2008 BW080003 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555-0001 Braidwood Station, Unit 1 Facility Operating License No, NPF 72 NRC Docket No. STN 50-456

Subject:

Braidwood Station, Unit 1 Thirteenth Refueling Outage Steam Generator

!nservice Inspection Summary Report In accordance with Technical Specification 5.6.9, Steam Generator (SG) Tube Insoection Report Exelon Generation Company, LLC is reporting the results of the SG inspections, which were completed during the Braidwood Station, Unit 1 thirteenth refueling outage (Al Ri 3). The attached report is also being submitted in accordance with the requirements of the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, 1989 Edition, Section Xl, Rules for Inservice Inspection of Nuclear Power Plant Components, Article IWA-6000, Records and Reports, and Article lV-7000, Report of Examination, of Mandatory Appendix IV, Eddy Current Examination of Non-Ferromagnetic Steam Generator Heat Exchanger Tubing.

If there are any questions regarding this submittal, please contact Mr. David Gullott, Regulatory Assurance Manager, at (815) 417-2800.

Respectfully, Thomas Coutu Site Vice President Braidwood Station

Attachment:

Exelon Braidwood Station Unit 1 Thirteenth Refueling Outage Steam Generator lnservice Inspection Summary Report

Exelon Nuclear BRAIDWOOD STATION UNIT 1 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: July 29, 1988 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT THIRTEENTH REFUELING OUTAGE (A1R13)

October 2007 Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 Document Completion Date: January 11, 2008

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 Examination Data 4.4 Witness and Verification of Examination 5.0 EXAMINATION RESULTS 5.1 Eddy Current Inspection 5.2 Other Inspection Results 6.0 RESULTS OF CONDITION MONITORING 6.1 Fan BarWear 6.2 Lattice Grid Wear 6.3 Foreign Object Wear 7.0 REPAIR

SUMMARY

8.0 DOCUMENTATION 9.0 FIGURES/TABLES/ATTACHMENTS

January 18, 2008 BW080003 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555-0001 Braidwood Station, Unit 1 Facility Operating License No, NPF 72 NRC Docket No. STN 50-456

Subject:

Braidwood Station, Unit 1 Thirteenth Refueling Outage Steam Generator

!nservice Inspection Summary Report In accordance with Technical Specification 5.6.9, Steam Generator (SG) Tube Insoection Report Exelon Generation Company, LLC is reporting the results of the SG inspections, which were completed during the Braidwood Station, Unit 1 thirteenth refueling outage (Al Ri 3). The attached report is also being submitted in accordance with the requirements of the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, 1989 Edition, Section Xl, Rules for Inservice Inspection of Nuclear Power Plant Components, Article IWA-6000, Records and Reports, and Article lV-7000, Report of Examination, of Mandatory Appendix IV, Eddy Current Examination of Non-Ferromagnetic Steam Generator Heat Exchanger Tubing.

If there are any questions regarding this submittal, please contact Mr. David Gullott, Regulatory Assurance Manager, at (815) 417-2800.

Respectfully, Thomas Coutu Site Vice President Braidwood Station

Attachment:

Exelon Braidwood Station Unit 1 Thirteenth Refueling Outage Steam Generator lnservice Inspection Summary Report

Exelon Nuclear BRAIDWOOD STATION UNIT 1 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: July 29, 1988 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT THIRTEENTH REFUELING OUTAGE (A1R13)

October 2007 Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 Document Completion Date: January 11, 2008

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 Examination Data 4.4 Witness and Verification of Examination 5.0 EXAMINATION RESULTS 5.1 Eddy Current Inspection 5.2 Other Inspection Results 6.0 RESULTS OF CONDITION MONITORING 6.1 Fan BarWear 6.2 Lattice Grid Wear 6.3 Foreign Object Wear 7.0 REPAIR

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 lnconel-690 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 1989 Edition, IWB 2500-1, Examination Category B-Q, Item B16.20, SG eddy current examinations were performed during the Braidwood Station Unit 1 thirteenth refueling outage (Al Ri 3). The inspections were performed consistent with the Electric Power Research Institute (EPRI) PWR Steam Generator Examination Guidelines, Revision 6, and Nuclear Energy Institute NEI 97-06, Steam Generator Program Guidelines, Revision 2. The inspections were conducted from October 4, 2007 through October 13, 2007 by the Westinghouse Electric Company (Westinghouse).

