BYRON 2011-0093, Inservice Inspection Summary Report for Refueling Outage 17
| ML11200A302 | |
| Person / Time | |
|---|---|
| Site: | Byron  |
| Issue date: | 07/14/2011 |
| From: | Tulon T Exelon Nuclear, Exelon Generation Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| BYRON 2011-0093 | |
| Download: ML11200A302 (62) | |
Text
Exelon Generation Company, LLC www.exeloncorp.com Exelon Byron Station Nuclear 4450 North German Church Road Byron, IL61010-9794 July 14, 2011 LTR: BYRON 2011-0093 File: 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 for Refueling Outage 17 In accordance with Technical Specification 5.6.9, "Steam Generator (SG) Tube Inspection Report," Exelon Generation Company, LLC is reporting the results of the steam generator inspections that were completed during the Byron Station Unit 1, Refueling Outage 17. The attached report is also being submitted in accordance with the requirements of the American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel Code, 2001 Edition through the 2003 Addenda, Section Xl, "Rules for Inservice Inspection of Nuclear Power Plant Components," Article IWA-6000, "Records and Reports," and Paragraph 11-890.2.3, "Reporting" of ASME Section V "Nondestructive Examination", Article 8-Appendix II, "Eddy Current Examination of Nonferromagnetic Heat Exchanger Tubing", 2001 Edition through the 2003 Addenda.
If there are any questions regarding this report, please contact Dave Gudger, Regulatory Assurance Manager, at (815) 406-2800.
Respectfully, Ti r 1 oy J. Tulon Si Vice President Byron Nuclear Generating Station
Attachment:
Byron Station Unit 1 Steam Generator Eddy Current Inspection Report Refueling Outage 17, March 2011 TJT/PMC/TH/cy
Exelon Generation Company, LLC BYRON STATION UNIT 1 4450 North German Church Road Byron, Illinois 61010 COMMERCIAL OPERATION: September 16,1985 BYRON STATION UNIT 1 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT REFUELING OUTAGE 17 March 2011 Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 Mailing Address 4300 Winfield Road Warrenville, IL 60555 Documentation Completed Date: July 7, 2011 Page 1 of 32
TABLE OF CONTENTS
1.0 INTRODUCTION
........................................................................ 3 2.0 SUM MA RY ................................................................................ 3 3.0 CERTIFICATIONS ...................................................................... 4 3.1 Procedures/Examinations/Equipment .............................. 4 3.2 Personnel ....................................................................... 5 4.0 EXAMINATION TECHNIQUE AND EXAMINATION SCOPE .......... 7 4.1 SG Tube Examination Techniques .................................. 7 4.2 SG Tube Inspection Scope ............................................. 8 4.3 Recording of Examination Data ....................................... 9 4.4 Witness and Verification of Examination ........................... 9 5.0 EXAMINATION RESULTS ........................................................ 10 5.1 Indications Found ............................................................ 10 5.2 Other SG Inspection Results ........................................... 11 6.0 RESULTS OF CONDITION MONITORING ................................ 12 6.1 Fan Bar Wear .................................................................. 13 6.2 Lattice Grid Wear ............................................................. 13 6.3 Foreign Object Wear ......................................................... 13 6.4 Primary-to-Secondary Leakage Assessment .................... 13 7.0 REPAIR
SUMMARY
................................................................... 13 8.0 DOCUMENTATION ................................................................... 14 9.0 FIGURES / TABLES / ATTACHMENTS .................................... 14 Page 2 of 32
1.0 INTRODUCTION
Byron 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 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 Figure A.1.
The replacements SGs were installed during the eighth refueling outage.
In accordance with Byron 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 the 2003 Addenda, IWB 2500-1, Examination Category B-Q, Item B1 6.20, SG eddy current examinations were performed during the Byron Station, Unit 1 Refueling Outage 17 (B1 R17).
The Byron Unit 1 SG's are currently in their End Point of the 144 effective full power month (EFPM) inspection interval following SG replacement, per TS 5.5.9.d.2. The Byron Unit 1 SG's have operated 136.104 EFPM within the 144 EFPM Inspection Period at Refueling Outage 17. Refueling Outage 16 was neither the inspection period mid-point outage nor the inspection period end-point outage. The mid-point inspection outage was conducted during Refueling Outage 13 (67.896 EFPM within the inspection period).
The Refueling Outage 17 inspections were performed consistent with the Electric Power Research Institute (EPRI) "PWR Steam Generator Examination Guidelines: Revision 7",
applicable interim guidance and Nuclear Energy Institute (NEI) 97-06, "Steam Generator Program Guidelines, Revision 2." Westinghouse Electric Company LLC conducted the field inspection activities from March 17 through March 27, 2011. The following tube inspections were performed during this outage (TS 5.6.9.a):
o 100% Full Length Bobbin Coil in all four SGs.
o 20% Plus-Point of the Hot Leg Dents/Dings >2.0 volts in all four SGs.
o 20% Plus-Point of the Hot Leg +/- 3 top of tubesheet.
o 100% Visual Inspection of Previously Installed Welded Tube Plugs.
o 100% Visual Inspection of Previously Installed Mechanical Tube Plugs in all four SGs.
o Upper Bundle & Feedring Visual Inspection (1 B SG) o Steam Drum Visual Inspection (1 B SG) 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 this inspection. A Degradation Assessment (DA) was performed prior to each inspection to ensure the proper EPRI Appendix H, "Performance Demonstration for Eddy Current Examination",
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 detection and sizing capabilities are applicable to the Byron Station, Unit 1 site-specific condition in accordance with Section 6.2.1 of the EPRI Guidelines. All data analysts were qualified to Appendix G, "Qualification of Nondestructive Examination Personnel for Analysis of Nondestructive Page 3 of 32
Examination Data," of the EPRI Guidelines (i.e., Qualified Data Analyst (QDA)). All data analyst and acquisition personnel satisfactorily completed site specific performance 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 the current inspection were fan bar wear, and lattice grid support plate 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 all four SG's (1A, 11B, 1C, 1D). There were no scanning limitations during the examinations.
As a result of the current eddy current inspections and response to conditions found, no tubes required repaired by tube stabilization and plugging. Table 2.1 provides the tube plugging levels for each SG. Table 2.2 provides the total number of tubes plugged in the current outage by degradation mode.
TABLE 2.1 Equivalent Tube Plugging Level (TS 5.6.9.f & TS 5.6.9.h)
________" " A .SGGA 9GB SG:C. SG.D TOTAL Tubes Previously Plugged 1 1 14 5 21 Tubes Plugged in Cycle 17 0 0 0 0 0 Total Tubes Plugged 1 1 14 5 21 Total Tubes Plugged (%) 0.015% 0.015% 0.21% 0.075% 0.08%
Mode of Degradation SG A- :.SGB SGC SG D Total.
Fan Bar Wear 0 0 0 0 0 Lattice Grid Wear 0 0 0 0 0 Foreign Object Wear 0 0 0 0 0 Preventatively Plugged 0 0 0 0 0 Refueling Outage 17 0 0 0 0 0 Plugging Totals __"_...0_._0 _. 0_
_ _ 0_
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)/
American Society for Nondestructive Testing (ASNT) CP-1 89, "ASNT Standard for Qualification and Certification of Nondestructive Testing Personnel". For previously approved Certifications, the 1991 Edition of (ANSI)/ASNT CP-189 and 1984 Edition of (ASNT) Recommended Practice SNT-TC-1A, "Personnel Qualification and Certification in Nondestructive Page 4 of 32
Testing", and Exelon Generation Company, LLC (EGC) procedure ER-AP-335-039, "Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing," Revision 4 and EGC procedure ER-AP-335-040, "Evaluation of Eddy Current Data for Steam Generator Tubing," Revision 6, were used for data acquisition and analysis.
3.1.2 The examinations, equipment, procedures and personnel were in compliance with the following requirements: the EGC and Westinghouse Quality Assurance Programs for Inservice Inspection; Byron Station Technical Specification 5.5.9; 2001 Edition through the 2003 Addenda of the ASME B&PV Code Section Xl, "Rules for Inservice Inspection of Nuclear Power Plant Components"; 2001 Edition through the 2003 Addenda of the ASME B&PV Code Section V, "Nondestructive Examination"; Revision 7 of the EPRI PWR SG Examination Guidelines; and NEI 97-06, "Steam Generator Program Guidelines," Revision 2.
