BYRON 2005-0071, Steam Generator Inservice Inspection Summary Report

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Steam Generator Inservice Inspection Summary Report
ML051600185
Person / Time
Site: Byron Constellation icon.png
Issue date: 06/03/2005
From: Kuczynski S
Exelon Generation Co, Exelon Nuclear
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
BYRON 2005-0071
Download: ML051600185 (47)
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Text

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Exelon Generation Company, LLC www.exeloncorp.con-i Nuci ear Byron Station 4450 North German Church Road Byron, IL 610109794 June 3, 2005 LTR: BYRON 2005-0071 t-~FiIe: 1.10.0101 U. S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Byron Nuclear Power Station, Unit 1 Facility Operating License NPF-37 NRC Docket No. STN 50-454

Subject:

Byron Station Unit 1 Steam Generator Inservice Inspection Summary Report In accordance with Technical Specification 5.6.9, Steam Generator (SO) Tube Inspection Reports, Item b, we are reporting the results of the steam generator inspections that were completed during the Byron Station Unit 1, Refueling Outage 13.

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 report, please contact W. Grundmann, Regulatory Assurance Manager, at (815) 406-2800.

Respectfully, 3c,~7L~L Stephen E. Kuczynski Site Vice President Byron Nuclear Generating Station

Attachment:

Byron Station Unit 1 Steam Generator Eddy Current Inspection Report Refueling Outage 13, March 2005 SEK/JS/TLF/rah

Exelon Generation Company, LLC 4300 Winfield Road Warrenville, IL 60555 Byron Station Unit I 4450 N. German Church Road Byron, IL 61010 COMMERCIAL OPERATION: September 16, 1985 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT REFUELING OUTAGE 13 March 2005 Documentation Completed Date: June 1, 2005 Page 1 of 46

Table of Contents 1.0 Introduction. 3 2.0 Summary 3 3.0 Certifications 4 3.1 Procedures/Examinations/Equipment 4 3.2 Personnel 5 4.0 Examination Technique and Examination Scope 6 4.1 Examination Techniques 6 4.2 Steam Generator Inspection Scope 8 4.3 RecordingofExamination Data 8 4.4 Witness and Verification of Examination 9 5.0 Examination Results 9 5.1 Eddy Current Inspection 9 5.2 Visual Inspection of Installed Tube Plugs 12 6.0 Repair Summary 12 7.0 Documentation 12 8.0 Tables/Figures/Attachments 13-46 Page 2 of 46

1.0 INTRODUCTION

Byron Station Unit I operates with four Babcock & Wilcox Replacement Steam Generators (SOs) 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 SO configuration is shown in Figures A. I and A.2. The replacement SOs were installed during the eighth refueling outage.

In compliance with Byron Station Technical Specification 5.5.9, Steam Generator Tube Surveillance Program, and American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (B&PV) Code, 1989 Edition,Section XI, Rules for Inservice Inspection of Nuclear power Plant Components, IWB 2500-1, Examination Category B-Q, Item B16.20, SG eddy current examinations were performed during the Byron Station Unit 1 Refueling Outage 13. In addition, 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. The field inspection activities were conducted from March 6, 2005, through March 14, 2005, by Westinghouse Electric Company, Ltd. The following tube inspections were performed during this outage:

  • 100% full-length bobbin coil inspection in all four SOs;
  • 20% pIus-point probe inspection of hot leg top of tubesheet region in all four SGs;
  • 100% plus-point inspection of hot leg dents/dings that were ~2.0 volts in all four SGs
  • Visual inspection of all previously installed tube plugs;
  • Diagnostic plus-point inspections based on bobbin coil results; 2.0

SUMMARY

The guidance in Revision 6 of the EPRI PWR Steam Generator Examination Guidelines (i.e., EPRI Guidelines) was used during this inspection. Additionally, the EPRI Guideline Interim Guidance that was issued on March 16, 2004 was also implemented during this inspection. A degradation assessment was performed prior to the inspection to ensure the proper EPRI Guideline 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 Byron Station Unit I specific condition in accordance with Section 6.2.4 of 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. 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.

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As a result of the SO eddy current inspection, no tubes were found that contained flaws exceeding the repair limit. The results of this inspection were classified as inspection category C-I pursuant to Technical Specification 5.5.9.c, Inspection Results Classification. There were no scanning limitations during the eddy current examinations. A total of seven (7) tubes were preventatively repaired. Table 2-1 provides the total tube plugging history and equivalent plugging levels to date for the Byron Station Unit I SGs. Table 2-2 provides the total number of tubes plugged in the current outage by degradation mode.

Table 2-1 Equivalent Tube Plugging Level SGA SGB SGC SGD Total Tubes Previously Plugged* 0 0 1 0 I Tubes Plugged in 1 -~ 0 5 7 Current_Outage TotalTubes Plugged 1 1 1 5 8 Total Tubes Plugged (%) 0.015% 0.015% 0.015% 0.075% 0.03%

  • Tube plugged at factory during vessel fabrication.

TABLE 2-2 Tubes Repaired During Refueling Outage 13 Mode of Degradation SG A SG B SG C SG D Total Volumetric Indication at 1 1 0 0 2 Lattice Grid*

Preventively Plugged to 0 0 0 5 5 Bound Foreign Object Outage 13 Plugging Totals 1 1 0 5 7

  • Attributed to foreign object wear, although no indication of an object was present 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 Ill in accordance with American Society for Nondestructive Testing Recommended Practice No. SNT-TC-IA (1984 Edition), 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 2 and Exelon procedure ER-AP-335-040, Evaluation of Eddy Current Data for Steam Generator Tubing, Revision I were used for the data acquisition and analysis.

3.1.2 The examinations, equipment and personnel qualifications were in compliance with the requirements of Exelon and Westinghouse Quality Assurance Programs for Inservice Inspection, Byron Station Technical Specification 5.5.9, ASME B&PV Code, 1989 Edition, Section Xl, Rules for Inservice Inspection of Nuclear power Plant Components, and Section V, Nondestructive Examination, EPRI Page 4 of 46

PWR SG Examination Guidelines, Revision 6 and NEI 97-06, Steam Generator Program Guidelines, Revision I.

3.1.3 Certification packages for examiners, data analysts and equipment are available at Byron Station. Table A.1 and Table A.2 lists all personnel who performed, supervised or evaluated the data during this SG inservice inspection.

3.1.4 R/D Tech Inc. TC6700 Remote Data Acquisition Units (RDAU5) with Westinghouse ANSER Version 8.4.1, Revision 232 computer software were used to acquire the eddy current data. Analysis was performed with Westinghouse ANSER Version 8.4.3, Revision 13 computer software. Secondary analysis was performed with CoreStar EddyVIS ION 32 Version 5.7.1 computer software.

