LR-N02-0055, Stations Technical Specification 6.9.1.5 Annual Reports
| ML020710732 | |
| Person / Time | |
|---|---|
| Site: | Salem, Hope Creek  |
| Issue date: | 02/26/2002 |
| From: | Salamon G Public Service Enterprise Group |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| LR-N02-0055 | |
| Download: ML020710732 (54) | |
Text
PSEG Nuclear LLC P.O. Box 236, Hancocks Bridge, New Jersey 08038-0236 0 PSEG NuciearLLC FEB 2 6 2002 LR-N02-0055 U. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Gentlemen:
TECHNICAL SPECIFICATION 6.9.1.5 ANNUAL REPORTS SALEM AND HOPE CREEK GENERATING STATIONS DOCKET NOS. 50-272, 50-311, AND 50-354 PSEG Nuclear LLC hereby submits the enclosed Annual Reports for the Salem and Hope Creek Generating Stations, in accordance with Technical Specifications 6.9.1.5.3 and 6.9.1.5.b of Appendix A to Facility Operating Licenses Nos. DPR-70, DPR-75, and NPF-57.
Pursuant to Technical Specification 6.9.1.5.a, Enclosures 1, 2, and 3 are submitted for Salem Unit 1, Salem Unit 2, and Hope Creek, respectively. These enclosures contain 2001 data on the number of station, utility, and other personnel receiving exposures greater than 100 mrem/year and the collective exposures according to work and job function for each unit. provides information pursuant to the requirements of Technical Specification 6.9.1.5.b of Appendix A to Facility Operating Licenses No. DPR-75. The information pertains to the Salem Unit 1 steam generator tube inspection completed in 2001.
Pursuant to the requirements of Technical Specification 6.9.1.5.b of Appendix A to Facility Operating License No. NPR-57, the following information is provided concerning the Hope Creek Safety/Relief Valves (SRVs). During 2001, the SRVs were not challenged by any overpressurization events or transients that would have required the valves to respond. SRV testing was performed on installed SRVs during 2001 and the results were provided to the NRC in Hope Creek LER 01-007-00, sent via letter LRN 01-0415, dated, December 13, 2001.
SOoA 95-2168 REV. 7/99
FEB 2 6 2002 Document Control Desk LR-N02-0055 Should you have any questions or comments regarding this submittal, please contact Mr. Michael G. Mosier at 856-339-5434.
Sincerely, Gabor Salam n Manager - Nuclear Safety and Licensing Enclosures (4)
FEB 2 6 2002 Document Control Desk LR-N02-0055 C: Mr. H. J. Miller, Administrator - Region I U. S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406 Mr. R. Fretz, Licensing Project Manager - Salem U. S. Nuclear Regulatory Commission Mail Stop 08B2 Washington, DC 20555 Mr. R. Ennis, Licensing Project Manager - Hope Creek U. S. Nuclear Regulatory Commission Mail Stop 08B1 Washington, DC 20555 USNRC Senior Resident Inspector Office (X24)
Mr. K. Tosch, Manager IV Bureau of Nuclear Engineering P. O. Box 415 Trenton, NJ 08625
C PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 1 ANNUAL REPORT Salem 1 - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION All Personnel (> 100 mrem) Total Man-Rem Station I Utility I Contractors Station I Utility I Contractors Work & Job Function Employees I Employees I and Others Employees i Employees I and Others RX OPERATION & SURVEILL
-MAINTENANCE 57 0 10 17.300 0.023 4.120
-OPERATIONS PERSONNEL 29 0 0 7.733 0.000 0.628
-HEALTH PHYSICS 41 0 30 12.611 0.000 10.871
-SUPERVISORY PERSONNEL 16 0 164 6.648 0.221 67.072
-ENGINEERING PERSONNEL 0 0 0 0.005 0.000 0.012 ROUTINE MAINTENANCE
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 INSERVICE INSPECTION
-MAINTENANCE 0 0 3 0.117 0.000 0.913
-OPERATIONS PERSONNEL 5 0 0 0.888 0.000 0.001
-HEALTH PHYSICS 0 0 0 0.123 0.000 0.000
-SUPERVISORY PERSONNEL 3 0 34 1.140 0.086 10.722
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 SPECIAL MAINTENANCE
-MAINTENANCE 0 0 0 0.349 0.000 0.005
-OPERATIONS PERSONNEL 0 0 0 0.007 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 12 0.215 0.011 7.121
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 WASTE PROCESSING
-MAINTENANCE 0 0 0 0.304 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.090 0.000 0.002
-HEALTH PHYSICS 5 0 1 1.472 0.000 0.520
-SUPERVISORY PERSONNEL 0 0 0 0.005 0.000 0.002
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 REFUELING
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000
PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 2 ANNUAL REPORT Salem 1 - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION I All Personnel (> 100 mrem) II Total Man-Rem I Station I Utility i Contractors I Station I Utility I Contractors I Work & Job Function Employees I Employees I and Others I Employees i Employees I and Others TOTALS
-MAINTENANCE 57 0 13 18.071 0.023 5.038
-OPERATIONS PERSONNEL 34 0 0 8.719 0.000 0.631