3.1.3 Certification packages for examiners, data analysts, and equipment are available at Byron Station. Table A.1 and Table A.2 contained in Attachment 'A' lists all personnel who performed, supervised, or evaluated the data during the current inspection.
3.1.4 Corestar International Corporation Model Omni-200TM Remote Data Acquisition Units (RDAUs) with ANSER Version 10.01.3370 on Windows 7 PC dated 1/18/11 software was used to acquire the eddy current data.
Analysis was performed with Westinghouse ANSER Version 8.4.3, Revision 533 computer software.
3.1.5 The bobbin coil examinations were performed with a 0.560-inch diameter bobbin coil eddy current probe. A 0.540-inch diameter probe was used in Rows 1 through 8 where there was difficulty traversing the low radius U-bend region.
3.1.6 The special interest and dent/ding rotating coil examinations were performed with a 0.560-inch diameter three-coil rotating plus-point probe that contained a plus-point coil, a 0.115-inch diameter pancake coil and a 0.080-inch diameter pancake coil.
3.1.7 The rotating coil examinations in the U-Bend region were performed with a 0.520-inch diameter rotating plus-point probe.
3.2 Personnel 3.2.1 The personnel who performed the SG eddy current inspection data acquisition were qualified to Level II or Level I in accordance with the 1995 Edition of ANSI/ASNT CP-1 89, "ASNT Standard for Qualification and Certification of Nondestructive Testing Personnel". For previously approved Certifications, the 1984 Edition of ASNT Recommended Practice SNT-TC-1A, "Personnel Qualification and Certification in Nondestructive Testing". A list of certified eddy current personnel who performed data acquisition for the examination are contained in Table A.1 of Attachment A.
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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 the ASNT Recommended Practice SNT-TC-1 A, "Personnel Qualification and Certification in Nondestructive Testing" or the 1995 Edition of ANSI/ASNT CP-1 89, "ASNT Standard for Qualification and Certification of Nondestructive Testing Personnel." A list of certified eddy current personnel who performed data analysis for the examination are contained in Table A.2 of Attachment A 3.2.3 All SG eddy current data analysts were qualified in accordance with EPRI Appendix G for QDA's. 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.
Resolution analysts were also trained and tested specifically for the performance of data resolution. All analysts were required to achieve a minimum probability of detection of 80% with a 90% minimum confidence level on practical examinations and a minimum score of 80% on the written test 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 of all data was performed by personnel from Westinghouse Electric Company, Infineddy, M&IS, Master-Lee, and Tricen.
Secondary analysis was performed by personnel from Anatec, MoreTech, and Tricen. Discrepancies between the two parties required Level III concurrence between both parties for the final resolution. Data Resolution was performed by personnel from Westinghouse, Anatec, and MoreTech.
3.2.6 Two independent SG eddy current Level III QDA's who were not part of the resolution team were employed to serve as a process control reviewer, in accordance with EPRI Guidelines, Sections 6.2.1, 6.3.1, and 6.3.3. The Independent Level III QDA randomly sampled the data to ensure the resolution process was properly performed and that the field calls were properly reported. The Independent Level III 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 reported directly to the EGC Nondestructive Examination Level Il1.
3.2.7 Personnel from Westinghouse, MISTRAS, and System One, performed data acquisition.
3.2.8 Real time data quality verifications were performed by personnel qualified as data analysts.
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4.0 EXAMINATION TECHNIQUE AND EXAMINATION SCOPE All eddy current examination techniques used are qualified in accordance with Appendix H & I of the EPRI PWR SG Examination Guidelines. Each examination technique was evaluated to be applicable to the tubing and conditions of the Byron, Unit 1 SGs.
4.1 SG Tube Examination Techniques (TS 5.6.9.c) 4.1.1 The bobbin coil examinations were performed with a 0.560 inch diameter bobbin coil eddy current probe described in Section 3.1.5. For low row U-Bend regions in Rows 8 and lower, a 0.540-inch diameter bobbin probe was utilized where there was difficulty traversing the U-bend region. The nominal probe inspection speed was 40 inches per second for the 0.560-inch diameter probe and 24 inches per second for the 0.540-inch diameter probe and for the 0.560-inch probe in the low row tubes. Sufficient sampling rates were used to maintain a minimum of 30 samples per inch.
The bobbin coil probes were operated at frequencies of 650 kHz, 320 kHz, 160 kHz, and 35 kHz operating in the differential and absolute test modes.
In addition, suppression mixes were used to enhance the inspection.
These mixes were as follows: 650/160 kHz differential mix, a 320/160 kHz absolute mix, and a 650/320/160 kHz differential mix. The 650/320/160 kHz differential mix was used to aid in detection of foreign objects and foreign object wear.
4.1.2 The rotating coil and plus-point examinations were performed with a 0.560-inch diameter three-coil plus-point eddy current probe described in Section 3.1.6. The nominal probe speed was 0.7 inches per second in straight sections, and 0.1 inches per second for dents and dings. A sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 30 samples per inch in the axial direction. For dents and dings, a sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 30 samples per inch in the axial direction. The rotating probes were operated at frequencies of 300 kHz, 200 kHz, 100 kHz and 20 kHz. In addition to the four base frequencies, four process channels were used to display circumferential indications in the positive trace and to provide a suppression mix for indications at the lattice grid.
4.1.3 The plus-point examinations in the U-bend regions were performed with a 0.520-inch diameter plus-point probe described in Section 3.1.7. The nominal probe speed was 0.3 inches per second. A sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 30 samples per inch in the axial direction. The plus-point probe was operated at frequencies of 400 kHz, 300 kHz, 100 kHz, and 20 kHz. In addition to the four base frequencies, four process channels were used to display circumferential indications in the positive trace and to provide a suppression mix for indications at the fan bar support.
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4.1.4 The eddy current calibration standards used for the bobbin coil and plus-point inspections met the requirements of Section 6.2.3 of the EPRI PWR Steam Generator Examination Guidelines, Revision 7 and Sections V and Xl of the ASME B&PV Code, 2001 Edition through the 2003 Addenda.
4.1.5 The SG eddy current examination techniques used during this inspection were equivalent to the EPRI Appendix H & I techniques listed in Table 4.1.
Each Examination Technique Specification Sheet (ETSS) was evaluated and determined to be applicable to the site conditions.
Table 4.1 EPRI Appendix H Techniques EPRI Location EPRIETS ETrS Probe
- ____Rev -
Fan Bar and Lattice Grid Wear 96004.3 13 Bobbin 96004.3 13 Bobbin Foreign Object/Freespan Wear 96910.1 10 +Point 21998.1 4 +Point TTS Sludge Pile, Freespan Regions, Support (Detection) 2 +Point Structures (ODSCC) Axial (Sizing) 128432 Sludge Pile Region (ODSCC) Axial (Detection) 2 +Point 128424 (Sizing) 1 +Point 128431 TTS Expansion (ODSCC) Circ 21410.1 6 +Point TTS Expansion (PWSCC) Axial 20511.1 8 +Point TTS Expansions (PWSCC) Circ 20510.1 7 +Point Dents/Dings (PWSCC) Axial 96703.1 17 +Point Dents/Dings (PWSCC) Circ 20510.1 7 +Point Dents/Dings < 2 Volts (ODWCC) Axial (Detection) 2 +Point 128425 (Sizing) 1 +Point 128432 Dents/Dings > 2 Volts (ODSCC) Axial 22401.1 4 +Point Dents/Dings (ODSCC) Circ 21410.1 6 +Point Sludge Pile (ODSCC) Axial (Detection) 2 Bobbin 128413 Tube-to-Tube Contact Wear 96004.3 13 Bobbin Freespan (MBMs) Vol 96010.1 7 Bobbin 4.2 SG Tube Inspection Scope (TS 5.6.9.a) 4.2.1 100% of the tubes in all SGs were inspected full length, tube end to tube end, with a bobbin coil probe described in Section 4.1.1 above.
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4.2.3 20% of the hot leg dents and dings that are >2.0 volts were inspected with a plus-point probe described in Section 4.1.2. A total of 4 hot leg dings comprised the hot leg dent/ding inspection population. Due to the small population, 100% of the dents/dings were inspected. Three were in the 1A SG and the one was in the 1 B SG.