3.1.5 The bobbin coil examinations were performed with Zetec and R/D Tech 0.560 inch diameter probes. Zetec and R/D Tech 0.540 inch diameter probes were used in low row tubes.

3.1.6 The rotating coil examinations were performed with Zetec 0.560 inch diameter high frequency three coil plus-point probe for examinations in the straight portion of the tube. The coils within this probe were a 0.115 inch diameter pancake coil, a shielded 0.080 inch diameter pancake coil and a standard plus-point coil. For examinations in the U-bend region, a Zetec 0.520 inch diameter high frequency plus-point probe was used.

3.2 Personnel 3.2.1 The personnel who performed the SG eddy current inspections were qualified to Level I and Level II certification in accordance with the 1984 Edition of SNT-TC-IA. The Level I personnel performed the inspections under the direct supervision of Level II personnel. A list of the certified eddy current personnel who conducted data acquisition is contained in Table A.I.

3.2.2 The personnel who performed the SO 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-IA and Article lV-2000 of ASME Section XI, 1989 Edition. A list of the certified eddy current personnel who conducted data analysis is contained in Table A.2.

3.2.3 All eddy current data analysts were qualified in accordance with the EPRI Guidelines, 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 plus-point inspection data analysis techniques. Resolution analysts were also trained and tested specifically for the performance of data resolution. All analysts were required to achieve a probability of detection of 80% or greater with 90% confidence level on practical examinations and a minimum score of 80% on the written test prior to analyzing data.

3.2.4 All SO eddy current data acquisition personnel were trained and tested in accordance with a site specific performance demonstration program. The data Page 5 of 46

acquisition operators were required to achieve a written test score of 80% or greater prior to acquiring data.

3.2.5 The SO eddy current analysis was subject to two independent analyses. Primary analysis of all data was performed by Westinghouse, with NDE Technology, Corestar and Master-Lee as sub-contractors. An independent company, Anatec, performed the secondary analysis. Primary and secondary analysis was performed by an automated data screening analysis system as described in Section 6.3.3.3 of the EPRI PWR Steam Generator Examination Guidelines, Revision 6. The analysis systems were operated in the manual interactive mode.

Each system was required to successfully pass the industry Automated Analysis Perform Demonstration Qualification and the site specific performance demonstration practical examination prior to analyzing field data.

3.2.6 An independent SO eddy current Level III QDA was employed to serve as a process control reviewer, in accordance with EPRI Guidelines, Section 6.3.3.2, to randomly sample the data to ensure the resolution process was properly performed and that the field calls were properly reported. The Independent Level Ill QDA 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 provide a data quality check of acquired data.

The Independent Level III QDA was employed by, NDE Technology, and reported directly to the Exelon Level Ill inspector.

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

4.1 Examination Techniques 4.1.1 100% of the inservice tubes were inspected full length utilizing 0.560 inch diameter bobbin coil probes described in Section 3.1.5 of this report. For low row tubes regions where there was difficulty using the 0.560 inch diameter probe over the U-bend, a 0.540 inch diameter bobbin probe was utilized. Nominal probe inspection speed was 40 inches per second for tube rows greater than row 8 and for straight tubing inspection in tube rows 8 and less. Nominal probe inspection speed was 24 inches per second for rows I through 8 U-bend regions and straight sections where the probe traversed through the U-bend. Sufficient sampling rates were used to maintain a minimum digitizing rate of 30 samples per inch. The bobbin probes were operated in the differential and absolute modes at frequencies of 650 kHz, 320kHz, 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, 650/320/1 60 kHz differential mix, and a 650/320 kHz differential mix.

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4.1.2 20% of the tubes in each SG were inspected at the hot leg top of tubesheet expansion transition region (+1- 3 inches) with a three-coil plus-point probe as described in Section 3.1.6. Axial probe inspection speed was 0.6 inches per second. 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 were operated in the absolute test mode at frequencies of 300 kHz, 200kHz, 100 kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display circumferential indications in the positive trace.

4.1.3 Diagnostic examinations were planned for non-quantifiable indications and hot leg dents/dings greater than or equal to 2.0 volts that may be detected by the bobbin coil examination. The diagnostic examinations were to utilize a three-coil plus-point probe as described in Section 3.1.6. Axial probe inspection speed was 0.6 inches per second for straight tubing, 0.15 inches per second for dents/ding locations and 0.35 inches per second for U-bend regions of the tubing. 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 were operated in the absolute test mode at frequencies of 300 kHz, 200kHz, 100 kHz and 20 kHz.

U-bend examinations were performed at frequencies of 400 kHz, 300 kHz, 100kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display circumferential indications in the positive trace.

4.1.4 The eddy current calibration standards used for the bobbin coil and plus-point inspections met the requirements of Section 6.2.7 of the EPRI PWR Steam Generator Examination Guidelines, Revision 6 and Sections V and Xl of the ASME B&PV Code, 1989 Edition.

4.1.5 The SG eddy current examination techniques used during this inspection were equivalent to the EPRI Appendix H techniques listed in Table 4.1-I. Each technique was evaluated and determined to be applicable to the site conditions.

Table 4.1-1 EPRI Appendix H Techniques EPRI Degradation Revision Probe Location Mode Orientation Technique 96004.3 9 Bobbin Fan Bar Wear Vol 96004.3 9 Bobbin Lattice Grid Wear Vol 96004.3 9 Bobbin Foreign 96910.1 8 Plus-Point . Wear Vol Object/Freespan 21998.1 3 PIus-Point 4 Sludge Pile, 21409.1 Plus-Point Freespan Regions, ODSCC Axial Support Structures 21410.1 4 PIus-Point TTS Expansion ODSCC Circ 20511.1 7 Plus-Point TTS Expansion PWSCC Axial 20510.1 5 Plus-Point TTS Expansions PWSCC Circ 96703.1 15 Plus-Point Dents/Dings PWSCC Axial Page 7 of 46

Technique Revision Probe Location Mode Orientation 20510.1 5 Plus-Point Dents/Dings PWSCC Circ 22401.1 3 Plus-Point Dents/Dings ODSCC Axial 21410.1 4 PIus-Point Dents/Dings ODSCC Circ Tube Support Plate 96008.1 13 Bobbin IGA/ODSCC Axial

& Sludge Pile Tube to Tube Wear Vol 96004.3 9 Bobbin Contact 96010.1 6 Bobbin Freespan MBMs Vol

- ITS Top of Tubesheet

- IGA/ODSCC lntergranular Attack/Outer Diameter Stress Corrosion Cracking

- PWSCC Primary Water Stress Corrosion Cracking

- Vol Volumetric

- Circ Circumferential

- MBM Manufacturing Burnish Mark 4.2 Steam Generator Inspection Scope 4.2.1 100% of the inservice tubes in each SG were inspected full length utilizing a bobbin coil probe described in Sections 3.1.5 and 4.1.1 of this report.