-HEALTH PHYSICS 46 0 31 14.206 0.000 11.390
-SUPERVISORY PERSONNEL 19 0 210 8.008 0.318 84.917
-ENGINEERING PERSONNEL 0 0 0 0.005 0.000 0.012 GRAND TOTALS 156 0 254 49.009 0.341 101.989 TOTAL DOSE 151.338
ENCLOSURE2 PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 1 ANNUAL REPORT Salem 2 - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION I All Personnel (> 100 mrem) I Total Man-Rem I Station i Utility I Contractors I Station I Utility I Contractors Work & Job Function Employees I Employees I and Others I Employees I Employees I and Others RX OPERATION & SURVEILL
-MAINTENANCE 0 0 0 1.866 0.003 0.014
-OPERATIONS PERSONNEL 0 0 0 1.309 0.000 0.016
-HEALTH PHYSICS 1 0 0 0.779 0.000 0.026
-SUPERVISORY PERSONNEL 0 0 0 0.462 0.022 0.407
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.002 ROUTINE MAINTENANCE
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 INSERVICE INSPECTION
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.013 0.000 0.023
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 SPECIAL MAINTENANCE
-MAINTENANCE 0 0 0 0.001 0.000 0.036
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.018 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.008 0.000 0.523
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 WASTE PROCESSING
-MAINTENANCE 0 0 0 0.064 0.000 0.000
-OPERATIONS PERSONNEL 0 0 1 0.011 0.000 0.188
-HEALTH PHYSICS 1 0 1 0.461 0.000 0.238
-SUPERVISORY PERSONNEL 0 0 1 0.007 0.000 0.259
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 REFUELING
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000
PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 2 ANNUAL REPORT Salem 2 - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION I All Personnel (> 100 mrem) II Total Man-Rem I Station I Utility I Contractors II Station I Utility I Contractors Work & Job Function I Employees I Employees I and Others II Employees I Employees I and Others TOTALS
-MAINTENANCE 0 0 0 1.931 0.003 0.050
-OPERATIONS PERSONNEL 0 0 1 1.320 0.000 0.204
-HEALTH PHYSICS 2 0 1 1.258 0.000 0.263
-SUPERVISORY PERSONNEL 0 0 1 0.490 0.022 1.213
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.002 GRAND TOTALS 2 0 3 4.999 0.025 1.732 TOTAL DOSE 6.756
z PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 1 ANNUAL REPORT Hope Creek - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION I All Personnel (> 100 mrem) I Total Man-Rem I Station I Utility I Contractors I Station I Utility I Contractors Work & Job Function Employees I Employees I and Others I Employees I Employees I and Others RX OPERATION & SURVEILL
-MA.INTENANCE 105 2 9 29.402 0.949 3.300
-OPERATIONS PERSONNEL 54 0 2 16.808 0.000 0.678
-HEALTH PHYSICS 40 0 31 16.721 0.000 9.767
-SUPERVISORY PERSONNEL 50 9 197 13.982 2.588 67.107
-ENGINEERING PERSONNEL 0 0 0 0.010 0.000 0.036 ROUTINE MAINTENANCE
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 INSERVICE INSPECTION
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 SPECIAL MAINTENANCE
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 WASTE PROCESSING
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 REFUELING
-MAINTENANCE 0 0 0 0.000 0.000 0.000
-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000
-HEALTH PHYSICS 0 0 0 0.000 0.000 0.000
-SUPERVISORY PERSONNEL 0 0 0 0.000 0.000 0.000
-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000
PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-08-2002 Page 2 ANNUAL REPORT Hope Creek - Year of 2001 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION All Personnel (> 100 mrem) i Total Man-Rem Station I Utility i Contractors i Station i Utility i Contractors Work & Job Function Employees I Employees i and Others iI Employees i Employees I and Others TOTALS
-MAINTENANCE 105 2 9 29.402 0.949 3.300
-OPERATIONS PERSONNEL 54 0 2 16.808 0.000 0.678
-HEALTH PHYSICS 40 0 31 16.721 0.000 9.767
-SUPERVISORY PERSONNEL 50 9 197 13.982 2.588 67.107
-ENGINEERING PERSONNEL 0 0 0 0.010 0.000 0.036 GRAND TOTALS 249 11 239 76.923 3.537 80.887 TOTAL DOSE 161.347
ENCLOSURE4 Salem Unit I and Unit 2 2001 Steam Generator Tube In-Service Inspection Report In Spring 2001, Framatome Advanced Nuclear Products (F ANP) conducted eddy current examinations and performed primary production/resolution data analysis on the Salem Unit 1 steam generators (SG) during the 14th Refueling Outage (1R14). No inspections were performed on Unit 2 during 2001. The next scheduled outage for Unit 2 is in April 2002; therefore, this report only addresses Salem Unit 1. All inspections were performed under the supervision of the station's Steam Generator Group. Zetec Inc. performed secondary production/resolution data analysis. Moretech Inc., provided Independent Qualified Data Analysis and Station Level III oversight.