4.2.4 20% Plus-Point of the Hot Leg +/- 3 top of tubesheet was inspected with a plus-point probe described in Section 4.1.2. A total of 5380 tubes were in the inspection population. 1353 in the 1A SG, 1353 in the 1B SG, 1331 in the 1C SG, and 1343 in the 1D SG.
4.2.5 Diagnostic examinations were conducted on the following types of indications and conditions using a rotating probe described in Section 4.1.2 and 4.1.3:
o Non-quantifiable indications that were detected by the bobbin coil examination.
o Tubes in the vicinity of potential foreign objects in order to determine the extent of tubes potentially affected by the objects.
o A 20% sample of new fan bar wear indications (6 total).
A total of 24 tubes were inspected as a result of these diagnostic examinations.
4.2.6 Attachment 'B' contains tube sheet maps indicating the tube inspections that were performed during Refueling Outage 17.
4.3 Recording of Examination Data The raw eddy current data and analysis results were recorded on digital data storage media. The data was then loaded into the Westinghouse Eddy Current Data Management System, "ST Max," Version 1.27. This system was used to track the proper examination of all tubes and it was also used to generate the final eddy current report summaries.
4.4 Witness and Verification of Examination Eddy current inspections were witnessed and/or verified by the Authorized Nuclear Inservice Inspectors, Mr. Jeff Hendricks, Mr. Greg Feigel, and Mr. Lee Malabanan, of the Hartford Steam Boiler of CT of Hartford Connecticut, Chicago Branch, 2443 Warrenville Road, Suite 500, Lisle, Illinois 60532-9871.
Refer to Attachment 'D' for the ASME Form NIS-1, "Owners Report for Inservice Inspections". No ASME Form NIS-2, "Owner's Report for Repair/Replacement Activity" for steam generator mechanical tube plugging were completed due to no plugging/tube repairs being performed.
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5.0 EXAMINATION RESULTS 5.1 Indications Found (TS 5.6.9.b) 5.1.1 Fan Bar Wear - Tube degradation was found during the Refueling Outage 17 bobbin coil examination in the U-bend region due to fretting of the fan bar supports on the tube. A total of 173 indications in 139 tubes were reported. The EPRI Appendix H bobbin coil examination technique 96004.3 was utilized in this inspection for the depth sizing of fan bar wear.
No tubes exceeded the 40% TW repair limit and no tubes were plugged due to fan bar wear. The largest indication found was 20% through wall (TW) and was found in tube R86-C63 in SG 1B. The depth of the fan bar wear ranged from 1% TW to 20% TW. (Table 5.1.1 provides a summary of fan bar wear degradation. Attachment C provides a listing of all tube flaws containing measurable through wall depth and inservice indications, including fan bar wear.
Table 5.1.1 Refueling Outage 17 Fan Bar Wear Summary SGA k : SG B: SGC".ý' SGD:
_ _ Indications. Indications Indications, Indications
<_10%_TW 18 67 19 40 10-19% TW 3 13 5 7
>= 20% TW 0 1 0 0 TOTAL
- 21 81 24 47
- Tubes may contain multiple indications and may be identied in multiple size categories.
5.1.2 Lattice Grid Wear - Three (3) tubes were found that contained indications of lattice grid wear. The depth of the lattice grid wear ranged from 3% TW to 11% TW as measured by the EPRI Appendix H qualified bobbin coil examination technique 96004.3. No tubes were plugged as a result of lattice grid wear. Refer to Attachment C. Table 5.1.3 below provides a summary of tubes that contain lattice grid wear.
TABLE 5.1.3 Refuelinc Outage 17 Lattice Grid Wear Summary Support NDE SG Row Column . Location Depth 1B 118 73 07H (+1.T') 11%
1D 51 8 08C (-1.49") 3%
1D 117 78 07H (+0.7") 4%
5.1.3 Foreian Obiect Wear - There were no indications of foreign object wear detected during the Refueling Outage 17 inspection. There was no historical foreign object wear.
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5.2 Other SG Inspection Results 5.2.1 Hot Leg Dent/Ding Inspection: During Refueling Outage 17, 100% of the hot leg dents and dings > 2.0 volts were inspected with a three-coil rotating probe, which included a plus-point coil. A total of four tubes contained dings that met the inspection criteria and were inspected, three (3) found in the 1A SG; hot leg and one (1) found in the 1B SG; hot leg. No indication of degradation was found as a result of these inspections.
5.2.2 Visual Inspection of Installed Tube Plugs: All previously installed welded plugs and previously installed mechanical plugs were visually inspected for signs of degradation and leakage. A total of 2 welded plugs and 40 mechanical plugs were visually inspected. No anomalies were found.
5.2.3 Tubesheet Visual Inspection: Visual inspection of the secondary tubesheet was performed following sludge lancing activities in each SG. The tube annulus, tube lane, and peripheral tubes (6-8 tubes deep) were visually inspected for foreign material. A total of four (4) small foreign objects were found during these inspections. A small piece of slag was found in the 1B SG, a piece of gasket material was found in the 1C G, small wire found in the 1 D SG, and a piece of slag was found in the 1D SG. All foreign objects were successfully removed except for the piece of slag material (tightly adhered to the tubesheet) in the 1 D SG. Based on the inspection results and condition monitoring no tubes required to be plugged during B1 R1 7 refueling outage.
5.2.4 Upper Bundle and Feedrinq Inspection: Visual inspections of the Upper Bundle (9 th Support Plate), Feedring, and Steam Drum were performed within the 1 B SG. During the inspections of the 9th support plate, trace amounts of scale deposits were noted in the cold leg in-bundle region and uniformly coated layer of scale deposits in the hot leg in-bundle region. It was additionally noted that the tube and lattice grid surfaces were dull in appearance. No anomalous conditions or degradation found during the upper bundle inspection. During the Feedring inspections, no anomalous structural conditions or foreign objects were observed.
Additionally, no erosion or component degradation was found.
5.2.5 Steam Generator Steam Drum Inspections: During the steam drum inspection, erosion was found in the steam nozzle venturi area. The localized degradation was observed in the material surrounding the venturi adjacent to the retaining plate (also referred to as the "Star-Plate"). The Original Equipment Manufacture (OEM), BWC, was contacted regarding this condition and concluded to accept condition "as-is" and that there are no further actions required. The conclusion was made based on the following; the venturi's are held into the head primarily by an interference fit between the venturi and steam nozzle, the retaining plate only provides a secondary retaining function, and localized Page 11 of 32
degradation of the base material will in no way affect the function of the venturies or increase the risk of the venturies loosening during operation.
Other than those previously described, no other anomalous conditions were observed, no erosion or component degradation was found, and much of the surface areas were covered in a light colored surface rust.
This light colored material was easily removed in locations by the manipulation of the inspection probe.
5.2.6 Attachment C - (TS 5.6.9.d) contains tube lists with axial elevations of all tube flaws that contain measurable through wall depth and inservice indications that were found during the Refueling Outage 17 eddy current inspection.
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 Unit 1, Refueling Outage 17 inspection. The condition monitoring assessment was performed in accordance with TS 5.5.9.a and NEI 97-06 Rev. 2 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 tube integrity, those loads that do significantly affect burst or collapse shall be determined and assessed in combination with loads due to pressure with a safety factor of 1.2 on combined primary loads and 1.0 on axial secondary loads.
The structural limit used was based upon 360 degree uniform wall thinning for infinite length assuming ASME Code minimum material properties. The structural limits provided below are conservative in that they assume 360 degree uniform wall thinning for the length of the tube. Satisfying this structural limit ensures that the SG tube integrity performance criteria for structural integrity, accident induced leakage and operational leakage will be maintained.
The as-found condition of each degradation mechanism found during Refueling Outage 17 was shown to meet the appropriate limiting structural integrity performance parameter with a probability of 0.95 at 50% confidence level, including consideration of relevant uncertainties.
No tube pulls or in-situ pressure testing was performed or required during Refueling Outage 17.
Sections 6.1 through 6.3 provide a summary of the condition monitoring assessment for each degradation mechanism. Section 6.4 provides a primary to secondary leakage assessment.