4.2.2 20% of the tubes in each SO were inspected at the hot leg top of tubesheet expansion transition region (+1- 3 inches) with a three-coil plus-point probe as described in Sections 3.1.6 and 4.1.2.

4.2.3 Diagnostic examinations were performed for non-quantifiable indications 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 performed to investigate potential foreign object signals and extent of condition for the potential foreign objects. Diagnostic examinations were also performed to confirm that indications at fan bar and lattice grid locations were associated with wear. Thirty-seven percent (37%) of the fan bar indications and 100% of the lattice grid indications were included in the diagnostic examinations. These special examinations are performed with the plus-point probe described in Sections 3.1.6 and 4.1.3 above. A total of 124 tubes were inspected as a result of these diagnostic examinations.

4.2.4 Figures B.1 through B.22 contain tube sheet maps indicating the tube inspections that were performed Refueling Outage 13.

4.3 Recording of Examination Data Results of the SO eddy current data analysis were recorded on optical disks. The data was then loaded into a Westinghouse SG eddy current data management system. The system was used to track the completion of the examinations and was used to generate the final SG eddy current report summaries.

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4.4 Witness and Verification of Examination SO eddy current inspections were witnessed and/or verified by Authorized Nuclear Inservice Inspectors, Mr. Jeff Hendricks and Mr. Lee Malabanan of the Hartford Steam Boiler Inspection & Insurance Company of Connecticut, Chicago Branch, 2443 Warrenville Road, Suite 500, Lisle, Illinois 60532-9871.

ASME Form NIS-1, Owners Report for Inservice Inspections, is shown in Attachment C.5.

5.0 EXAMINATION RESULTS 5.1 Eddy Current Inspection 5.1.1 Fan Bar Wear Tube degradation was found during the bobbin coil examination in the U-bend region due to fretting of the Fan Bars on the tube. A total of 46 indications in 42 tubes were reported. The EPRI Appendix H bobbin coil examination technique 96004.3, Revision 9, was utilized in this inspection for the depth sizing of fan bar wear. The largest indication found was 21 % through wall (TW). No tubes were plugged as a result of these indications. Table 5.1.1-1 provides a summary of fan bar wear degradation. Table 5.1.1-2 provides a listing of all fan bar wear indications found during Refuel Outage 13.

Table 5.1.1-1 Refuel Outage 13 Fan Bar Wear Summary SGA SGB SGC SGD Total Ind. Ind. Ind. Ind. md.

<10%TW 6 7 2 11 26 10-19%TW 3 8 0 8 19 20-39%TW 0 1 0 0 1

>=40%TW 0 0 0 0 0 TOTAL* 9 16 2 19 46 Table 5.1.1-2 Refuel Outage 13 Fan Bar Wear Indications Ind. SG Row Column Depth Location* Inch No.

1 IA 60 93 5% F06 -1.2 2 IA 64 65 10% F06 +0.47 3 IA 66 55 6% F05 -0.61 4 IA 70 55 7% F03 +0.64 5 IA 72 63 4% F05 -0.84 6 IA 75 58 9% F05 -0.58 7 IA 78 51 14% F05 +0.95 8 IA 86 71 6% F05 -1.34 9 IA 86 71 16% F06 +1.36 10 lB 35 84 7% F05 -0.33 II lB 64 57 14% F06 -0.13 Page 9 of 46

lnd. SG Row Column Depth Location* Inch No.

12 lB 67 62 7% F01 -1.32 13 lB 75 60 4% F02 -1.82 14 lB 81 62 7% F06 +1.06 15 lB 82 63 11% F06 +2.26 16 lB 86 63 12% F05 +0 17 lB 86 63 21% F06 +1.15 18 lB 87 90 10% F06 +1.45 19 lB 91 64 11% F06 +0.38 20 lB 95 66 9% F05 -0.7 21 lB 97 64 17% F06 +0.36 22 lB 101 74 10% F05 +1.46 23 lB 102 107 11% F05 +0.25 24 lB 109 56 7% F08 +0.49 25 lB 114 79 7% F05 +1.18 26

  • IC 52 79 4% F05 -1.22 27 IC 53 92 6% F05 -0.93 28 ID 58 79 6% F06 +0.65 29 ID 65 90 6% F06 +1.74 30 ID 69 82 8% F05 -0.37 31 ID 72 65 7% F06 +1.37 32 ID 82 67 11% F06 +1.09 33 ID 90 67 11% F06 +1.4 34 ID 99 66 7% F05 +1.36 35 lD 103 68 12% F06 +0.57 36 ID 105 66 7% F05 +1.43 37 ID 106 63 10% F04 +1.3 38 ID 106 63 10% F05 +1.2 39 1D 106 65 8% F06 -1.43 40 ID 106 65 7% F07 +1.5 41 1D 106 67 9% F06 +2.02 42 ID 107 60 11% F06 -0.53 43 1D 112 61 10% F06 +1.4 44 ID 113 58 7% F06 +0.51 45 ID 113 64 10% F05 -0.95 46 ID 113 68 9% F06 +0.95
  • Fan Bar Support Number 5.1.2 Lattice Grid Wear One tube (tube R51-C8 in SG D) was found that contained and indication of wear caused by fretting from the lattice grid support number 8 on the cold leg side (i.e., lattice grid number 08C). The depth of the lattice grid wear was 3% 1W as measured by the EPRI Appendix H qualified bobbin coil examination technique 96004.3, Revision 9. The indication was further inspected with the plus-point probe to confirm the degradation mechanism was lattice grid wear. No tubes were plugged as a result of lattice grid wear. Table 5.1.2-I provides a listing of all lattice grid wear indications found during Refuel Outage 13.

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Table 5.1.2-1 Refuel Outage 13 Lattice Grid Wear Indications Ind. SG Row Column Depth Location Inch No.

I ID 51 8 3% 08C -1.72 5.1.3 Foreign Obiect Wear Tube degradation was found in two (2) tubes that was attributed to foreign object wear during the current inspection. The indications were 14% TW and 23% TW as measured by the EPRI Appendix H plus point qualified examination technique 21998.1, Revision 3. The indications were volumetric in nature and located within the lattice grid structures, but were not characteristic of lattice grid wear. The indications were located away from the lattice grid to tube contact points and were indicative of foreign object wear, however, no indication of foreign objects was detected by eddy current. Both tubes were preventatively removed from service. Table 5.1.3-I provides a listing of the tubes that contained foreign object wear found during Refuel Outage 13.