The following inspections were performed during this outage (TS 5.6.9.a).

100% full length bobbin coil eddy current in all four SGs

100% hot leg dents and dings > 2.0 volts +PointTM

Diagnostic +PointTM eddy current based on bobbin coil eddy current results

100% Visual Inspection of Previously Installed Tube Plugs

100% Visual Inspection of Newly Installed Tube Plugs 2.0

SUMMARY

The requirements of Revision 6 of the EPRI PWR Steam Generator Examination Guidelines (i.e., EPRI Guidelines) along with Interim Guidance as provided by EPRI, were implemented during this inspection. A degradation assessment was performed prior to the inspection to ensure the proper EPRI Guidelines Appendix H, Performance Demonstration for Eddy Current Examination, qualified inspection techniques were used to detect any existing and potential modes of degradation. Each technique was evaluated to ensure that the 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.

1

The modes of tube degradation found during Al Rl 3 were fan bar wear, lattice grid wear and foreign object wear. Pursuant to EPRI Guideline Section 3.5, Inspection Results Categories, the results of the inspection were classified as inspection category 0-1 for all four SGs.

As a result of the eddy current inspection of the SGs, a total of 21 tubes were removed from service by mechanical tube plugging. The 21 tubes were removed from service due to either having wear associated with secondary side foreign objects or were required to be removed from service in order to bound high flow locations where secondary side foreign objects could not be retrieved.

There were no tubes containing wear greater than the TS plugging limit of ~ 40% in any of the four SGs.

There were no scanning limitations during the eddy current examinations. 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 Ri 3, provides the total number of tubes during the current outage by degradation mode.

Table 2.1 Eauivalent Tube Pluaclinci Level (TS 5.6.9.f and 5.6.9h)

SO A SG B SO C SO D Total Tubes Plugged at Factory 1 2 0 0 3 Tubes Plugged in A1RO8 1 0 0 0 1 Tubes Plugged in A1R1O 8 10 3 0 21 Tubes Plugged in A1R11 0 2 2 1 5 Tubes Plugged in A1R12 11 17 0 0 28 Tubes Plugged in A1R13 6 8 7 0 21 Total Tubes Plugged 27 39 12 1 79 Total Tubes Plugged (%) 0.41% 0.59% 0.18% ~ 0.02% a30%

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

Table 2.2 Tubes Plugged D~~~1R ~6.9.b and TS

~~ofDeq~adatI~n SO A SO B SO C SO D Total FanBarWear 0 0 0 0 0 Lattice Grid Wear 0 0 0 0 0 Foreign Object Wear 1 0 0 0 1 Preventively Plugged 5 8 7 0 20 Total Tubes Plugged in 6 8 7 0 21 A1R13 2

3.0 CERTIFICATIONS 3.1 Procedures/Examinations/Equipment 3.1.1 The examination and evaluation procedures used during the SG eddy current inspection were approved by personnel qualified to Level III in accordance with the 1984 Edition of SNT-TC-1A, Personnel Qualification and Certification in Nondestructive Testing. Exelon Generation Company, LLC (i.e., Exelon) Procedure ER-AP-335-039, Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing, Revision 4 and Exelon Procedure ER-AP-335-040, Evaluation of Eddy Current Data for Steam Generator Tubing, Revision 3, were used for data acquisition and analysis.

3.1.2 The examinations, 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; 1989 Edition of ASME Boiler and Pressure Vessel Code Sections Xl, Rules for Inservice Inspection of Nuclear power Plant Components, and Section V, Nondestructive Examination; EPRI PWR SG Examination Guidelines, Revision 6; and NEI 97-06, Steam Generator Program Guidelines, Revision 2.

3.1.3 Certification packages for examiners, data analysts, and equipment are available at Braidwood Station. Tables A.l 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-2001M Remote Data Acquisition Units (RDAU5) with Westinghouse ANSER computer software was used to acquire the eddy current data. Analysis was performed with Westinghouse ANSER 8.4.3 Rev 275 computer software. Secondary analysis was performed with CoreStar EddyVisionTM32, Release 6.3 computer software.