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6.1 Fan Bar Wear The largest fan bar wear indication found during the Refueling Outage 17 inspection was 20% TW as measured by the EPRI Appendix H qualified technique ETSS 96004.3, Revision 13. Considering technique and analyst uncertainties, the largest fan bar wear indication found is corrected to 27.60%
TW with a 0.95 probability at 50% confidence level. This is well below the fan bar wear structural limit of 60% TW.
6.2 Lattice Grid Wear The largest lattice grid wear indication found during the Refueling Outage 17 inspection was 11% TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision 13. Considering technique and analyst uncertainties, the largest lattice grid wear indication found is corrected to 18.87%
TW with a 0.95 probability at 50% confidence level. This is well below the lattice grid wear structural limit of 60% TW.
6.3 Foreign Object Wear There were no indications of foreign object wear detected during the Refueling Outage 17 inspection. Therefore, condition monitoring performance criteria was met for foreign object wear.
6.4 Primary-to-Secondary Leakage Assessment Byron Station Unit 1 did not observe any operational primary to secondary leakage greater than three gallons per day and no detectable leakage < 3 gallon per day over the last two operating cycles preceding the inspection. The SG tube inspections did not find any potential sources of tube leakage. Chemistry sampling of the Steam Jet Air Ejector and liquid SG blowdown sample locations did not detect any SG operational leakage that was above the detection threshold. Therefore, it was determined that there was no quantifiable SG operational leakage.
7.0 REPAIR
SUMMARY
No tube repairs were required in B1 R17. Table 7.1 shows no repairs conducted during Refueling Outage 17.
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TABLE 7.1 Summary of Refueling Outage 17 Tube Plugging REPAIRS PERFORMED SG A, j SG B SGC SG D TOTAL Tubes Plugged 0 0 0 0 0 Tubes Stabilized 0 0 0 0 0 8.0 DOCUMENTATION All original optical disks and hard drives have been provided to EGC and are maintained at Byron Station. The final data sheets and pertinent tube sheet plots are contained in the Westinghouse Final Outage Reports for Byron Station, Unit 1, Refueling Outage 17 Steam Generator Inspection. The report is also maintained at Byron Station.
9.0 FIGURES/TABLES/ATTACHMENTS Attachment A Table A.1 Data Acquisition Personnel Certification Table A.2 Data Analysis Personnel Certification Figure A.1 Babcock & Wilcox Replacement Steam Generator Byron Unit 1 Configuration Figure A.2 Byron Station Unit 1 Steam Generator Tubesheet Configuration (Typical)
Attachment B Attachment B.1 Hot Leg Bobbin Coil Inspection Scope Attachment B.2 Cold Leg Bobbin Coil Inspection Scope Attachment B.3 Special Interest Plus-Point Inspection Scope, Including Hot Leg Dents and Dings Attachment B.4 Hot Leg TTS Plus-Point Inspection Scope Attachment C Attachment C.1 1A Steam Generator Inservice Indications Attachment C.2 1B Steam Generator Inservice Indications Attachment C.3 1C Steam Generator Inservice Indications Attachment C.4 1D Steam Generator Inservice Indications Attachment D Attachment D.1 NIS-1 Form.
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ATTACHMENT A PERSONNEL CERTIFICATIONS BABCOCK & WILCOX REPLACEMENT STEAM GENERATOR BYRON UNIT 1 CONFIGURATION Page 15 of 32
TABLE A.1 DATA ACQUISITION PERSONNEL CERTIFICATIONS No. ' " Name" Company Level ODA 1 Chiplaskey, G Westinghouse II No 2 Davenport, T Westinghouse II No 3 Dawson, F System One II No 4 Dillard, W Westinghouse II No 5 Estel, J Westinghouse II No 6 Evering, D Westinghouse II No 7 Herold, C System II No 8 Lopez, P System One I No 9 Mantich, S Westinghouse II No 10 Markowsky, M System One I-T No 11 Pessek, S MISTRAS IIA No 12 Restina, D Westinghouse II No 13 Schachte, D Westinghouse II No 14 Taylor, A Westinghouse I No 15 Thompson, K Westinghouse II No 16 Villanueva, J System One II No 17 Zirkelbach, J Westinghouse II No Page 16 of 32
TABLE A.2 DATA ANALYSIS PERSONNEL CERTIFICATIONS No. . Name& Company Level QDA 1 Bell C F Anatec III QDA 2 Chizmar D A Anatec IIA QDA 3 Circosta S A Anatec IIA QDA 4 DeLaPintiere L M Anatec III QDA 5 Dlabik A J Master-Lee lilA QDA 6 Dykes R A Anatec IIA QDA 7 Emery R S Anatec IIA ODA 8 Enloe R K M&IS IIA QDA 9 Ericson E R Westinghouse III QDA 10 Fuller C L MoreTech IliA QDA 11 Funanich J J MoreTech lilA QDA 12 Galmoff T A Master-Lee IIA QDA 13 Hako E J Anatec IIA QDA 14 Hall K J MoreTech lilA QDA 15 Heinzen A Tricen IIA QDA 16 Herold M Infineddy IIA QDA 17 Holden T A M&IS III QDA 18 Hover G D Anatec IIA QDA 19 Ingenthron G J Anatec IIA QDA 20 Ingenthron J Infineddy IIA QDA 21 Kirshberger G Tricen IIA QDA 22 Lynch D E Westinghouse III QDA 23 Manley M G MoreTech lilA QDA 24 Maurer R S* Westinghouse III QDA 25 Merriam S P MoreTech lilA QDA 26 Miller M W Anatec III QDA 27 Neff A S Anatec III QDA 28 Newman E P MoreTech lilA QDA 29 Radovanic J I Anatec III QDA 30 Richardson H A MoreTech lilA QDA 31 Rogers G F Anatec III QDA 32 Rush S* Infineddy IliA QDA 33 Sordini J D MoreTech IIA QDA 34 Stanger D A Anatec III QDA 35 Stokke T Tricen lilA QDA 36 Tommarello D J Master-Lee IIA QDA 37 Webb M A MoreTech lilA QDA 38 Wieber J A Anatec IIA QDA Independent Qualified DataAnalyst Page 17 of 32
FIGURE A.1 Babcock & Wilcox Replacement Steam Generator Byron Unit I Configuration
.,--STEAM OUTLE'T OENOZZLE SEPARANTOS ET -0FWAT LLAUTIL-IARY
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Page 18 of 32
FIGURE A.2 Byron Unit 1 Steam Generator Tubesheet Configuration (Typical)
Byron Station UNIT: 1 SG: 1 A 5 10 15 20 '5 30 35 40 45 so 55 855 70 75 8o85 10 HI Ila 115 120 125 M30 135 140 0 0000 0 --- 115 LOS 145 ilO ... - - 90i CD 00t50 0Bo 0 0I00 00Q 0 70 0