Table 5.1.3-1 Refuel Outage 13 Lattice Grid Volumetric Indications Summary Ind. SG Row Column Depth Location Inch

, No.

I IA 38 61 14% 07H -1.53 2 lB 88 119 23% 09H +0.48 5.1.4 Other Inspection Results During the bobbin coil inspection of the row I tubes, it was discovered that the fan bar collector bar did not completely engage all of the row I hot leg tubes in the I B SO as expected. Investigations revealed that the fan bar collector bar engaged or partially engaged 10 of the 67 hot leg row I tubes. The collector bar was verified to engage all row I cold leg tubes and all row 2 hot leg tubes. Additionally, the fan bar collector bar was verified to be engaged in all row I hot leg and cold leg tubes in SGs IA, IC and ID. Further investigation showed that this condition was present in the baseline pre-service inspection.

Discussions with the original equipment manufacturer, Babcock & Wilcox Canada (B&VV), concluded that the fan bar collector bar was most likely mis-positioned during a fabrication repair that re-positioned the fan bar support structures called J-tabs. The j-tabs support the fan bar support arch bars and tie bars on the tubes. B&W performed a tube flow induced vibration analysis for the tubes where the collector bar did not properly engage the row I hot leg tubes.

This analysis concluded that no fluid elastic instability issues exist for the as-found condition and that the condition is acceptable. Operating experience supports this conclusion in that no tube wear or degradation has occurred in the I B SG row I tubes at the lattice grid support or the cold leg collector bar locations.

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5.2 Visual Inspection of Installed Tube Plugs All previously installed tube plugs (i.e., two shop welded plugs) were visually inspected for signs of degradation and leakage. No evidence of degradation or leakage was detected.

6.0 REPAIR

SUMMARY

Seven (7) tubes were repaired by tube plugging during this inspection. Five (5) of those tubes were also stabilized prior to tube plugging. The repairs were conducted in accordance with ASME Section Xl, 1989 Edition. All tube plugging was performed by Westinghouse using AIIoy-690 mechanical tube plugs. All repairs were performed in accordance with approved Westinghouse procedures.

Table 6-I depicts the repairs conducted during this inspection. Table 6-2 lists the tube locations that were repaired during this inspection.

TABLE 6-1 Summary of Refueling Outage 13 Tube Plugging REPAIRS PERFORMED SGA SGB SGC SGD TOTA[1 Tubes Plugged* 1 1 0 5 7 Tubes Stabilized 0 0 0 5 7

  • Includes number of tubes stabilized and plugged.

TABLE 6-2 SG Tubes Repaired During Refueling Outage 13 SG Row Col Repair Stabilizer Depth Location Comment 1 IA 38 61 Plug None 14% 07H-l.53 2 lB 88 119 Plug None 23% 09H+0.48 3 ID 103 98 Plug Hot Leg NDD - Preventatively Plugged 4 ID 102 99 Plug Hot Leg NDD - Preventatively Plugged 5 ID 104 99 Plug Hot Leg NDD - Preventatively Plugged 6 ID 101 100 Plug Hot Leg NDD - Preventatively Plugged 7 ID 103 100 Plug Hot Leg NDD - Preventatively Plugged

  • NDD No Detectable Degradation 7.0 DOCUMENTATION All original SG eddy current optical disks have been provided to Exelon and are maintained at Byron Station. The final data sheets and pertinent SG tube sheet plots are contained in the Westinghouse Final Outage Report for Byron Station Unit I, Refueling Outage I 3, and are also maintained at Byron Station.

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8.0 TABLES/FIGURES/ATTACHMENTS Table A.1 Eddy Current Data Acquisition Personnel Certifications Table A.2 Eddy Current Data Analysis Personnel Certifications Figure A.I Babcock & Wilcox Replacement Steam Generator Byron Unit 1 Configuration Figure A.2 Byron Station Unit I Steam Generator Tubesheet Configuration Figure B.I SGA Hot Leg High Row Bobbin Inspection Figure B.2 SGA Hot Leg Low Row Bobbin Inspection Figure B.3 SGA Cold Leg Bobbin Inspection Figure B.4 SGA Hot Leg Top of Tubesheet Inspection Figure B.5 SGA Hot Leg Special Interest Inspection Figure B.6 SGA Cold Leg Special Interest Inspection Figure B.7 SG B Hot Leg High Row Bobbin Inspection Figure B.8 SO B Hot Leg Low Row Bobbin Inspection Figure B.9 SG B Cold Leg Bobbin Inspection Figure B.I0 SG B Hot Leg Top of Tubesheet Inspection Figure B.II SO B Hot Leg Special Interest Inspection Figure B.l2 SO B Cold Leg Special Interest Inspection Figure B.13 SO C Hot Leg High Row Bobbin Inspection Figure B.14 SG C Hot Leg Low Row Bobbin Inspection Figure B.I5 SG C Cold Leg Bobbin Inspection Figure B.16 SO C Hot Leg Top of Tubesheet Inspection Figure B.17 SO C Cold Leg Special Interest Inspection Figure B.18 SG D Hot Leg High Row Bobbin Inspection Figure B.19 SO D Hot Leg Low Row Bobbin Inspection Figure B.20 SO D Cold Leg Bobbin Inspection Figure B.2I SG D Hot Leg Top of Tubesheet Inspection Figure B.22 SO D Hot Leg Special Interest Inspection Figure B.23 SG D Cold Leg Special Interest Inspection Attachment C.I SG A ASME Form NIS-BB Attachment C.2 SO B ASME Form NIS-BB Attachment C.3 SO C ASME Form NIS-BB Attachment C.4 SO D ASME Form NIS-BB Attachment C.5 ASME Form NIS-I, Owners Report for Inservice Inspections Page 13 of 46

TABLE A.1 EDDY CURRENT DATA ACQUISITION PERSONNEL CERTIFICATIONS Page 1 of I Name Company Level QDA

  • *** * (Yes/No)

I Bates, SR TMP/Hudson II No 2 Evering, DP Westinghouse II No 3 Fore, SK Westinghouse II No 4 Groh, TA Westinghouse II No 5 Hazlett, WE Westinghouse II No 6 Hill, WW Westinghouse I No 7 Mantich, SM TMP/Hudson I No 8 McElhinny, JW Westinghouse II No 9 Miller, GW Westinghouse II No 10 Patton, BB Westinghouse II No II Percosky, S Westinghouse I-Limited No 12 Shipley, EB Westinghouse II No 13 Vernon, DP Westinghouse II No Page 14 ot 46

TABLE A.2 EDDY CURRENT DATA ANALYSIS PERSONNEL CERTIFICATIONS Page 1 of I Name ~

  • Coflip ~ Level QDA fr

~ (Yes/No)

