ML060050336
| ML060050336 | |
| Person / Time | |
|---|---|
| Site: | Byron  |
| Issue date: | 12/05/2005 |
| From: | Exelon Generation Co, Exelon Nuclear |
| To: | Office of Nuclear Reactor Regulation |
| References | |
| 1.10.0101, BYRON 2006-0007 | |
| Download: ML060050336 (16) | |
Text
Exelon Generation Company, LLC BYRON STATION UNIT 2 4450 North German Church Road Byron, Illinois 61010 COMMERCIAL OPERATION: August 21, 1987 BYRON STATION UNIT 2 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT CYCLE 12 REFUELING OUTAGE September 2005 Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 Mailing Address 4300 Winfield Road Warrenville, IL 60555 Documentation Completed Date:
December 5, 2005 Page 1 of 31
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 Inspection Scope 7
4.3 Recording of Examination Data 8
4.4 Witness and Verification of Examination 8
5.0 EXAMINATION RESULTS 8
5.1 Indications Found 8
5.2 Other Results 10 6.0 REPAIR
SUMMARY
11 7.0 DOCUMENTATION 12 8.0 FIGURES/TABLES/ATTACHMENTS 12 Page 2 of 31
Exelon Generation Company, LLC BYRON STATION UNIT 2 4450 North German Church Road Byron, Illinois 61010 COMMERCIAL OPERATION: August 21, 1987 BYRON STATION UNIT 2 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT CYCLE 12 REFUELING OUTAGE September 2005 Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 Mailing Address 4300 Winfield Road Warrenville, IL 60555 Documentation Completed Date:
December 5, 2005 Page 1 of 31
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 Inspection Scope 7
4.3 Recording of Examination Data 8
4.4 Witness and Verification of Examination 8
5.0 EXAMINATION RESULTS 8
5.1 Indications Found 8
5.2 Other Results 10 6.0 REPAIR
SUMMARY
11 7.0 DOCUMENTATION 12 8.0 FIGURES/TABLES/ATTACHMENTS 12 Page 2 of 31
1.0 INTRODUCTION
Byron Station, Unit 2 operates with four Westinghouse Model D-5 recirculating steam generators (SGs) in the four loop pressurized water reactor system. The steam generators contain thermally treated lnconel-600 U-tubes that have a nominal outside diameter of 0.750 inches and a nominal thickness of 0.043 inches. The tubes are hydraulically expanded into the full depth of the tubesheet. The tubes are supported by stainless steel quatrefoil support plates (TSPs) and chrome plated lnconel-600 anti-vibration bars (AVBs). See Figure A.1 for a diagram of the D-5 steam generator configuration.
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 Section Xl 1989 Edition, IWB 2500-1, Examination Category B-Q, Item B 16.20, SG eddy current examinations were performed during the Byron Station, Unit 2 Cycle 12 refueling outage.
The inspections were performed consistent with the Electric Power Research Institute (EPRI)
PWR Steam Generator Examination Guidelines: Revision 6, applicable interim guidance and Nuclear Energy Institute (NEI) 97-06, Steam Generator Program Guidelines, Revision 1. The field inspection activities were conducted September 29 through October 5, 2005, by Westinghouse Electric Company Ltd. The following inspections were performed during this outage.
- 100% Full Length Bobbin Coil in all four SGs
- 20% Hot Leg Top of Tubesheet Plus-Point (+3 inches to 17 inches) Plus-Point in all four SGs
- 20% Plus-Point of Bulges >18 volts and Overexpansions >1.5 mils located within 17 inches of the top of the hot leg tubesheet in all four SGs
- 100% Hot Leg Top of Tubesheet (+3 inches to 17 inches) Plus-Point of Tubes with Potentially High Residual Stress in all four SGs
- 20% Plus-Point of the total number of Pre-heater baffle expansions contained in one SG with the inspections being equally distributed between three SGs
- 100% Visual Inspection of Previously Installed Welded Tube Plugs in all SGs
- 100% Visual Inspection of Previously Installed Mechanical Tube Plugs in all SGs
- 100% Visual Inspection of Newly Installed Tube Plugs in all SGs 2.0
SUMMARY
The guidance in Revision 6 of the EPRI PWR Steam Generator Examination Guidelines (i.e.,
EPRI Guidelines and applicable interim guidance) was used during this inspection. A degradation assessment was performed prior to each inspection to ensure the proper EPRI 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 2 site-specific condition in accordance with Section 6.3.2 of the EPRI Guidelines. All data analysts were qualified to Appendix G, Qualification of Nondestructive Examination Personnel for Analysis of Nondestructive 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. 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.