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ATTACHMENT B INSPECTION SCOPE Page 20 of 32
ATTACHMENT B.1 Hot Leg Bobbin Coil Inspection Scope Page 21 of 32
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SG - C As Tested Cold Leg 560 Bobbin Inspection Byron B1R17 CAE 7720 a 14 Plugged Tube E 563 140 135 130 125 120 115 110 105 100 95 90 85 88 75 70 65 60 55 50 45 48 35 30 25 20 15 18 5 CO OOi000, 1 0~. 00dL0~0~ i 0
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.1 .--- .EE .E . . . . . . . . . E 5 EEE 13EEEEEE EEE EEE EEE EEE 1118E 10 95 . 90 EEE 85 EEE 8. EEE 75EEE .E78 EEE 65 EEE 60 EEE 55 EEE 58 45EEE 40EEE 35EEE 3.52E E E E EEE EEE4 5 E E Wkh EMbicl Cmpmy LLC - ST MW, 031282011 14:18.29
SG - D As Tested Cold Leg 560 Bobbin Inspection Byron B1R17 CAE 7720 a 5 Plugged Tube 0 563 Tested Straight Section 148 135 130 125 120 115 11 105 1M8 95 90 85 88 75 78 65 60 55 58 45 40 35 30 25 20 15 1 5
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Attachment B.3 Special Interest Plus-Point Inspection Scope Including Hot Leg Dents and Dings Page 23 of 32
SG - A 20% Sample of HL Dents and Dings >= 2v Actual Testing: 100% of HL Dents and Dings >2 v were tested in B1R17 Byron B1R17 CAE 7720 X 3 HL DNG/DNI -;'-
a 1 Plugged Tube 148 135 130 125 120 115 118 105 100 95 90 85 88 75 78 65 60 55 50 45 40 35 30 25 20 15 1i 5 115 i18 i - C, C ?0
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0000' 0' 000 00 0 0 000 148 135 138 125 128 115 118 185 188 95 98 85 88 75 78 65 68 55 58 45 48 35 38 25 28 15 18 5 Wea kiO.IseEi~dtri Co..pwy LLC -ST Ma. 03(2712011 15:57A7
Byron 1 BlR17 CAE 20110301 03/27/2011 14:08:54
+ +------------- - --- - - ----------- -- -- - - - - - - -- - - - - --- -
I INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
+-------------+ +-----+-----+
+-----+-----+-----+-----+-----+
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+-----+ - - +--------
63 28 2.03 183 DNT P1 09H -. 57 TEC TEH .560 NBAZC 43 HI 2008/03/01 63 28 2.44 180 DNT P1 09H -. 70 TEC TEH .560 SBACC 91 HI 75 50 2.15 183 ONG P1 04H 21.91 TEC TEH .560 NBAZC 35 HII I I 1 52 53 2.01 178 DNT P1 09H 1.78 TEC TEH .560 NBAZC 59 HI
+-------------+ +----+-----+
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---- + ----
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I INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
+-----+--+.- ---- +----------------+----+----+----+----+ ----- +- ---
Tubes: 3 Records: 4 1 ST Max
SG - B 20% Sample of HL Dents and Dings >= 2v Actual Testing: 100% of HL Dents and Dings >2 v were tested in B1R17 Byron B1R17 CAE 7720 X 1 HL D14G/UNT >-:2%
a 1 Plugged Tube 148 135 30 125 120 .15 110 105 100 95 98 85 88 00075 70 65 60 55 5s 45 40 35 30 25 28 15 18 5 115 Iý 00 0 115
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INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
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Tubes: 1 Records: 2 1 ST Max
SG - B 20% Sample of New Fan Bar Wear Byron B1R17 CAE 7720 a 1 Plugged Tube E 6 20% Sample of New Fan Bar wear 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 0 '0 00 0 00 ,°°°°
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SG - B CAE 03/27/2811 14:11:05 ATY INSPDATE ROW COL IDX VOLTS DEG IND PER CHN LOC INCHI INCH2 BEG END DIA PTYPE CAL PLN UTIL1 UTIL2 RES 2011/03/01 106 63 97 .39 a PCT 8 P2 FO5 1.35 TEC TEH 568 NBAZC 31H 1 RES 2011/03/01 106 63 15 .10 270 VOL P4 F85 1.11 FO5 F85 520 ZPUMR 129H 35
'R 2011/03/01 106 63 97 .74 0 PCT 13 P2 FO5 -1.09 TEC TEH 560 NBAZC 31H 1 RES"2011/03/01 106 63 15 .40 91 VOL P4 FOS -1.14 F85 F85 520 ZPUMR 129H 35 RES 2011/03/01 114 63 101 .30 8 PCT 6 P2 F85 1.84 TEC TEH 560 NBAZC 31H 1 RES 2011/03/01 114 63 16 .09 88 VOL P4 F05 1.34 F05 F85 520 ZPUMR 129H 35 RES 2011/03/01 106 65 171 .28 a PCT 6 P2 FOS 1.47 TEC TEH 560 NBAZC 29H 1 RES 2011/03/01 106 65 14 .13 78 VOL P4 FOS 1.63 F85 F85 520 ZPUMR 129H 35 RES 2011/03/01 109 66 13 .53 8 PCT 10 P2 FOS 1.36 TEC TEH 560 NBAZC 33H 1 RES 2011/03/01 109 66 18 .29 93 VOL P4 FOS 1.25 F05 FOS 520 ZPUMR 129H 35 RES 2011/03/01 109 66 13 .57 PCT 11 P2 F04 1.12 TEC TEH 560 NBAZC 33H 1 RES 2011/03/01 109 66 18 .29 84 VOL P4 F04 1.14 FU4 F04 520 ZPUMR 129H 35 RES 2011/03/01 109 66 13 .41 0 PCT 8 P2 F04 - .70 TEC TEH 560 NBAZC 33H 1 RES 2011/03/01 109 66 18 .23 91 VOL P4 F@4 -1.02 F04 F04 520 ZPUMR 129H 35 RES 2011/03/01 113 66 11 .39 0 PCT 8 P2 FOS - .64 TEC TEH 560 NBAZC 33H I RES 2011/03/01 113 66 17 .22 99 VOL P4 FO5 -1.10 F85 F05 520 ZPUMR 129H 35 RES 2011/03/01 84 83 38 .40 a PCT 9 P2 F05 -1.89 TEC TEH 560 NBAZC 39H 1 RES 2011/03/01 84 83 19 .25 90 VOL P4 FO5 -1.47 35 F05 F05 520 ZPUMR 129H Count: 9 End - ST Max
SG - B CAE 20% Sample of New Fan Bar Wear 03-27-2011 14:18:31 ATY INSPDATE ROW COL IDX VOLTS DEG IND PER CHN LOC INCH1 INCH2 BEG END DIA PTYPE CAL PLN UTIL1 UTIL2 I CRLEN CRWID CEG B-OFF E-OFF S 2....11/63/.............1....114........63......161........6 RES ........ TEH..............566.............NB..............C.......................1.......1 .
RES 2011/03/01 114 63 101 .30 0 PCT 6 P2 F@5 1.84 TEC TEH 560 NBAZC 31H 1 1 RES 2011/03/01 113 66 11 .39 0 PCT 8 P2 F@5 -. 64 TEC TEH 560 NBAZC 33H 1 1 RES 2011/03/01 log 66 13 .41 0 PCT 8 P2 F@4 -. 70 TEC TEH 560 NBAZC 33H 1 1 RES 2611/03/01 169 66 13 .53 0 PCT 10 P2 F@5 1.36 TEC TEH 560 NBAZC 33H 1 1 RES 2011/03/01 106 63 97 .39 0 PCT 8 P2 F@5 1.35 TEC TEH 560 NBAZC 31H 1 1 RES 2011/03/01 106 65 171 .28 0 PCT 6 P2 F@5 1.47 TEC TEH 560 NBAZC 29H 1 1 RES 2011/03/01 84 83 38 .40 0 PCT 9 P2 F@5 -1.89 TEC TEH 560 NBAZC 39H 1 1 Record Count = 7 End - ST Max Page 1 of 1 ST Max
SG - B CL FOSAR Object Byron B1R17 CAE 7720 a 1 Plugged Tube T 1 FOSAR Object Test TSC -1"/+4" 140 135 130 125 120 15 : 10 105 100 95 90 85 80 75 70 65 60 55 50 45 40 35 30 25 20 15 10 5 0 0 C 115 115 110 110 S. ". ". . . . . . '. . . . . . . . . . . .