3.1.5 The bobbin coil examinations of the SOs were performed with Westinghouse 0.560 inch diameter probes. For low row U-Bend tubing, a 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 shielded 0.080 inch diameter pancake coil and a standard +PointTM coil. For diagnostic evaluation of indications within the U-Bend tubing, a 0.520 inch diameter probe was used with a single standard +PointTM coil.

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3.2 Personnel 3.2.1 The personnel who performed the SO eddy current inspections were qualified to Level I and Level II certification in accordance with the 1984 Edition of SNT-TC-lA. The Level I personnel performed the inspections under the direct supervision of Level II or Level Ill personnel. A list of the certified eddy current personnel who performed data acquisition for the examination is contained in Table A.i 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 IIA) in accordance with the 1984 Edition of SNT-TC-1A and Article IV-2000 of ASME Section XI, 1989 Edition. A list of the certified eddy current personnel who performed data analysis for the examination is contained in Table A.2 of Attachment A.

3.2.3 All eddy current data analysts were qualified in accordance with EPRI Appendix 0 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 and secondary analysis was performed by an automated data screening analysis system as described in the EPRI Guidelines, Revision

6. The analysis systems were operated in the manual interactive mode.

Each system successfully passed the EPRI Automated Analysis Performance Demonstration Database (AAPDD). Each system also was required to successfully pass the site specific performance demonstration practical examination prior to analyzing field data. Discrepancies between the two parties required Level Ill concurrence between both parties for final resolution.

3.2.6 Two independent SO eddy current Level III QDAs were employed to serve as a process control reviewers, in accordance with EPRI Guidelines, to randomly sample 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 1

Sheet (ETSS) and to provide a data quality check of acquired data. The Independent Level Ill QDAs reported directly to the Exelon Level Ill inspector.

3.2.7 Personnel qualified as data analysts performed real time data quality verifications.

4.0 EXAMINATION TECHNIQUES AND EXAMINATION SCOPE All SG eddy current examination techniques used were qualified in accordance with Appendix H of the EPRI Guidelines. Each examination technique was evaluated to be applicable to the tubing and conditions of the Braidwood Station Unit 1 SOs.

4.1 Examination 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 10 and higher and 24 inches per second for low row tubes. Sufficient sampling rates were used to maintain a minimum digitizing rate of 30 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, 320/1 60 kHz absolute mix, 650/320 kHz differential mix and a 650/320/160 kHz differential mix.

4.1.2 Inspections of non-quantifiable bobbin coil indications and hot leg dents/dings greater than or to 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 0.6 inches per second for straight tubing, 0.35 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 6, and Sections V and Xl of the ASME Code, 1989 Edition.

2

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

Table 4.1

_____ EPRI Appendix H Techniques _________

EpRIr ~

Technique Probe j Description

_________ _____-____ ____

96004.3 Bobbin Fan Bar/Lattice Grid/Foreign Object Wear and Free Rev. 11 Span Flaws 96910.1 Foreign Object Wear/Free Span Flaws (Wear Like Rev. 10 +POintTM Flaws) 21998.1

+PointTM Foreign Object Wear (Volumetric Like Flaws)

Rev,_4 96703.1 Dents/Dings Primary Water Stress Corrosion Rev. 17 +PointTM Cracking (Axial PWSCC) 21409.1 Outer Diameter Stress Corrosion Cracking (Axial

÷PointTM ODSCC)

Rev. 5 21410.1

+PointTM Outer Diameter Stress Corrosion Cracking Rev. 6 (Circumferential ODSCC) 20511.1 Inside Diameter Stress Corrosion Cracking (Axial

+PointTM PWSCC)

Rev. 8 20510.1 Inside Diameter Stress Corrosion Cracking

÷PointlM (Circumferential PWSCC)

Rev. 7 96010.1 Bobbin Manufacturing Burnish Marks Rev._7 22401.1 Dents/Dings Outer Diameter Stress Corrosion

+POifltTM Rev. 4 Cracking (Axial ODSCC) 96008.1 Tube Support Plate / Sludge Pile Outer Diameter Bobbin Rev. 14 Stress Corrosion Cracking (Axial ODSCC)

PWSCC Primary Water Stress Corrosion Cracking

ODSCC Outside Diameter Stress Corrosion Cracking

4.2 Steam Generator Inspection Scope (TS 5.6.9.a) 4.2.1 100°/aof the tubes in all SOs 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 greater than or equal to 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.