I Anderson, DA NDE Technology IlA Yes 2 Bell, CF Anatec Ill Yes 3 Bowser, GC Westinghouse Ill Yes 4 *Brown, ME NDE Technology lilA Yes 5 Brumet, DL Anatec hA Yes 6 Causby, OW NDE Technology lIlA Yes 7 Gootz, TE Westinghouse Ill Yes 8 Haynes, WR NDE Technology lilA Yes 9 Himmelspach, RJ Anatec Ill Yes 10 Hutchinson, J NDE Technology lIlA Yes II Kirk, MB CoreStar Ill Yes 12 Lewis, DA NDE Technology lilA Yes 13 Maben, DE Anatec Ill Yes 14 *Mast MS NDE Technology lilA Yes 15 Moates, RC Westinghouse IIA Yes 16 Mullan, WA Anatec IIA Yes 17 Obazenu, DJ Anatec Ill Yes 18 Padgett, LT Master-Lee hA Yes 19 Popovich, R Westinghouse Ill Yes 20 Raper, U Anatec Ill Yes 21 Raschiatore, J Westinghouse Ill Yes 22 Rehak, RD Master-Lee hA Yes 23 Richmond, MA NDE Technology lilA Yes 24 Sheldon, JT NDE Technology lIlA Yes 25 Siegel, RA NDE Technology lilA Yes 26 Skirpan, JR NDE Technology lIA Yes 27 Stanger, DA Anatec Ill Yes 28 Stock, WF Westinghouse Ill Yes 29 Tan, JM Anatec IlA Yes 30 Wadaga, SM Anatec IlA Yes

  • Independent Level III Qualified Data Analyst Page 15 of 46

FIGURE £1 Babcock & Wilcox Replacement Steam Generator Byron Unit 1 Configuration SECONOARY HANWAY SECONDARY DEOC PRIHARY DECK FEEDWATER NOZZLE RECIRCILATIGN NOZZLE (tvP)

LATTICE GRID I USPECT I ON PORTS (TYP) lOGESHEET HANOMOLE GLOi~DOWN NOZZLE PRIMARY HEAD VERTICAL StPPCRF PAD REAC OR COC&,AN1 NOZZLE Page 16 of 46

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Page 17 of 46

FIGURE B.1 SG A Hot Leg High Row Bobbin Coil Inspection CAE-A HOT LEG .560 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column 1 is over the MANWAY ByroriBlRl3 CAE7720 c 6~7~ TESTED TEC TI4ROUGH TEM lAS 135 110 125 125 115 ItS 155 15* 95 95 95 9. 75 70 66 65 55 5. 4~ 4.S 15 3* 25 2~ 15 iS 115 I I I iS

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Page 18 of 46

FIGURE B.2 SG A Hot Leg Low Row Bobbin Coil Inspection CAE-A HOT LEG .540 BOBBtN INSPECTION PROGRAM AS T*ESTED Row 4 Column 1 is over the MANWAY

~yronB1R13 CAE7720 Z 31 TESTEEJ TEC THRO4JtUi TEll 0 9 TESTED F1~THROUGH TEH F 2 TESTED ~6C THROUGH TEH ~ 1 TESTED FSI THROUGH TEH H 2 TESTED aBC THROUGH TEll W 2 TESTED ~7C THROUGH TEll \ 18 T[STED ~9H THROUGH TEN fl 49B TESTED 09C THROUGH TEll 141 lIE. 135 L25 125 115 11* 155 155 96 55 55 I~5 75 7~ 65 65 55 S. 46 45 36 iS 26 2* 15 1* 5 l1!_ I. - .~ *  : :  : I  : ~ ~_: 116 11* .  : -: *:  : : . 11*

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Page 19 of 46

FIGURE B.3 SG A Cold Leg Bobbin Coil Inspection CAE-.A COLD LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I Is over the MANWAY GyronBlRl3 CAE7720 ii 24 TESTED 09H THROUGH TEC 0 7 TESTED FiG THROUGH TEC

/ 501 TESTED 090 THROUGH TEC 135 tl* 12 6 12* 1 15 115 1*5 15* 9* 96 8*75 7* 65 85 55 6* 45 45 35 1* 25 20 15 IITIC cI~3 .,c~3 115 liE. +~ .* ~t .~ 00+

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~It0aftslw LI.C-8T PM. 8515/SE ~9.S4 Page 20 of 46

FIGURE BA SG A Hot Leg Top of Tubesheet Inspection CAE-A HOT LEG TOP OF TUBESHEET INSPECTION PROGRAM Row 4 Column I is over the MAN WAY ByronBlRI3 CAE7720 1 1327 TEST TSH / 3 INCHES DURING 01R13 145 135 110 125 12* 115 11* 1*5 1*4 95 9* 25 as 75 7* + 85 65 55 55 45 45 35 15 25 2* 15 15 S 4310 1 1.15 116 115

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Page 21 of 46

FIGURE B.5 SG A Hot Leg Special Interest Inspection CAE-A HOT LEG SPECIAL INTEREST +POINT INSPECTION PROGRAM Row 4 Column i is over the MANWAY Byron B1R13 CAE7720 K 54 TUBE TESTED FOR SPECIAL INTEREST IN THE HOT LEG 144 135 130 12S 120 115 115 105 154 95 98 95 8* 75 7* 6S 6* 55 55 4,5 44 35 34 25 2* 15 15 5

  • *,~J 3 ~I 2.

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FIGURE B.6 SG A Cold Leg Special Interest Inspection CAE-A COLD LEG SPECIAL INTEREST +POINT INSPECTION PROGRAM Row 4 Column us over the MANWAY Byron B1RI3 CAE772O X 1 TUBE TESTED FOR SPECIAL INTEREST IN THE COLD LEG 1-4* 135 118 1-25 129 115 11* 105 1*4 95 9* 05 9* 767* I/S 60 5-5 55 45 4* 35 3* 25 20 15 1* 5 1 00/1 4, Ci::~+

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FIGURE B.7 SG B Hot Leg High Row Bobbin Inspection CAE-B HOT LEG .560 BOBBIN INSPECTION AS TESTED Row 4 Column I ~sover the NOZZLE Byron BIRI3 CAE 7720 6~7RTESTED TEC THROUGH TEH 14* 135 110 1.25 120 115 105 1*4 95 9* 25 8* 75 70 85 60 55 /1* 45 4* 35 3* 25 2* 15 1* 5 1151 Il_lI liii,,

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Page 24 of 46

FIGURE B.8 SG B Hot Leg Low Row Bobbin Inspection CAE-B HOT LEG .540 BOBBIN INSPECTION AS TESTED Row 4 Column us over the NOZZLE Byron B~R13 CAE 7720 9 663 TESTED ØOC THRDUGH TEH 14* 135 110 125 120 115 11* 105 1*4 95 9* 85 9* 76 70 85 60 55 6* 45 4* 36 3* 25 20 15 1* 5 313 ~ ~ ~,J+ bOo 115 ii 11* 1 11,.