Page 3of31
The modes of tube degradation found during the current inspection were anti-vibration bar wear, pre-heater wear and foreign object wear. Pursuant to Technical Specification 5.5.9.c, Inspection Results Classification, the results of the inspection were classified as inspection category C-i for SGs ND and C-2 for SGs B/C. There were no scanning limitations during the examinations.
As a result of the current eddy current inspections and response to conditions found, a total of seventeen (17) tubes were repaired by tube 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 SGA SGB SGC SGD TOTAL Tubes Previously Plugged 144 113 53 22 332 Tubes Plugged in Cycle 12 0
10 4
3 17 Total Tubes Plugged 144 123 57 25 349 Total Tubes Plugged (%)
3.15%
2.69%
1.25%
0.55%
1.91%
Mode of Degradation SG A SG B SG C SG D Total
~nti-VibrationBar Wear 0
1 0
0 1
Pre-Heater Wear 0
2 3
1 6
Foreign Object Wear 0
6 0
1 7
Preventively Plugged 0
1 1
1 3
Cycle 12 Plugging Totals 0
10 4
3 17 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 Ill in accordance with the 1984 Edition of the American Society for Nondestructive Testing Recommended Practice SNT-TC-1A, Personnel Qualification and Certification in Nondestructive Testing. Exelon Generation Company, LLC (EGC) procedure ER-AP-335-039, Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing, Revision 2 and EGC procedure ER-AP-335-040, Evaluation of Eddy Current Data for Steam Generator Tubing, Revision 1, were used for data acquisition and analysis.
3.1.2 The examinations, equipment, 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; 1989 Edition of the ASME B&PV Code Section XI, Rules for Inservice Inspection of Nuclear Power Plant Components; and 1989 Edition of the ASME B&PV Code Section V, Nondestructive Examination;
- Each SG contains 4570 Tubes TABLE 2.2 Tubes Repaired During Cycle 12 Page 4 of 31
Revision 6 of the EPRI PWR SG Examination Guidelines; and NEI 97-06, Steam Generator Program Guidelines, Revision 1.
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 RID Tech Incorporated Model TC6700 Remote Data AcquisEtion Units (RDAU5) with ANSER Version 8.4.1, Revision 232 software was used to acquire the eddy current data. Analysis was performed with Westinghouse ANSER Version 8.4.3, Revision 121 computer software.
3.1.5 The bobbin coil examinations were performed with a 0.610 inch diameter bobbin coil eddy current probe. For low row U-Bend regions in Row 1 through Row 4, a 0.590 inch diameter bobbin probe was utilized.
3.1.6 The top of tubesheet, baffle plate expansion, and special interest rotating coil examinations were performed with a 0.610 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.
3.2 Personnel 3.2.1 The personnel who performed the eddy current inspections were qualified to Level II in accordance with SNT-TC-1A, 1984 Edition. A list of certified eddy current personnel who performed data acquisition for the examination are contained in Table A. 1 of Attachment A.
3.2.2 The personnel who performed the SG eddy current data analysis were qualified to a minimum of Level II, with special analysis training (i.e.,
Level IIA) in accordance with the 1984 Edition of SNT-TC-1A and Article IV-2000 of ASME Section Xl, 1989 Edition. 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 Qualified Data Analysts (QDA5).
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 Westinghouse Electric Page 5 of 31
Company, NDE Technologies Incorporated, Infineddy LLC, Anatec International, Corestar International Corporation and Master-Lee.
Secondary analysis was performed by Young Technology Services.
Discrepancies between the two parties required Level III concurrence between both parties for the final resolution.
3.2.6 An independent SG eddy current Level Ill QDA who was not part of the resolution team was employed to serve as a process control reviewer, in accordance with EPRI Guidelines, Section 6.3.3. The Independent Level Ill 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 Ill QDA reported directly to the EGC Level Ill inspector.
3.2.7 Personnel from Westinghouse Electric Company and Hudson Global Resources performed data acquisition.
4.0 EXAMINATION TECHNIQUE AND EXAMINATION SCOPE All eddy current examination techniques used are qualified in accordance with Appendix H of the EPRI PWR SG Examination Guidelines. Each examination technique was evaluated to be applicable to the tubing and conditions of the Byron, Unit 2 SGs.