3

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

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, 1.20.02. The system was used to track the completion of the examinations and was used to generate the final SO eddy current report summaries.

4.4 Witness and Verification of Examination SO eddy current inspections were witnessed and/or verified by the Authorized Nuclear Inservice Inspectors, 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 EXAMINATION RESULTS 5.1 Eddy Current Inspection (TS 5.6.9.b and TS 5.6.9.d)

Full-length bobbin coil examination of all inservice tubes was performed in all SGs. Only two hot leg region dents / dings greater than or equal to 2.0 volts in the hot leg region were identified. These dents I dings were inspected with

+PointTM and showed no degradation.

5.1.1 Fan Bar Wear A total of 34 indications of tube wear at the Fan Bar

intersections were identified during Al Ri 3. The largest indication of Fan Bar wear was 16% Through Wall (1W) as measured by the eddy current technique. The EPRI Appendix H bobbin coil technique 96004.3 Revision ii was utilized in this inspection for depth sizing of all Fan Bar wear.

Refer to Attachment B.5 for detailed locations and sizing for all Fan Bar wear.

5.1 .2 Lattice Grid Wear A total of six indications of tube wear at the Lattice

Grid intersections were identified during Al Ri 3. The largest indication of Lattice Grid wear was 10% 1W as measured by the eddy current technique. The EPRI Appendix H bobbin coil technique 96004.3 Revision ii was utilized in this inspection for depth sizing of all Lattice Grid wear.

Refer to Attachment B.6 for detailed locations and sizing for all Lattice Grid wear.

5.1.3 Foreign Obiect Wear A total of five indications of secondary side foreign

object wear were identified during Al Ri 3. The EPRI Appendix H

+PointTM technique 21988.1 Revision 4 was utilized in this inspection for depth sizing of all foreign object wear.

4

Of the five indications, four were associated with relatively small amounts of tube wear (15% TW, 15% TW, 14% TW and 22%TW) as measured by the eddy current technique. These tubes were identified during the previous SO inspection (Al Ri 2) and were allowed to remain in service since they were below the TS plugging criteria of greater than or equal to 40% TW, coupled with secondary side visual inspection confirming that the objects that caused the tube wear were no longer present. Re-inspection of these indications during Al R13 confirmed that the associated wear had not changed since first identified during Al Ri 2.

Therefore these indications were allowed to remain in service.

One tube had secondary side foreign object wear that was newly identified during A1R13. In the 1A SO, Tube Row 112 Column 59 had an ii % 1W wear, as measured by the eddy current technique, at the top of the cold leg tubesheet + 0.26 inches. The wear was associated with a piece of metallic gasket material approximately 1.7 inches long. The object could not be successfully retrieved. The tube with the ii % TW indication, along with five tubes surrounding the gasket material were preventatively stabilized and plugged.

In the iC SO, seven tubes were preventatively plugged and stabilized in the hot leg top of tubesheet region due to visual inspection identifying a piece of metallic gasket material approximately 2.5 inches in length.

Since this object was in a high flow area and could not be successfully retrieved, the tubes surrounding the object were preventively stabilized and plugged even though they showed no signs of degradation based on eddy current or visual inspection.

In the 1 B SO, eight tubes were preventatively plugged and stabilized in the hot leg top of tubesheet region due to visual inspection identifying a piece of weld slag approximately 2.0 inches in length. Since this object was in a high flow area and could not be successfully retrieved, the tubes surrounding the object were preventively stabilized and plugged even though they showed no signs of degradation based on eddy current or visual inspection.

Refer to Attachment B.4 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 Ri 3 eddy current inspection.

5.2 Other Inspection Results 5.2.1 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 this outage were also visually inspected and the installation parameters were reviewed for acceptable installation.

No anomalies were found.

5

6.0 RESULTS OF CONDITION MONITORING (TS 5.6.9.g)

A condition monitoring assessment was performed for each inservice degradation mechanism found during the Ai Ri 3 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 2. 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. Since only volumetric wear was identified during Ai Ri 3, satisfying the structural limit ensures that the SO tube integrity performance criteria for structural integrity, accident induced leakage and operational leakage will be maintained. The structural limits provided below are conservative in that they assume uniform 360 degree wall thinning for the length of the tube.