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999 999 9999 999; 9299 9999 El~9~9999 9999 99~ 9999 9999 9999 9999 53 C1 J~9~ 9999 9999 9999 2999 9999 2919 ~

1 9 ~ 9999 9999 9999 9999 9999 ~9~9 9~9~ ~a~s 9999 9999 a~i~9999 ~

9999 9999 9999 9999 9 9 14* 135 110 126 120 115 114 105 1*4 95 96 05 04 75 70 66 60 55 6* 45 4* 35 3* 26 20 15 1* 6 IFMSna,s B~itCcavsrwUt -93 Pt, 051412(5. 131400 Page 25 of 46

FIGURE B.9 SG B Cold Leg Low Row Bobbin Inspection CAB-B COLD LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I is over the NOZZLE ByronBuRu3 CAE7720 9 663 TESTED 09C ThROUGH TEC 14* 135 110 125 120 115  :. scis iii 96 9* 95 9*75 70,66 60 55 5* 45 4* 35 30 26 20 15 14 6 3)_I,;). 4.

115 1 114 I I 11*

1*6 I 1*5 104 1*4 aS 1 ,I 96 94 94 86 86 94 9*

75 75 7*  :> 7*

U 86 6* 4 *b* 4 I +b**4*4+I~b44lib~ ~

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~ ~ 9~9~~ 9~9~  %~ 9~9~ ~ 9~9~~ g~~O~ ~ ~ 9999 9999 9999 9999 9999 999 -1~9~9,1) 9999 9999 ~9~9 9999 9999 99 1* ~ &

999 1~9 9999 9~9~ 9999 9999 9999 9999 9999 9999 9999 ?~J~~9~9 9999 9999 9999 9999 9999 9999 9999 l~F~ I1,j)~ 9999 9999 9~9 9999 9999 9 9 1I* 135 130 125 120 116 114 1*5 1*4 96 90 /15 90 75 70 86 60 55 54 4/1 4* 36 3* 25 20 16 10 5 WcflbaS SoWtCbfrtibqi Ut -ST Pt, 0514~5 i11127 Page 26 of 46

FIGURE B.1O SG B Hot Leg Top of Tubesheet Inspection CAE-B HOT LEG TOP OF TUBESHEET INSPECTION PROGRAM Row 4 Column I ~sover the NOZZLE Byron BIRI3 GAE7720 T 1327 TEST TSH -I~ 3 INCHES 14* 135 110 125 120 115 11* 106 14* 95 90 95 80 75 70 85 60 55 50 45 4* 35 3* 25 20 11 1* 5

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115 115

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11* 110

=:-4T :T~-:~: -:~::~:-  :.: t.:

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FIGURE B.11 SG B Hot Leg Special Interest Inspection CAB-B HOT LEG SPECIAL INTEREST POINT INSPECTION PROGRAM Row 4 Column 1 Is over the NOZZLE ByronRlRl3 CAE 7720 x 43 TUBE TESTED FOP SPECIAL INTEREST IN THE HOT LEG 14* 135 130 125 120 115 11* 105 10* 95 90 91 80 7670 86 80 55 60 45 4* 35 3* 26 20 15 1* 5 115 . 2~. C~t~~

1 +

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,+,,++,,o 43 3 I :Th~ *030, 3 I7__ .

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9. 9*

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14* 115 110 125 120 115 11* 105 1*0 96 90 95 90 75 70 85 80 55 50 45 4.4 *5 3* 25 20 15 1* 5 Beu~ry lit-ST Pt, 0*15t2~ilille Page 28 of 46

FIGURE B.12 SG B Cold Leg Special Interest Inspection CAE-B COLD LEG SPECIAL INTEREST i-POINT INSPECTION PROGRAM Row 4 Column I ~sover the NOZZLE Byron 81R13 CAE7720 X 1 TUBE TESTED FOR SPECIAL INTEREST IN THE COLD LEG 144 135 130 126 120 115 11* sos i0* 95 90 85 00 75 70 85 80 55 50 45 4* 35 3* 25 20 15 10

c;H~o~o ~.) ,:..,::

c 3.0 115 - 115 3

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105 - 1*5

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a. a.

0 85 ,~, 0,, *b ,., 95 04 a.

- ~+ yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr.

7S - -~IC~ yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr yr 76 4 ++,,4+,.,b,+II,..*..,.,.,+

7. -~ ,.+,.,*,*+-...,*..+,...++,.+,,,+,,. 7*

85 85

.I..,,+...,.,..* +

80 84 55 65

5. 5*

yr yr yr yr yr yr yr 45

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330 &1 i  : 0.331 o~o~ 00001 GO 10. I~133 c :01 ~O~3 o~3 TO_I..:  :..: 3330 000.3 .31330~OcO:I~ .J 3.:.. .. ..~, ~ ,~, cc.

14* t36 130 125 120 115 11* 105 104 95 90 95 9* 75 70 65 68 55 5* 45 4* 35 31* 25 20 15 10 5

~rn,~~bSCa1Ul, LLC - ST. O51~ 1401.43 Page 29 of 46

FIGURE B.13 SG C Hot Leg High Row Bobbin Inspection CAE-C HOT LEG .560 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I is over the MANWAY Byron 81R13 CAE 7720

~i 6~65 TESTED TEC THROUGH TEH 9 4 TESTED ~9C THROUGH TEll

~ 1 PLUG~DTUBE 14* 135 130 125 120 115 11* 105 204 95 Ii) 05 9* 75 70 65 80 55 50 46 4* 35 j8 25 20 15 10 11.5 11.5 11.* 11*

1*6 105 11* 104 I . 1111 II I 95 1 95

~

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, r1,_ ~ll li (1_ICICI cc ,. . I I I I I I 1 , I I 11, 70 7.