4.1 Examination Techniques 4.1.1 The bobbin coil examinations were performed with a 0.610 inch diameter bobbin coil eddy current probe described in Section 3.1.5.
For low row U-Bend regions in Rows 1 through 4, a 0.590 inch diameter bobbin probe was utilized to achieve the complete full tube inspection. Nominal probe inspection speed was 40 inches per second and 24 inches per second for rows 1 through 4 U-bend regions. Sufficient sampling rates were used to maintain a minimum of 30 samples per inch. The bobbin coil probes were operated at frequencies of 550 kHz, 300 kHz, 130 kHz, and 20 kHz operating in the differential and absolute test modes. In addition, suppression mixes were used to enhance the inspection. These mixes were as follows: 550/130 kHz differential mix, and a 300/130 kHz absolute mix, a 300/130 kHz absolute mix, and a 550/300/130 kHz differential mix.
4.1.2 The plus-point examinations at top of tubesheet and pre-heater baffle plate expansion transition regions, and special interest locations were performed with a 0.610 inch diameter three coil plus-point eddy current probe described in Section 3.1.6. Nominal probe speed was 0.5 inches per second. A sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 25 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, Page 6 of 31
three process channels were used to display circumferential indications in the positive trace.
4.1.3 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.
4.1.4 The SG eddy current examination techniques used during this inspection were equivalent to the EPRI Appendix H 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 ETSS Probe Description ETSS Revision 96004.3 9
Bobbin AVB*/Pre~HeaterITSP*IForeignObject Wear, Free Span Flaws 96005.2 8
Bobbin Free Span Pitting 96007.1 10 Bobbin Tube Support Plate Outer Diameter SCC*
96043.2 0
Bobbin Single Land Pre-Heater Support Wear 96511.1 15 PIus-Point Low Row U-bend Primary Water SCC 96703.1 16 Plus-Point Dent/Ding Primary Water SCC 96910.1 8
Plus-Point Foreign Object Wear/Free Span/Tapered Wear Flaw Sizing 21409.1 4
PIus-Point Sludge Pile Outer Diameter SCC 21410.1 4
Plus-Point Expansion Transition Circumferential SCC 20510.1 5
PIus-Point Expansion Transition Axial Outer Diameter SCC 20511.1 7
PIus-Point Expansion Transition Axial Primary Water SCC 21998.1 3
Plus-Point Foreign Object Wear/Free Span Volumetric Indications 22401.1 3
Plus-Point Dent/Ding Axial Primary Water SCC
- AVB Anti-vibration Bar
- TSpTube Support Plate
- SCC..Stress Corrosion Cracking 4.2 Steam Generator Inspection Scope 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.
4.2.2 20% of the tubes in all SGs were inspected at the hot leg top of tubesheet expansion transition region (+3 inches to 17 inches) with a plus-point probe described in Section 4.1.2. In addition, all tubes (40) that were identified with potentially high residual stress were inspected at hot leg top of tubesheet expansion transition region (+3 inches to 17 inches) with a plus-point probe described in Section 4.1.2.
4.2.3 20% of the tubes in all SGs that contained bulges >18 volts and overexpansion >1.5 mils located within the hot leg tubesheet to depths of 17 inches below the top of the hot leg tubesheet were inspected with a plus-point probe described in Section 4.1.2. Tubes containing bulges and overexpansions within the initial sample were inspected from the top of Page 7 of 31
the hot leg tubesheet +3 inches to 17 inches below the top of the tubesheet.
4.2.4 20% of the total number of pre-heater baffle plate expansion transitions
(+1-2 inches) contained in one SG were inspected with a plus-point probe described in Section 4.1.2. These inspections were evenly distributed between SGs B/C/D.
4.2.5 Diagnostic examinations were conducted on non-quantifiable indications that were detected by the bobbin coil examination. Diagnostic examinations were also conducted on tubes in the vicinity of potential foreign objects in order to determine the extent of tubes potentially affected by the objects. These examinations were performed with the three-coil plus-point probe described in Section 4.1.2 above. A total of 198 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 Cycle 12.
4.3 Recording of Examination Data The raw eddy current data and analysis results were recorded on optical disks.
The data was then loaded into the Westinghouse Eddy Current Data Management System, ST Max, version 1.16.01. 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 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.