The as-found condition of each degradation mechanism found during Al Rl 3 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-situ pressure testing was performed during Al Ri 3.

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 Ri 3 inspection was 16%

TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision

11. 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 structural limit of 60% 1W.

6.2 Lattice Grid Wear The largest Lattice Grid wear indication found during the Al Ri 3 inspection was 10% 1W as measured by the EPRI Appendix H qualified technique 96004.3, Revision ii. Considering technique and analyst uncertainties, the largest AVB wear indication found is corrected to i8.5% TW with a 0.95 probability at 50%

confidence. This is well below the conservative Lattice Grid wear structural limit of 60%TW.

6

6.3 Foreign Object Wear The largest Foreign Object wear indication found during the Al Ri 3 inspection was 22% 1W as measured by the EPRI Appendix H qualified technique 21998.1, Revision 4. Considering technique and analyst uncertainties, the largest Foreign Object wear indication found is corrected to 39.8% 1W with a 0.95 probability at 50% confidence. This is well below the conservative Foreign Object wear structural limit of 60% 1W.

7.0 REPAIR

SUMMARY

(TS 5.6.9.i)

Repairs were conducted in accordance with ASME Section XI, 1989 Edition. All repairs were performed using Inconel-690 mechanical tube plugs. All repairs were performed in accordance with Westinghouse approved procedures. Table 7.0 summarizes the repairs performed during Al Ri 3. No tube sleeving was performed.

Table 7.0

____ Summary of Al R13 Tube Plug~ing

~E~AiAs ~IA I SG1BJSG1C SG 1 D TOTAL

___ ____ __ ____ J Tubes 6 7 0 21 8.0 DOCUMENTATION All original data is stored on optical disks that have been provided to Exelon 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, Thirteenth Refueling Outage, and are also maintained at Braidwood Station.

NOTE: The ASME Section Xl NIS-i Form. Owners Report for Inservice Inspections, for steam generator inspections performed during the Braidwood Unit 1 Thirteenth Refueling Outage is contained in a separate transmittal: the Braidwood Station, Unit i lnservice Inspection Summary Report.

7

9.0 FIGURES/TABLES/ATTACHMENTS Attachment A Contents Table A.l Data Acquisition Personnel Certification List Table A.2 Data Analysis Personnel Certification List Figure A.i Babcock & Wilcox Replacement Steam Generator Braidwood Unit i Configuration Figure A.2 Babcock & Wilcox Replacement Steam Generator Braidwood Unit i Tubesheet Configuration Attachment B Contents Attachment 8.1 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 8.4 Tubes Containing Fan Bar Wear Attachment B.5 Tubes Containing Lattice Grid Wear Attachment B.6 Tubes Repaired During Al Ri 3 8

Attachment A Personnel Certifications

TABLE A.1 A1R13 Data Acquisition Personnel Certifications No. Name Company Level QDA (Y/N) 1 Estel, J. Westinghouse II No 2 Kukic, F. Westinghouse II No 3 Mantic, S. Hudson I No 4 Parris, J. Westinghouse II No 5 Pessek, S. Young IIA Yes 6 Pyle, S. Intech II No 7 Schachte, D. Westinghouse II No 8 Scott, A. Westinghouse II No 9 Smith, D. Westinghouse II No 10 Thompson, K. Westinghouse II No 11 Vernon, D. Westinghouse II No

TABLE A.2 A1R13 Data Analysis Personnel Certifications No. Name Company Level QDA (Y/N) 1 Belville, C. Wiltec IIA Yes 2 *Brown, M. NDE Technology lIt Yes 3 Causby,G. NDE Technology Ill Yes 4 Chevalier, W. Young hA Yes 5 Childers, J. Wiltec Ill Yes 6 Circosta, S. Young HI Yes 7 Dlabik, A. Master-Lee III Yes 8 Dzapo, M. HRID llA Yes 9 Gootz, T. Westinghouse HI Yes 10 Hill, J. lnfineddy Ill Yes 11 Kirk, M~ Consumers Ill Yes 12 Lewis, C. NDE Technology IIA Yes 13 Lewis, D. NDE Technology III Yes 14 Lynn, V. Master-Lee III Yes 15 Martin, A. Wiltec IIA Yes 16 Mast, M. NDE Technology III Yes 17 Mauller, K. Wiltec Ill Yes 18 Moon, D. Wiltec Ill Yes 19 Nadinic, B. HRID Ill Yes 20 Pocratsky, R. Westinghouse III Yes 21 Popovich, A. Westinghouse III Yes 22 Prentice, A. Anatec Ill Yes 23 Rengel, A. HRID hA Yes 24 Rush, S. hnfineddy Ill Yes 25 Schaefer, S. Anatec HI Yes 26 *Siegel, R. NDE Technology HI Yes 27 Skirpan, J. NDE Technology (hA Yes 28 Stock, W. ~g~ous~ (H Yes 29 Thompson, K. NDE Technology HA Yes 30 Yaklich, 0. Westinghouse HI Yes 31 Zerovnik, J. HRID HA Yes 32 Zevchak, J. NDE Technology IIA Yes 33 Zunac, D. HRID_____ IlA Yes