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~ I 86 I I I flfl 86 II (4 1 13 I 1 - ~ I I I ~ I I,: I I,, U 00 I II

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80 - -3~ nv- ~ -r--~ . r-- yr ~~ -~- yr ~ ~n~n 80 56 I1~fl~I ~  : . 1 rI I ~

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14* 136 130 1.26 120 115 110 105 104 95 90 86 90 75 70 85 50 55 50 45 4.0 36 3* 25 20 15 10 5

~t~+i ~ Ca+v~ LI,C-ff(Pt. II&16/~ i~G1 Page 30 of 46

FIGURE B,14 SG C Hot Leg Low Row Bobbin Inspection CAE-C HOT LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column 1 Is over the MANWAY Byron 81R13 CAE 7720 o 2 TESTED 8C THROUGH TEll n 541 TESTED ØQC THROUGH TEH / 8 TESTED @9H THROUGH TEH o 12 TESTED rim THROUGH TELl a 1 PLUGGED TUBE 4* 136 11* 125 120 116 110 106 10* 95 9* 96 90 75 70 85 60 55 60 45 4* 35 3* 25 20 16 1* 5 115 11 11* 110 105 1*5 10* _:, ~~ ~-~~~ ~  : 100 95 1 1 95 90 9*

8 95 90 90 75 3 76 70 7*

as 60 -, .- 80 56 ,: * ~, ~ , 66 45 ZI....... .,, .. ,,.,, ..,,,., +,, .,.,,;. 45 4* ~ 4*

3S ~ ~::::::  :~:::::::  ::i:~:::~::::~::  ::

30 41,. ..,.. 34 26 - 26 20 0 16 *

  • I +~ I 1+. - I ~

10 ~ 4. , . -I ~, 4 1(I +4 1+ .. II~(lI+~~4l 14 (1~fl~IrIInU I..Il~ n~I-1~I ~n~r ,4n~ dn 11h1.fl ~I~rI

~

I3~I1 II~III (11 ~

Iii ~(1~fl ;Igfl~4 ~!I1~I1 fl~fl~flflflll 1I~11~?~rI~fl fiflfi~ ilflfi 11+

11~II~~r4~I1 flhlflIl ~41l~4Il1I~I4 t~

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~ Bst,frCa,+,so~ tiC-ST Ma, O&i~PX4~iT ii t Page 31 of 46

FIGURE B.15 SG C Cold Leg Bobbin Inspection CAE-C COLD LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I Is over the MANWAY ByronBlRI3 CAE 7720 Il 8 TESTED SSH THROUGH TEC ~ 2 TESTED B9C THROUGH TE C 557 TESTED FiG THROUGH TEC ~ ~ PLUGGED TUBE 14* 135 130 125 120 115 11* 105 10* 95 90 06 90 7570 M 00 55 5* 45 4* 35 II 25 20 15 1*

.3 I>13 3.~.++ ~. . I ~ ~ , 1~%-i, ~

~4r-(.3 1 0 0..

115 116 110 I 10 11*6 - -~ 2St~2-2 105 13 00 10* 100 95 1 95

a. - 3, a.

95 1~10 as 90 a.

75 76 7* 7*

65 85 6* 60 55 55 6* 5*

46 45 4* 4*

35 15 3* S.

26 25 2* 2*

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6 E I;.I) o~o~ ~o~o~

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FIGURE B.16 SG C Hot Leg Top of Tubesheet Inspection CAE-C HOT LEG TOP OF TUBESHEET INSPECTION PROGRAM Row 4 Column I is over the MANWAY ByronBlRI3 CAE 7720 T i327 TEST 1511 -1+ 3 INCHES DURING 81R13 U i PLUGGED TUBE 4* 135 130 .25 12* 116 11* 1*6 10* 95. 9* 85 0* 7570 65 60 55 5* 46 44 35 3* 25 20 16 1* 5 115 11.5 X~T~, TT ~!

+~ ~!

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Page 33 of 46

FIGURE B.17 SG C Cold Leg Special Interest Inspection CAE-C COLD LEG BOBBIN INSPECTION PROGRAM Row 4 Column 1 Is over the MANWAY ByronBlRI3 CAE7720 I,) 563 TEST ~9H THROUGH TEC a i PLUGGED TISE 14* 135 13* 125 120 116 114 105 1*4 96 9* 95 9* 75 70 85 60 55 5* 45 4* 35 3* 25 2* 15 1*

C ~ :1~- -~ ~ L 3~0 -~

115 - 0~1 9-403 115 C

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FIGURE B.18 SG 0 Hot Leg High Row Bobbin Inspection CAE-D HOT LEG .560 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column us over the NOZZLE ByronBlRi3 CAE7720 I 6~~~ESTEi3 TEC THROUGH TEH 14* 135 130 126 120 115 110 105 10* 95 00 £45 8* 76 70 65 00 55 6* 45 44 35 3* 26 20 15 1* 5 1

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~ 11+0-5? Ma. 9~151.XI)S it4*06 Page 35 of 46

FIGURE B.19 SG 0 Hot Leg Low Row Bobbin Inspection CAE-D HOT LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I is over the NOZZLE ByrorB1R13 CAE7720 W 1 TESTED 07C Tt-IROIJGH TEll 0 75 TESTED FlO THROUGH TEH ti 427 TESTED OQC THROUGH TEH ~ 6~TESTED 09H THROUGI4 TEH 14* 135 130 125 126 115 110 105 1*4 95 90 ~ ~ ~ 60 65 50 45 4* 35 3* 25 2* iS 14 6 115 - : :  ::  : . :1 115 14 -  : 1 - 11*

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Page 36 of 46

FIGURE B.20 SG 0 Cold Leg Bobbin Inspection CAE-D COLD LEG .540 BOBBIN INSPECTION PROGRAM AS TESTED Row 4 Column I is over the NOZZLE ByronBlRl3 CAET72O I) 62 TESTED 091 THROUGH TEC O 349 TESTEO FlO THROUGH TEC

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~fla S~ItCa*fiS*~1.1+0 - ST PM, 001512015 ia20Z Page 37 of 46

FIGURE B.21 SG 0 Hot Leg Top of Tubesheet Inspection CAE-D HOT LEG TOP OF TUBESHEET INSPECTION PROGRAM Row 4 Colum 1 is over the NOZZLE ByrOnB1RI3 CAE7720 1 1327 TEST TSH -I~-~~ 3 INCHES DURING B1R13 Us 110 126 120 uS 114 105 1*4 95 9* 05 80 75 70 86 80 55 5* 45 4* 35 3* 26 217 15 1* 5

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1.~flt~it ~1I~ YSIW US-ST Mi. 0015I2035 11-11248 Page 38 of 46

FIGURE B22 SG 0 Hot Leg Special Interest Inspection CAE-D HOT LEG SPECIAL INTEREST ÷POINTINSPECTION PROGRAM Row 4 Column I is over the NOZZLE ByronBlRl3 CAE7720 7 23 TUBE TESTED FOR SPECIAL INTEREST IN THE HOT LEG 14* 135 130 125 12* 116 11* 105 1*0 95 90 ~ _55 5, 45 4* ~ ~ 25 2* 15 1* S