The Cycle 12 ASME Form NIS-1, Owners Report for lnservice Inspections, is contained in Attachment D.
5.0 EXAMINATION RESULTS 5.1 Indications Found 5.1.1 Anti-Vibration Bar (AVB) Wear Tube degradation was found during the Cycle 12 bobbin coil examination in the U-bend region due to fretting of the Anti-Vibration Bars on the tube. A total of 775 indications in 466 tubes were reported. The EPRI Appendix H bobbin coil examination technique 96004.3 was utilized in this inspection for the depth sizing of AVB wear.
The largest indication found was 40% through wall (TW) and was found in one tube (R39-C96 in SG 2B). The tube was subsequently plugged. Table 5.1.1 provides a summary of AVB Wear degradation. Attachment C Page 8 of 31
provides a listing of all indications with percent through-wall degradation, including AVB wear.
Table 5.1.1 Cycle 12 AVB Wear Summary SGA SGB SGC SGD Tubes*
Ind.
Tubes*
md.
Tubes*
md.
Tubes*
md.
<20%1W 73 92 115 146 98 124 56 68 20-39%TW 54 75 86 135 54 71 46 63
>=40%TW 0
0 1
1 0
0 0
0 TOTAL*
96 167 163 282 126 195 81 131
- Tubes may categories.
contain multiple indications and may be identified in multiple size 5.1.2 Foreign Object Wear Tube degradation was found in ten (10) tubes that was attributed to foreign object wear during the Cycle 12 inspection.
The indications ranged from 7% TW to 33% TW as measured by the EPRI Appendix H plus point qualified examination techniques 21998.1 and 96910.1. Three of the indications did not change from the previous inspection because the foreign object was removed in the prior outage.
Seven tubes were preventatively plugged and stabilized because foreign object retrieval could not be performed due to lack of access to the affected location. Table 5.1.2 provides a summary of the tubes that contained foreign object wear during Cycle 12.
Cycle Table 5.1.2 12 Foreign Object Wear Summary SG Row Column Depth Location Comment 2A 45 67 7%
TSP 02C+2.85 No Change from Cycle 11 2A 45 67 7%
TSP 02C+1.17 No Change from Cycle ii 2B 9
5 10%
TSP 05H+0.75 Plugged and Stabilized 2B 9
6 13%
TSP 05H+0.76 Plugged and Stabilized 2B 10 5
10%
TSP 05H+0.70 Plugged and Stabilized 2B 10 6
33%
TSP 05H+0.69 Plugged and Stabilized 2B 26 10 22%
TSP 07H+0.58 Plugged and Stabilized 2B 26 ii 12%
TSP 07H+0.62 Plugged and Stabilized 2D 1
55 26%
TSP 06C+0.26 Plugged and Stabilized 2D 24 65 11%
TSP 02C+1.00 No Change from Cycle ii 5.1.3 Pre-Heater Wear Twenty-two (22) tubes were found that contained indications of pre-heater baffle plate/TSP wear. The depth of the pre-heater wear ranged from 6% TW to 49% TW as measured by the EPRI Appendix H qualified bobbin coil examination technique 96043.2 for single land quatrefoil wear, 96004.3 for drill hole baffle plate wear and 96910.1 for tapered wear. Four (4) tubes were found with flaws greater than the 40%
TW repair limit. Six (6) tubes were plugged and stabilized as a result of pre-heater support wear. Table 5.1.3 below provides a summary of tubes that contain pre-heater wear.
Page 9of31
Cycle 12 TABLE 5.1.3 Pre-heater Baffle Plate/TSP Wear Summary SG Row Column Depth TSP Location 2B 15 91 6%
06C 2B 46 50 19%
07C 47 75 9%
02C 48 50 36%
07C 48 53 28%
07C 48 54 26%
07C 48 55 27%
07C 48 59 31%
07C 49 50 43%
07C 49 52 18%
07C 49 53 44%
07C 49 63 29%
07C 48 35 8%
02C 49 48 39%
07C 49 62 49%
07C 49 63 49%
07C 49 70 31%
07C 49 73 23%
07C 49 52 39%
07C 49 67 31%
07C 49 69 33%
07C 48 63 19%
07C 5.2 Other Results 5.2.1 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 25 welded plugs and 703 mechanical plugs were visually inspected.
In addition, all plugs installed during this outage (i.e., 34 mechanical plugs in 17 tubes) were also visually inspected and the installation parameters were reviewed for acceptable installation. No anomalies were found.