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No EC Base Special Interest in SG C in B1R17
No EC Base Special Interest in SG D in B1R17
Attachment B.4 Hot Leg TTS Plus-Point Inspection Scope Page 24 of 32
SG - A As Tested Hot Leg Top of Tubesheet +Point Inspection Byron B1R17 CAE 7720 0 1 Plugged Tube S 1363 lested [IS 140 135 130 125 120 115 110 105 100 95 9g 85 8 75 70 65 60 55 58 45 40 35 30 25 20 15 18 5
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ATTACHMENT C Steam Generator Inservice Indications Page 25 of 32
Attachment C.1 1A Steam Generator Inservice Indications Page 26 of 32
SG - A ST Max Byron 1 BlR17 CAE 20110301 06/14/2011 10:15:23
+ -...- ----
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I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
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78 51 .68 0 PCT 13 P2 F@5 .90 TEC TEH .560 NBAZC 35 H 66 55 .17 0 PCT 4 P2 F@5 - .70 TEC TEH .560 NBAZC 35 H 66 55 NOD TSH TSH .560 NPS3C 133 H 55 .31 0 PCT TEC TEH .560 NBAZC 70 7 P2 F03 .96 35 H 70 55 NOD TSH TSH .560 NPS3C 133 H 53 58 .22 0 PCT 4 P2 F06 .52 TEC TEH .560 NBAZC 45 H 75 58 .33 0 PCT 7 P2 F05 -. 54 TEC TEH .560 NBAZC 35 H 86 59 .21 180 INF P2 F04 - .26 TEC TEH .560 NBAZC 35 H 86 59 .18 0 PCT 4 P2 F04 1.54 TEC TEH .560 NBAZC 35 H 73 62 .21 0 PCT 5 P2 F05 - .42 TEC TEH .560 NBAZC 31 H 72 63 .17 0 PCT 4 P2 F05 -. 93 TEC TEH .560 NBAZC 31 H 72 63 NOD TSH TSH .560 NPS3C 129 H 100 63 .21 0 PCT 5 P2 FO5 -1.67 TEC TEH .560 NBAZC 31 H 100 63 NOD TSH TSH .560 NPS3C 129 H 112 63 .60 0 PCT 13 P2 F04 .50 TEC TEH .560 NBAZC 31 H 112 63 NDD TSH TSH .560 NPS3C 129 H
.560 NBAZC 64 65 .56 0 PCT 8 P2 F06 .67 TEC TEH 29 H 64 65 NDD TSH TSH .560 NPS3C 127 H 80 67 .23 0 PCT 6 P2 F06 -1.06 TEC TEH .560 NBAZC 31 H 84 69 .23 0 PCT 3 P2 F06 - .57 TEC TEH .560 NBAZC 29 H 88 69 .34 0 PCT 5 P2 F06 -. 47 TEC TEH .560 NBAZC 29 H 96 69 .59 0 PCT 8 P2 F@5 -1.85 TEC TEH .560 NBAZC 29 H 96 69 .62 0 PCT 9 P2 F06 -. 39 TEC TEH .560 NBAZC 29 H 89 70 .16 0 PCT 4 P2 F09 - .62 TEC TEH .560 NBAZC 31 H 86 71 .40 0 PCT 9 P2 F05 -1.20 TEC TEH .560 NBAZC 31 H 86 71 .85 0 PCT 17 P2 F06 1.31 TEC TEH .560 NBAZC 31 H 115 78 .49 0 PCT 9 P2 F@5 1.90 TEC TEH .560 NBAZC 27 H 60 93 .25 0 PCT 3 P2 F@6 -1.68 TEC TEH .560 NBAZC 21 H 60 93 NDD TSH TSH .560 NPS3C 129 H S--------+ ---- ----
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Attachment C.2 1 B Steam Generator Inservice Indications Page 27 of 32
SG - B ST Max Byron 1 B1R17 CAE 20110301 06/14/2011 10:15:24
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79 52 .11 0 PCT 2 P2 F05 .46 TEC TEH .560 NBAZC 23 HI 79 52 NOD TSH TSH .560 NPS3C 115 HI TEC TEH .560 NBAZC 29 HI 109 56 .17 0 PCT 4 P2 F05 - .63 TEC TEH .560 NBAZC 29 HI 109 56 .27 0 PCT 6 P2 F07 .56 TEC TEH .560 NBAZC 29 HI 109 56 .22 0 PCT 5 P2 F08 1.72 TEC TEH .560 NBAZC 27 HI 64 57 .82 0 PCT 15 P2 F06 -1.13 TEC TEH .560 NBAZC 31 HI 75 60 .39 0 PCT 8 P2 F02 -2.26 TEC TEH .560 NBAZC 29 HI 60 61 .41 0 PCT 8 P2 F06 - .70 TEC TEH .560 NBAZC 29 HI 67 62 .38 0 PCT 8 P2 F01 -1.67 TEC TEH .560 NBAZC 29 HI 81 62 .33 0 PCT 7 P2 F06 1.34 TEC TEH .560 NBAZC 43 HI 60 63 .11 0 PCT 3 P2 F@5 .77 TEC TEH .560 NBAZC 29 HI 66 63 .18 0 PCT 4 P2 F04 1.62 TEC TEH .560 NBAZO 29 HI 68 63 .11 0 PCT 3 P2 F05 -1.65 TEC TEH .560 NBAZC 29 HI 82 63 .55 0 PCT 10 P2 F06 1.88 TEC TEH .560 NBAZC 31 HI 86 63 .62 0 PCT 12 P2 F05 - .94 TEC TEH .560 NBAZC 31 HI 86 63 1.40 0 PCT 20 P2 F06 1.14 TEC TEH .560 NBAZC 31 HI 88 63 .43 0 PCT 9 P2 F08 .93 TEC TEH .560 NBAZC 31 HI 106 63 .74 0 PCT 13 P2 F05 -1.09 TEC TEH .560 NBAZC 31 HI 106 63 .39 0 PCT 8 P2 F05 1.35 TEC TEH .560 NBAZC 31 HI 106 63 .44 0 PCT 9 P2 F07 1.59 63 .40 91 VOL P4 F05 -1.14 FO5 F05 .520 ZPUMR 129 HI 106 F05 FO5 .520 ZPUMR 129 HI 106 63 .10 270 VOL P4 F05 1.11 TEC TEH .560 NBAZC 31 HI 114 63 .30 0 PCT 6 P2 F@5 1.84 TEC TEH .560 NBAZC 31 HI 114 63 .36 0 PCT 8 P2 F06 1.02 TEC TEH .560 NBAZC 31 HI 114 63 .50 0 PCT 10 P2 F07 1.46 TEC TEH .560 NBAZC 31 HI 114 63 .38 0 PCT 8 P2 F08 .72 114 63 .06 86 VOL P4 F05 -1.30 FO5 F05 .520 ZPUMR 129 HI 114 63 .09 88 VOL P4 F05 1.34 FO5 FO5 .520 ZPUMR 129 HI TEC TEH .560 NBAZC 43 HI 65 64 .32 0 PCT 8 P2 F05 .75 TSH TSH .560 NPS3C 113 HI 65 64 NOD TEC TEH .560 NBAZC 43 HI 77 64 .65 0 PCT 15 P2 F@5 -1.66 TSH TSH .560 NPS3C 113 HI 77 64 NOD TEC TEH .560 NBAZC 29 HI 91 64 .38 0 PCT 8 P2 F06 -. 61 TSH TSH .560 NPS3C 113 HI 91 64 NOD TEC TEH .560 NBAZC 29 HI 97 64 .68 0 PCT 12 P2 F06 -. 65 TSH TSH .560 NPS3C 113 HI 97 64 NDD 113 64 .34 0 PCT TEC TEH .560 NBAZO 29 HI 7 P2 F04 .70 TSH TSH .560 NPS3 113 HI 113 64 NOD TEC TEH .560 NBAZC 65 HI 52 65 .13 0 PCT 4 P2 F04 -1.86 TEC TEH .560 NBAZC 41 HI 66 65 .10 0 PCT 2 P2 F03 -1.90 TEC TEH .560 NBAZC 41 HI 74 65 .40 0 PCT 8 P2 F06 1.54 TEC TEH .560 NBAZC 41 HI 76 65 39 0 PCT 8 P2 F05 .81 S--- - - - ------------------------