Independent Qualified Data Analyst

FIGURE A.1 Babcock & Wilcox Replacement Steam Generator Braidwood Unit 1 Configuration 1**

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FIGURE A 2 Babcock & Wilcox Replacement Steam Generator Braidwood Unit 1 Tubesheet Configuration

Attachment B Inspection Scope / Results A1R13

Attachment B.1 As-tested Bobbin Inspection Maps A1R13

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Tubes: 5 Records: 10 1

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SG D Hot Leg i-PT Special Interest Tests Braidwood Al Ri 3 CCE 7720

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SG - 0 Hot Leg i-PT Special Interest Testing Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:37:51 I ROW CDL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL LI

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+----+----+----÷----+----÷ ÷ +----+----÷ ÷ +

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Tubes: 17 Records: 36 1

Attachment B.3 Tubes Damaged by Secondary Side Foreign Objects A1RI3

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SG - A Tubes with Foreign Object Wear Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:44:01

+- +----+--- i--i--- + --+-+-+-+-+-

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SG B Tubes with Foreign Object Wear Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:43:59

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Tubes: 1 Records: 7 1

Attachment B.4 Tubes Containing Fan Bar Wear A1R13

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SG - A Fan Bar Wear Indications Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:55:40 I ROW COL VOLTS DEG IND PER CNN LOCN INCH1 INCH2 BEGT ENOT PDIA PTYPE CAL Lf

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Tubes: 3 Records: 3 1

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SG - B Fan Bar Wear Indications Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:55:39 I ROW COL VOLTS DEG INO PER CNN LOCN INCH1 INCH2 BEGT ENDT POIA PTYPE CAL Lf

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Tubes: 7 Records: 7 1

SG C Tubes with Fan Bar Wear Indications

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SG - C Fan Bar Wear Ind~cations Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:55:39 ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI

+----+----+----+----÷----+ + +----+----+ + ÷ +--+

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+----+----+ +----+----+----+----+----+ + +----+----+ + +

I ROW COL VOLIS DEG IND PER CHN LOCN INCH1 INCH2 BEGI ENDI PDIA PIYPE CAL LI

+----+----+----÷----÷----+ + +----+----+ + + +--+

Tubes: 18 Records: 18

SO D Tubes with Fan Bar Wear Indications

-

Braidwood AIRI3 CCE 7720 X 6 Tub. with Fan Bar Wear indications

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SG - 0 Fan Bar Wear Ind~cations Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:55:40 I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL Lf

+----+----+----+----+----+ + +----+----+ + +

I 96 69 .51 0 PCT 8 P2 F08 .67 TEC TEH .560 SBALL 55 Hf 85 70 .92 0 PCT 16 P2 F06 -1.29 TEC TEN .560 ZBALL 57 Hf 72 71 .40 0 PCT 8 P2 F06 .92 TEC TEH .560 ZBALL 57 Hf 97 74 .44 0 PCT 9 P2 F08 - .59 TEC TEH .560 ZBALL 57 Hf 104 77 .37 PCT 7 P2 F06 -1.45 TEC TEN .560 SBALL 59 Hf 35 138 .33 0 PCT 5 P2 F05 1.21 TEC TEH .560 ZBALL 85 Hf