5.2.2 Preventative Tube Plugging Three tubes were preventatively plugged that did not contain through-wall tube flaws. Tube R15-C48 in SG 2D was preventatively plugged due to the hot leg tubesheet was found not to be hydraulically expanded into the tubesheet (NTE). Implementation of License Amendment 144 for a limited tubesheet inspection program relies upon the hydraulic expansion within the top 17 inches of the hot leg tubesheet. Since this tube did not contain a hydraulic expansion, the tube was removed from service. During the eddy current inspection, all tubes were reviewed for the presence of full tubesheet depth hydraulic expansions and this tube was the only tube identified that did not contain a full depth tubesheet hydraulic expansion.
Page 10 of 31
Tube R20-C90 in SG 2B was preventatively plugged and stabilized because it contained a 156-volt bulge (BLG) located 3 inches above the cold leg tubesheet.
Tube R25-C15 in SG 2C was preventatively plugged because it contained a 164-volt bulge located within the cold leg tubesheet at 11 inches from the tube end.
5.2.3 Attachments C contains tube lists with axial elevations of all imperfections that contain measurable through wall depth that were found during the Cycle 12 eddy current inspection.
6.0 REPAIR
SUMMARY
Repairs were conducted in accordance with ASME Section Xl, 1989 Edition. All tube plugging was performed by Westinghouse using Alloy 690 mechanical tube plugs. All repairs were performed in accordance with approved Westinghouse procedures. Table 6.1 depicts the repairs conducted during Cycle 12. Table 6.2 lists the tube locations that were repaired in Cycle 12.
TABLE 6.1 Summary of Cycle 12 Tube Plugging REPAIRS PERFORMED
-~
SG A SG B SGC SG0 TOTAL Tubes Plugged*
0 10 4
3 17 Tubes Stabilized 0
9 3
2 14
- Includes number of tubes stabilized and plugged.
TABLE 6.2 SG Tubes Repaired During Cycle 12 Stabilizer SG Row Col Repair Leg Indication Location 1
2B 9
5 Plug Hot Leg 10%
TSP 05H+0.75 2
28 9
6 Plug Hot Leg 13%
TSP 05H+0.76 3
2B 10 5
Plug Hot Leg 10%
TSP 05H+0.70 4
2B 10 6
Plug Hot Leg 33%
TSP 05H+0.69 2B 26 10 Plug Hot Leg 22%
TSP 07H+0.58 6
2B 26 11 Plug Hot Leg 12%
TSP 07H+0,62 7
28 20 90 Plug Cold Leg BLG TSC+3.00 8
2B 39 96 Plug None 40%
AV2+0.00 9
2B 49 50 Plug Cold Leg 43%
TSP 07C-0.08 10 28 49 53 Plug Cold Leg 44%
TSP 07C+0.11 11 2C 25 15 Plug None BLG TEC+1166 12 2C 49 48 Plug Cold Leg 39%
TSP 07C-0.52 13 2C 49 62 Plug Cold Leg 49%
TSP 07C-0.08 14 2C 49 63 Plug Cold Leg 49%
55 Plug Cold Leg 26%
TSP 06C+0.26 16 2D 15 48 Plug None NTE HL Tubesheet 17 2D 49 52 Plug Cold Leg 39%
TSP 07C+0.43 Page 11 of 31
7.0 DOCUMENTATION All original optical disks 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 2, Cycle 12 Steam Generator Inspection.
The report is also maintained at Byron Station.
8.0 FIGURES/TABLES/ATTACHMENTS Attachment A Contents Table A.1 Cycle 12 Data Acquisition Personnel Certification List Table A.2 Cycle 12 Data Analysis Personnel Certification List Figure A.1 Westinghouse Model D-5 Tube Support Configuration Attachment B Contents Attachment B.1 Hot Leg Bobbin Coil Inspection Scope Attachment B.2 Hot Leg Low Row U-Bend Bobbin Coil Inspection Scope Attachment B.3 Cold Leg Bobbin Coil Inspection Scope Attachment B.4 Hot Leg Top of Tubesheet Plus-Point Inspection Scope Attachment B.5 Baffle Plate Expansion Plus-Point Inspection Scope Attachment B.6 Special Interest Plus-Point Inspection Scope Attachment C Contents Attachment C.1 SG A ASME Form NIS-BB Attachment C.2 SG B ASME Form NIS-BB Attachment C.3 SG C ASME Form NIS-BB Attachment C.4 SG D ASME Form NIS-BB Attachment D Contents Attachment D.1 ASME Form NIS-1, Owners Report for Inservice Inspections Page 12 of 31
ATTACHMENT A PERSONNEL CERTIFICATIONS WESTINGHOUSE MODEL 0-5 TUBE SUPPORT CONFIGURATION Page 13 of 31
TABLE A.1 DATA ACQUISITION PERSONNEL CERTIFICATIONS No.