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FIGURE B.22 SG 0 Cold Leg Special Interest Inspection CAE-D COLD LEG SPECIAL INTEREST i-POINT INSPECTION PROGRAM Row 4 Column I is over the NOZZLE ByronBlRl3 CAE772O x 1 TUBE TESTED FOR SPECIAL INTEREST IN THE COLD LEG 14* 135 130 126 120 15 110 106 1*4 95 9* 05 8* 76 70 85 60 55 60 45 4* 36 3* 26 20 15 1* 5

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~t.a,s BtIfiCsIItthIw US .SIPM.. 0Y1512015 ,tt:t Page4O of 46

ATTACHMENT C*1 ASME Section XI Form NIS-BB IA Steam Generator EDDY CURRENT EXAMINATION RESULTS REFUEL OUTAGE 13 Site: Byron Station, Unit I Steam Generator: IRCOIBA Test Frequency: 35, 160, 320, 650 kHz Date: 3/14/2005

  • 20, 100, 200, 300 kHz (MRPC)

% Tube Wall Row Column Penetration Origin Location nc~i 38 61 14 OD 07H -1.53 60 93 5 OD F06 -1.2 64 65 10 OD F06 047 66 55 6 OD F05 -0.61 70 55 7 OD F03 0.64 72 63 4 OD F05 -084 75 58 9 OD F05 -0.58 78 51 14 OD F05 095 86 71 6 OD F05 -134 86 71 16 OD F06 1.36 Page 41 of 46

ATTACHMENT C.2 ASME Section XI Form NIS-BB lB Steam Generator EDDY CURRENT EXAMINATION RESULTS REFUEL OUTAGE 13 Site: Byron Station, Unit I Steam Generator: IRCOIBB Test Frequency: 35, 160, 320, 650 kHz Date: 3/14/2005

  • 20, 100, 200, 300 kHz (MRPC)

%TubeWall Row Column Penetration Origin Location Inch 35 84 7 OD F05 -0.33 64 57 14 OD F06 -0.13 67 62 7 OD FOl -1.32 75 60 4 00 F02 -1.82 81 62 7 00 F06 1.06 82 63 11 OD F06 2.26 86 63 12 OD F05 0 86 63 21 00 F06 1.15 87 90 10 00 F06 1.45 88 119 23 00 09H 0.48 91 64 11 OD F06 0.38 95 66 9 OD F05 -0.7 97 64 17 00 F06 0.36 101 74 10 OD F05 1.46 102 107 11 OD F05 0.25 109 56 7 OD F08 0.49 114 79 7 OD F05 1.18 Page 42 of 46

ATTACHMENT C.3 ASME Section XI Form NIS-BB IC Steam Generator EDDY CURRENT EXAMINATION RESULTS REFUEL OUTAGE 13 Site: Byron Station, Unit I Steam Generator: I RCOI BC Test Frequency: 35, 160, 320, 650 kHz Date: 3/14/2005

  • 20, 100, 200, 300 kHz (MRPC)

% Tube Wall Row Column Penetration Origin Location Inch 52 79 4 OD F05 -1.22 53 92 6 OD F05 -0.93 Page 43 of 46

ATTACHMENT CA ASME Section XI Form NIS-BB ID Steam Generator EDDY CURRENT EXAMINATION RESULTS REFUEL OUTAGE 13 Site: Byron Station, Unit I Steam Generator: IRCOIBD Test Frequency: 35, 160, 320, 650 kHz Date: 3/14/2005

  • 20, 100, 200, 300 kHz (MRPC)

%Tube Wall Row Column Penetration Origin Location Inch 51 8 3 OD 080 -1.72 58 79 6 00 F06 0.65 65 90 6 OD F06 1.74 69 82 8 OD F05 -0.37 72 65 7 00 F06 1.37 82 67 11 OD F06 1.09 90 67 11 OD F06 1.4 99 66 7 OD F05 1.36 103 68 12 OD F06 0.57 105 66 7 OD F05 1.43 106 63 10 OD F04 1.3 106 63 10 OD F05 1.2 106 65 8 OD F06 -1.43 106 65 7 OD F07 1.5 106 67 9 OD F06 2.02 107 60 11 OD F06 -0.53 112 61 10 OD F06 1.4 113 58 7 OD F06 0.51 113 64 10 OD F05 -0.95 113 68 9 OD F06 0.95 Page 44 of 46

ATTACHMENT C.5 FORM MS-i OWNERS REPORT FOR IINSERVICE INSPECTIONS As Required by the Provisions of the ASME Code Rules

1. Owner: Exelon Generation Company, LLC 4300 Winfleld Road, Warrenville, IL 60555 (Name and Address of Owner)
2. Plant: Byron Station 4450 N. German Church Rd. Byron, Illinois 61010 (Name and Address of Plant)
3. Plant Unit: One (1) 4. Owner Certificate of Authorization (ifrequired): NLA
5. Commercial Service Date: 09/16/85 6. National Board Number for Unit: N-198
7. Components Inspected: Steam Generator Eddy Current Inspection Component or Manufacturer or Manufacturer or State or Province National Board No.

Appurtenance Installer Installer Serial No. No.

1RCO1BA Babcock & Wilcox 7720-02 ILU-242904 165 IRCOIBB Babcock & Wilcox 7720-03 ILU-242903 166 1 RCO 1 BC Babcock & Wilcox 7720-01 ILU-242902 164 1RCOIBD Babcock & Wilcox 7720-04 ILU-242901 167 Page 45 of 46

FORM NIS-i (Back)

8. Examination Dates 03/6/05 to 03/14/05 9. Inspection Interval from 6/30/96 to 6/30/05
10. Abstract of Examinations. Include a list of examinations and a statement concerning status ofwork required for current interval.

Refer to the Attached Steam Generator Inspection Report II, Abstract ofConditions Noted Refer to the Attached Steam Generator Inspection Report

12. Abstract of Corrective Measures Recommended and Taken Refer to the Attached Steam Generator Inspection Report We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of the ASME Code,Section XI.

Certificate of Authorization No. (if applicable) Not Applicable Expiration Date Not Applicable Date -~J1/~/ ~ 20 O3~ Signed For Exelon Nuclear By ~ ,~./,~

Owner CERTIFICATE OF INSERVICE INSPECTION I, the undersigne& holdin a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of _____________ and employed by ~15/~ ~ T, o~ //rn/1,,d, C T have inspected the components described in this Owners Report during the period ~/4PS to ~ and state that to the best of my knowledge and belief, the Owner has performed examinations and taken 6orrective masites described in this Owners Report in accordance with the requirements of the ASME Code, Section Xl.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owners Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or loss of any kind arising from or connected with this inspection.

_______________________ Commissions /~1 /J5Lf l~ectorsSignature National Board, State, Province, and Endorsements Date / 20 ~3 Page 46 of 46

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