+----+----+----+----+----+ + +----+----+ + +

I ROW COL VOLTS DEG IND PER CNN LOCN INCH1 INCH2 BEGT ENDT POIA PTYPE CAL LI

+----+----+----+----+----+ + +----+----+ + +

Tubes: 6 Records: 6 1

Attachment B.5 Tubes Containing Lattice Grid Wear A1R13

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SG - A Lattice Grid Wear Indications Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:52:12 I ROW COL VOLTS DEG IND PER CNN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL LI

+----+----+ +----+----+----+----+----+ + +----+----+ + +

72 19 .17 0 PCT 4 P2 05H .48 TEC TEN .560 ZBALL 97 Hf 39 70 .36 0 PCT 10 P2 O1H -1.85 TEC TEH .560 SBALL 47 Hf

+----+----+----+----+----+ + +----+----+ + +

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL Lf

+----+----+----+----+----+ + +----+----+ + +

Tubes: 2 Records: 2 1

SG B Tubes with Lattice Grid Wear Indications Braidwood A1RI3 CCE 7720 0 31 Plugged Tube 140 135 130 25 120 115 10 105 100 95 90 85 00 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5

ft ~ ~

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140 135 130 125 120 115 110 105 100 95 90 85 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 Wo.844 8 .C, Elealna 000.pUny LLC - ST Mae ¶0/14(2807 12*4802 9 00

SG - B Lattice Grid Wear Indications Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:52:11

- +- +----+----+ -+ -+- +--+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI

+----+----+----+----+----+ + +----+----+ + +

47 24 .11 0 PCT 3 P2 08H -1.53 TEC TEH .560 ZBALL 27 Hf

~+!+T+~!++!~+ *~+

I ROW COL VOLTS DEG IND PER CNN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL LI Tubes: 2 Records: 2 1

SG C Tubes with Lattice Grid Wear Indications

-~

Braidwood A1R13 CCE 7720 a 5 Plugged Tube 140 135 130 125 120 115 110 105 100 95 90 85 80 75 70 65 60 55 ~ 45 40 35 30 25 20 15 10 5

:

115 - ft-~::~~ft~ . C I L 110 105 + 105

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140 135 130 4125 120 115 110 105 100 95 90 85 80 75 70 65 60 55 ~Ø 45 40 35 30 25 20 15 10 5 Wo.0 4(4eaft~~El*.te. Company I LC. ST Mae IS 142507 124643

SG - C Lattice Grid Wear Indications Braidwood 1 A1R13 CCE 20071001 01/14/2008 09:52:11 I ROW COL VOLTS DEG INO PER CNN LOCN INCH1 INCH2 BEGT ENOT POIA PTYPE CAL LI

+----+----+----+----+----+ + +----+----+ + +

I 9 92 .11 0 PCT 3 P2 05C -1.59 TEC TEN .560 ZBALL 29 Hf

+----+----+----+----+----+ + +----+----+ + +

I ROW COL VOLTS DEG IND PER CNN LOCN INCH1 INCH2 BEGT ENDT POIA PTYPE CAL Lf

+----+----+----+----+----+ + +----+----+ + +

Tubes: 1 Records: 1

SG D Tubes with Lattice Grid Wear indications Braidwood A1R13 CCE 7720 a 1 Plugged Tube 140 135 130 125 120 115 110 105 100 95 90 85 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 115 . ~ 115 ise .

110

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4 + 4 ¶ N N C 5 140 135 130 125 120 115 110 105 100 95 90 85 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 00 Ie qh~eeE/ 0(4 - C 004/ 400110 ST Mae 1014 20)7 124001

SG - D Lattice Grid Wear Indications Braidwood 1 A1R13 CCE 20071001 10/14/2007 12:37:23

- +----+----+----+----+----+-+-+----+----+-+-+- +--+---+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL L COMI

+----+----+ +----+----+----+----+----+ + +-.--+----+ + +

I 41 70 .36 0 PCT 8 P2 08H -1.51 TEC TEN .560 ZBALL 57 HI

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I ROW CDL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL L COMI

+----+----+----+----+----+ + +----+----+ + +

Tubes: 1 Records: 1 1

Attachment B.6 Tubes Repaired During A1R13

01) 4)

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v t e Letter Sequence Request
TAC:MD7914, (Approved, Closed)
Initiation Request, Request Acceptance... Administration Questions 16 June 2008 Answers 13 August 2008 Results Approval Other:
MONTHYEAR2008-10-20 [Table View]

ML080180437

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