Name Company Level QDA (YIN) 1 Bland, Murray Hudson II No 2
Conner, Michael Westinghouse II No 3
Evering, Douglas Westinghouse II No 4
Fore, Steven Westinghouse II No 5
Glenn, Walker Westinghouse II No 6
Groh, Timothy Westinghouse II No 7
Hopper, Joseph Westinghouse II No 8
Mains, Philip Westinghouse II No 9
Miller, Gary Westinghouse II No 10 Reif, David Westinghouse II No 11 Smith, Anthony Westinghouse II No 12 Smith, Donald Westinghouse II No 13 Vernon, Donald Westinghouse II No Page 14 of 31
TABLEA.2 DATA ANALYSIS PERSONNEL CERTIFICATIONS No.
Name Company Level QDA (YIN) 1 Bowser, Craig*
Westinghouse Ill QDA 2
Brown, Marc*
NDE Technology lIlA QDA 3
Calender, Dominic Young Technical IIA QDA 4
Calender, Douglas Young Technical lIlA QDA 5
Case, John NDE Technology lIlA QDA 6
Cauvan, Michael Anatec IIA QDA 7
Chizmar, David Anatec IlA QDA 8
Circosta, Silvestro Young Technical lIlA QDA 9
Dye, John NDE Technology IA QDA 10 Ethridge, Gary Young Technical lIlA QDA 11 Gomez, Andrew Young Technical IIA QDA 12 Hill, John lnfineddy Ill QDA 13 Hover, Lynn Young Technical lIlA QDA 14 Ingenthron, Joseph Infineddy IIA QDA 15 Kajari, Igor Master-Lee IlA QDA 16 Kumar, Suresh Young Technical lIlA QDA 17 Lewis, Carol NDE Technology lIA QDA 18 Lewis, Damian NDE Technology lIlA QDA 19 Lynn, Vincent Master-Lee lIlA QDA 20 Martin, Anthony CoreStar lIA QDA 21 McLeod, Edward Young Technical IIA QDA 22 Newsom, Clinton Young Technical lIA QDA 23 Osborne, John Young Technical lIA QDA 24 Ostler, Eric Young Technical IlA QDA 25 Padgett, Lawrence Master-Lee IIA QDA 26 Popovich, Roy Westinghouse Ill QDA 27 Ready, Sean Young Technical lIA QDA 28 Rehak, Richard Master-Lee IA QDA 29 Richmond, Mark NDE Technology lIlA QDA 30 SaIls, Yohanne Young Technical lIlA QDA 31 Schmitz, Kenneth NDE Technology lIlA QDA 32 Siegel, Roger NDE Technology lIlA QDA 33 Stewart, Kenneth Young Technical IlA QDA 34 Stocklin, Kelly Young Technical lIA QDA 35 Sumrall, William Young Technical lIlA QDA 36 Taylor, Scott Westinghouse Ill QDA 37 Terning, Gary Westinghouse Ill QDA 38 Thompson, Kurt NDE Technology lIA QDA 39 Tobin, Robert Westinghouse Ill QDA 40 Visconti, Christopher CoreStar lIlA QDA 41 Webb, Joel Young Technical lIlA QDA 42 Wrubleski, Albert NDE Technology lIlA QDA 43 Yaklich, Daniel Westinghouse Ill QDA 44 Yatabe, Steven Young Technical hA QDA 45 Zevchak, James NDE Technology IIA QDA
- Independent Qualified Data Analyst Page 15 of 31
FIGUREA.1 Westinghouse Model D-5 Tube Support Configuration IJ5C 04C 03C O?C aic TSC TEC F~edw4~19r lnl~
AV~
A~itI~#IIiraIl oii hdr~
liii lOll 09 Fl 09 I-I IC IUC 0/Fl 05 Fl 07C t~3C O~Fl IJ1H Is H TIE I-I Nu z z I M~nw~y Page 16 of 31