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.109 76 .22 0 PCT 6 P2 F05 - .75 TEC TEH .560 NBAZC 35 H 109 76 .56 0 PCT 12 P2 F06 1.47 TEC TEH .560 NBAZC 35 H 109 76 .23 0 PCT 6 P2 F09 .76 TEC TEH .560 NBAZC 35 H 109 76 NODD TSH TSH .560 NPS3C 119 H 94 77 .12 0 PCT 3 P2 F07 1.85 TEC TEH .560 NBAZC 35 H 104 77 .17 0 PCT 5 P2 F@5 -1.89 TEC TEH .560 NBAZC 35 H 108 77 .10 0 PCT 3 P2 F07 - .55 TEC TEH .560 NBAZC 35 H
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I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
-- ------------ +---.+----.----+- +------+ ---- +.--------+- "- ----- -...... +-....--
109 33 HI 78 .22 0 PCT 4 P2 F02 -1.90 TEC TEH .560 NBAZC 109 78 NDD TSH TSH .560 NPS3C 117 HI 114 79 .23 0 PCT 6 P2 F@5 .89 TEC TEH .560 NBAZC 39 HI 103 80 .16 0 PCT 4 P2 F06 .78 TEC TEH .560 NBAZC 35 HI i111 80 .17 0 PCT 5 P2 F06 .86 TEC TEH .560 NBAZC 35 HI 94 81 .40 0 PCT 8 P2 F05 1.44 TEC TEH .560 NBAZC 37 HI 84 83 .40 0 PCT 9 P2 F@5 -1.89 TEC TEH .560 NBAZC 39 HI 84 83 .25 90 VOL P4 F05 -1.47 F@5 F@5 .520 ZPUMR 129 HI 35 84 .24 0 PCT 6 P2 F05 -. 90 TEC TEH .560 NBAZC 73 HI 105 84 .36 0 PCT 8 P2 F05 - .70 TEC TEH .560 NBAZC 37 HI 94 85 .25 0 PCT 6 P2 F06 -1.54 TEC TEH .560 NBAZC 37 HI 65 86 .37 0 PCT 7 P2 F06 .45 TEC TEH .560 NBAZC 45 HI 64 87 .23 0 PCT 6 P2 F05 -1.00 TEC TEH .560 NBAZC 47 HI 65 88 .28 0 PCT 8 P2 F06 -. 88 TEC TEH .560 NBAZC 47 HI 65 88 NOD TSH TSH .560 NPS3C 119 HI 69 88 .20 0 PCT 6 P2 F06 -. 76 TEC TEH .560 NBAZC 47 HI 69 88 NOD TSH TSH .560 NPS3C 119 HI 87 90 .38 0 PCT 9 P2 F06 1.65 TEC TEH .560 NBAZC 39 HI 87 90 NDD TSH TSH .560 NPS3C 117 HI 90 39 HI 113 .10 0 PCT 3 P2 F07 .65 TEC TEH .560 NBAZC 113 90 NDD TSH TSH .560 NPS3C 117 HI 109 92 .12 0 PCT 3 P2 F04 -1.43 TEC TEH .560 NBAZC 37 HI 63 94 .28 0 PCT 7 P2 F06 1.84 TEC TEH .560 NBAZC 45 HI 43 HI 85 98 .10 0 PCT 3 P2 F07 1.90 TEC TEH .560 NBAZC 43 HI 102 107 .26 0 PCT 8 P2 F@5 .61 TEC TEH .560 NBAZC
+ ---
+ ----
+ ---
+- +- -- + ------ -- +---- + -+- +- -- -
I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
+ + + 4"-- - +
+---+---+------- + ---------- - +-- -- + -- -- +-++-.....+-....-- +
Tubes: 65 Records: 110 3 ST Max
Attachment C.3 1C Steam Generator Inservice Indications Page 28 of 32
SG - C ST Max Byron 1 B1R17 CAE 20110301 06/14/2011 10:15:23
- ----------- +--------+------------+--------.------..---.+-......+ --
I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
--- +-----------------+-- ---
+---------+-+-+- - --
47 14 .23 0 PCT 6 P2 F05 .99 TEC TEH .560 NBAZC 67 HI 41 38 .11 0 PCT 4 P2 F05 -1.63 TEC TEH .560 NBAZC 59 HI 45 46 .11 0 PCT 3 P2 F05 -1.59 TEC TEH .560 NBAZC 59 HI 56 47 .15 0 PCT 4 P2 F04 .68 TEC TEH .560 NBAZC 53 HI I56 47 INF P1 F05 .53 TEC TEH .560 NBAZC 53 HI I87 64 .25 0 PCT 6 P2 F5 .77 TEC TEH .560 NBAZC 45 HI 40 67 .15 0 PCT 3 P2 F04 1.07 TEC TEH .560 NBAZC 43 HI 48 69 .13 0 PCT 3 P2 F06 1.09 TEC TEH .560 NBAZC 41 HI 70 71 .21 0 PCT 8 P2 F05 1.20 TEC TEH .560 NBAZC 47 HI 63 76 .09 0 PCT 2 P2 F05 1.81 TEC TEH .560 NBAZC 35 HI I109 78 .32 0 PCT 5 P2 F5 .75 TEC TEH .560 NBAZC 33 HI 52 79 .13 0 PCT 3 P2 F06 -1.26 TEC TEH .560 NBAZC 35 HI 113 80 .77 0 PCT 16 P2 F04 1.18 TEC TEH .560 NBAZC 35 HI I113 80 .13 0 INR P2 F5 -. 87 TEC TEH .560 NBAZC 35 HI 113 80 .19 0 PCT 5 P2 F05 .80 TEC TEH .560 NBAZC 35 HI I60 81 .24 0 PCT 4 P2 FO5 1.33 TEC TEH .560 NBAZC 33 HI I97 84 .50 0 PCT 11 P2 F05 -. 86 TEC TEH .560 NBAZC 31 HI 97 84 .49 0 PCT 11 P2 F06 TEC TEH .560 NBAZC 31 HI.78 109 84 .66 0 PCT 14 P2 F04 .64 TEC TEH .560 NBAZC 35 HI 109 84 .28 0 PCT 7 P2 F05 .94 TEC TEH .560 NBAZC 35 HI 109 84 .47 0 PCT 11 P2 F06 .96 TEC TEH .560 NBAZC 35 HI 190 85 .51 0 PCT 9 P2 F05 -1.49 TEC TEH .560 NBAZC 29 HI I90 85 NDD TSH TSH .560 NPS3C 109 HI 148 87 .20 0 PCT 6 P2 F@5 -1.70 TEC TEH .560 NBAZC 39 HI 100 89 .36 0 PCT 5 P2 F05 -. 70 TEC TEH .560 NBAZC 33 HI 53 92 .27 0 PCT 6 P2 F05 -. 44 TEC TEH .560 NBAZC 31 HI 99 94 .43 0 PCT 6 P2 F03 .59 TEC TEH .560 NBAZC 33 HI 109 84-- -- -+....+
0- 4 P+ --
F04.64---+- - - +5.+ . .- . 3+- H-I I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
+ ....------- +--+--+------+--+---.. .. -- -+--+-....+- +- +-+... --
Tubes: 20 Records: 27 1 ST Max
Attachment C.4 1 D Steam Generator Inservice Indications Page 29 of 32
SG - D ST Max Byron 1 BlR17 CAE 20110301 06/14/2011 10:15:23
+ . -. . - . . . + - --I- - - - -- .- .- .- -- + -+
-- - - ---- -- - -- - - - - - - - - -- - - - - - - - - --- - - - -+
-- .- .- .- -- .- .- - .- .--- . .- --. . - .- . - . .- +- - - +-
I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL Ll
+ .... + .... +--- "--+-....+-....- - --- -- -----..
+ .+ - -- + -- * - - - . - . --.+ .- ..-- --- .
.+ . . - --
51 8 .18 0 PCT 3 P2 08C -1.49 TEC TEH .560 NBAZC 15 HI TEC .60 EH BAZC 19 I 80 57 .23 0 PCT 3 P2 F06 - .90 TEC TEH .560 NBAZC 19 HI 106 57 .22 0 PCT 3 P2 F07 -1.82 TEC TEH .560 NBAZC 19 HI 112 57 .36 0 PCT 5 P2 FOB -1.77 /I TEC TEH .560 NBAZC 19 HI 113 58 .37 0 PCT 8 P2 F@6 .62 TEC .60 EH BAZC 17 I TEC TEH .560 NBAZC 17 HI 78 59 .23 0 PCT 5 P2 F05 1.36 78 59 .53 0 PCT P2 F@6 1.50 TEC .60 EH BAZC 17 I TEC TEH .560 NBAZC 17 Hi 86 59 .22 0 PCT P2 F@5 1.34 TEC TEH .560 NBAZC 17 HI 86 59 .33 0 PCT 7 P2 F06 1. 08 TEC TEH .560 NBAZC 17 HI 107 60 .61 0 PCT 9 P2 F06 - .44 107 60 .32 0 PCT 5 P2 F@7 .71 TEC TEH .560 NBAZC 17 HI 107 60 NODD TEC .60 EH BAZC 19 I 70 61 .22 0 PCT 3 P2 F07 1.88 TEC TEH .560 NBAZC 19 HI 112 61 .85 0 PCT 12 P2 F06 1. 11 TEC TEH .560 NBAZC 19 HI 91 62 .31 0 PCT 6 P2 F06 . 96 91 62 NODD TEC TEH .560 NBAZC 123 HI TEC ,60 EH BAZC 23 I 102 63 .68 0 PCT 12 P2 F@5 1.06 TEC TEH .560 NBAZC 19 HI 106 63 .39 0 PCT 7 P2 F@4 1.14 TEC .60 EH BAZC 23 I 106 63 .38 0 PCT 7 P2 F@5 1.10 TEC TEH .560 NBAZC 19 HI 113 64 .29 0 PCT 5 P2 F04 -1.74 TEC .60 EH BAZC 23 I 113 64 .53 0 PCT 8 P2 F05 -. 95 TEC TEH .560 NBAZC 17 HI 113 64 .32 0 PCT 5 P2 F06 1.43 TEC TEH .560 NBAZC 129 HI 72 65 .56 0 PCT 8 P2 F06 1.56 TEC TEH .560 NBAZC 21 HI 76 65 .43 0 PCT 7 P2 F@6 1.38 TSH .60 SH NS3C 27 I 84 65 .44 0 PCT 7 P2 F@6 1.26 TEC TEH .560 NBAZC 21 HI TEC TEH .560 NBAZC 21 HI 106 65 .51 0 PCT 8 P2 F06 -1.14 106 65 .62 0 PCT 9 P2 F07 1.49 TEC .60 EH BAZC 21 I TEC TEH .560 NBAZC 23 HI 99 66 .45 0 PCT 9 P2 F@5 1.24 99 66 NODD TEC TEH .560 NBAZC 23 HI TEC TEH .560 NBAZC 23 HI 105 66 .46 0 PCT 9 P2 F05 1.14 105 66 NODD TEC 56 TH NBAZ 21 I TEC TEH .560 NBAZC 23 HI 82 67 .53 0 PCT le P2 F06 1.34 90 67 .49 0 PCT 9 P2 F@6 1. 38 92 67 .53 0 PCT P2 F06 1.23 102 67 .64 0 PCT P2 F06 1.75 106 67 .32 0 PCT 6 P2 F05 -1.16 1 106 67 .49 0 PCT 9 P2 F06 1.53 108 67 .16 0 PCT 2 P2 FOB 1.73 112 11 0 PCT I P2 F05 -1.16 67
+ -' - ---
-- ...----- - --- - --+ -
- .. ..---- .. - .. - ..- - - +--
I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL Ll
+ . . . . +- +- - - - -- -+-..
- - -- + --
..- - +-- - - +- ------ - - -- - ----- -- . .+ . . .-- . . -+.+ .---- . . - - +-
1 ST Max
SG - D ST Max Byron 1 B1R17 CAE 20110301 06/14/2011 10:15:23 S- ----- -- ...-
.+ -- - - . - +- - - ----- - -- - -- - - + - - - ÷- -÷ I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
+-----+-----+------+----+-----+-----+----+ ----
+-----+ - - +-------
73 68 .18 0 PCT 3 P2 F05 - .60 TEC TEH .560 NBAZC 23 HI 73 68 NOD TSH TSH .560 NPS3C 129 HI 103 68 .64 0 PCT 9 P2 F06 .68 TEC TEH .560 NBAZC 23 HI 103 68 NDD TSH TSH .560 NPS3C 129 HI 113 68 .55 0 PCT 8 P2 F06 .92 TEC TEH .560 NBAZC 23 HI 113 68 NOD TSH TSH .560 NPS3C 129 HI 23 HI 112 69 .48 0 PCT 7 P2 F04 1.16 TEC TEH .560 NBAZC 23 HI 112 69 .61 0 PCT 9 P2 FO5 -1.63 TEC TEH .560 NBAZC 23 HI 112 69 .77 0 PCT 11 P2 F06 1.17 TEC TEH .560 NBAZC 117 78 .28 0 PCT 4 P2 07H .70 TEC TEH .560 NBAZC 31 HI 117 78 NOD TSH TSH .560 NPS3C 129 HI 58 79 .28 0 PCT 6 P2 F06 .84 TEC TEH .560 NBAZC 33 HI 69 82 .47 0 PCT 4 P2 F05 - .91 TEC TEH .560 NBAZC 35 HI 67 84 .29 0 PCT 6 P2 F06 1.51 TEC TEH .560 NBAZC 33 HI 75 84 .26 0 PCT 5 P2 F06 1.90 TEC TEH .560 NBAZC 33 HI 79 84 .24 0 PCT 5 P2 FO5 .97 TEC TEH .560 NBAZC 33 HI 65 90 .30 0 PCT 6 P2 F06 1.85 TEC TEH .560 NBAZC 37 HI 70 95 13 0 PCT 2 P2 F06 - .89 TEC TEH .560 NBAZC 43 HI S - - ------------------ + - - - - - - -------- + - - - - -. -+ -- - - -- +
I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 BEGT ENDT PDIA PTYPE CAL LI
÷ .... ÷ .... ÷ ..... 1----------+---+-------- ---------- ÷-
+÷ ------ +--" +--- . --- ÷ Tubes: 39 Records: 57 2 ST Max
Attachment D.1 NIS-1 Form Page 30 of 32
ATTACHMENT D FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As Required by the Provisions of the ASME Code Rules
- 1. Owner: Exelon Generation Company, LLC, 200 Exelon Way, Kennett Square, PA, 19348 (Name and Address of Owner)
- 2. Plant: Byron Station, 4450 North German Church Road, Byron, Illinois, 61010 (Name and Address of Plant)
- 3. Plant Unit: One (1) 4. Owner Certificate of Authorization (if required): N/A
- 5. Commercial Service Date: 09/16/85 6. National Board Number for Unit: N- 198
- 7. Components Inspected: Steam Generator Eddy Current Inspection - Refueling Outage 17 Component or Manufacturer or Manufacturer or State or Province National Board No.
Appurtenance Installer Installer Serial No. No.
IRCO0BA Babcock & Wilcox 7720-02 ILU-242904 165 I RC01BB Babcock & Wilcox 7720-03 ILU-242903 166 IRCOIBC Babcock & Wilcox 7720-01 ILU-242902 164 IRCO1BD Babcock & Wilcox 7720-04 ILU-242901 167
- 4. 9 4
- 4. 4. 4 .4 4 4. 4 4 NOTE: Supplemental sheets in the form of lists, sketches, or drawings may be used, provided (1) size is 8 Y2 in. x II in.,
(2) information in items I through 6 on this report is included on each sheet, and (3) each sheet is numbered and the number of sheets is recorded at the top of this form.
Page 31 of 32
FORM NIS-1 (Back)
- 8. Examination Dates: 03/17/11 to 03/27/11
- 9. Inspection Period Identification: Second Period
- 10. Inspection Interval Identification: Third Inservice Inspection Interval
- 11. Applicable Edition of Section XI: 2001 Edition through the 2003 Addenda
- 12. Date/Revision of Inspection Plan: April 1, 2011 / Revision 6
- 13. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval.
See Attached Report
- 14. Abstract of Results of Examinations and Tests.
See Attached Report
- 15. Abstract of Corrective Measures.
See Attached Report We certify that the statements made in this report are correct, b) the examinations and tests meet the Inspection Plan as required by the ASME Code,Section XI, and c) corrective measures taken to conform to the rules of the ASME Code,Section XI.
Certificate of Authorization No. (if applicable) Not Applicable Expiration Date Not Applicable Date 7 "- Signed For Exelon Generating Company, LLC By i Owner CERTIFICATE OF INSERVICE INSPECTION I, the undersigned,_holding a valid commission issued the National Board of il .d e sure Vessel Inspe tors and the State or Province of . and employed by r /
rave i inspected the components described in this Owner's Report during the period to .f ' and'state that to the best of my knowledge and belief, the Owner has performed examinations and ýake--corrective meas rs described in this Owner's Report in accordance with the requirements of the ASME Code,Section XI.
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 Owner's 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 xfVz a Ini'ctor's Signature National Board, State, Province", and Endorsements DateQAo 7, A. //
Page 32 of 32