OVERVIEW Eddy current data acquisition was performed with the ROGER Manipulator using a dual guide tube tool head. Inspection data was transmitted to F ANP's Lynchburg, VA, and Benicia, CA, data room facility for primary production analysis and to Zetec's Issaquah, WA, data room facility for secondary production analysis. Resolution analysis was performed at the station's off-site data room facility. Primary production analysis of the bobbin coil data was performed manually by F ANP. Secondary production analysis of bobbin coil data was performed using Zetec's automated data analysis system. Both parties (primary and secondary) performed manual analysis of all rotating coil data.
The inspection scope was delineated in the 1R14 Steam Generator Tubing Degradation Assessment. This document identified the degradation mechanisms that have affected or could affect the tubing in the unit's steam generators, identified the inspection scopes and techniques to be used, documented the review of Electric Power Research Institute (EPRI) qualified techniques against site-specific steam generator conditions, and provided structural limits that were used to assess tube integrity requirements. The base eddy current examination scope met Salem Unit 1 Technical Specification requirements. A summary of the base scope follows:
"* Full-length bobbin coil inspection of 100% of the in-service tubes in each steam generator.
"* Rotating Coil (+ PointTM) exam of 100% of the Row I and Row 2 short radius U-bends in each steam generator.
"* Rotating Coil (+ PointTM) exam of 50% of the Hot Leg (HL) Top of Tubesheet (TTS) transition regions in 12 and 14 steam generators.
"* Rotating Coil (+ PointTM) exam of 100% of the >5 volt dented HL Tube Support Plate (TSP) intersections, based on 1R13 bobbin coil data.
"* Rotating Coil (+ PointTM) exam of 100% of the >5 volt HL free span dings based on 1R13 bobbin coil data.
"* Rotating Coil (+ PointTM) examination of previous tubesheet expansion anomalies.
"* Special Interest Rotating Coil (+ PointTm ) examinations as delineated in the 1R14 Steam Generator Tubing Degradation Assessment or as required based on the results of the outage's bobbin coil data analysis. of the Degradation Assessment provides a summary of the Non Destructive Examination (NDE) techniques utilized during 1R14 for detection (and sizing as applicable) of each degradation mechanism.
1
In accordance with Revision 5 of the EPRI Pressurized Water Reactor (PWR) Steam Generator Examination Guidelines, the station contracted Independent Qualified Data Analysts (QDA) from Moretech Inc., to verify the resolution process was properly performed and that field calls were properly reported.
Revision 5 of the EPRI PWR Steam Generator Examination Guidelines allows utilities to deviate from specific requirements through a documented technical justification for each deviation. Six technical deviations were implemented for 1 R14. All deviations were reviewed and approved by station management. A summary of the deviations is provided below:
0 1R14-01-001 deviated from the voltage normalization requirements specified in Rev. 5 for sizing Anti-Vibration Bar (AVB) wear indications. Revision 5 requires all bobbin examinations to be normalized off of the prime frequency on the four 20% through-wall holes and the voltage normalized to 4.00 volts. The station has historically deviated from this requirement and reports and sizes AVB wear by setting the 50% AVB wear scar to 5.0 volts. Raising the voltage on the AVB reporting channel offers greater consistency for sizing deeper wear scar indications than the lower voltage settings. For the purposes of comparing current data to historical data, the station continues to deviate from the Revision 5 voltage normalization requirement.
0 1R14-01-002 deviated from the calibration requirements for the rotating coil inspections.
EPRI Examination Technique Specification Sheet (ETSS) 20511.1, 20510.1, 20409.1, and 96511.2 require calibration on the 40% Inside Diameter (ID) axial and/or circumferential notches. The station calibration standards do not contain a 40% ID axial or circumferential notch therefore calibration is performed utilizing the 20% ID axial and/or circumferential notches. Calibrating on the 20% notches rather than the 40% notches is a deviationi in the conservative direction and offers following benefits:
- Heightens the analysts awareness of the smallest flaw in the calibration standard,
- Ensures that the 20% ID notch is not set horizontal and as such provides for better detection of smaller ID and OD flaws.
- 1R14-01-003 deviated from requiring all data analysts to pass the Site Specific Performance Demonstration (SSPD). Salem's contracted Level III Data Analyst assisted in the development of the training program and SSPD and, as such, is thoroughly familiar with plant specific data and steam generator tubing conditions. This individual was exempt from taking the SSPD.
0 1 R14-01-004 deviated from requiring that production data analysts review overcalls. The station does not feel this requirement adds value to the analysis process. The station would rather have production analysts err on the conservative side and let the more experienced resolution analysts make the final determination.
- 1R14-01-005 deviated from the requirement to perform a 20% eddy current inspection of installed F ANP Inconnel-690 rolled plugs based on material properties and industry inspection data.
- 1R14-01-006 deviated from the minimum required Electro-discharge machining (EDM) notches in the rotating coil calibration standards. Revision 5 requires a 100% axial and circumferential notch with a minimum length of 0.375" and a width of 0.003" to 0.006". The stations calibration standards do not contain the 100% circumferential notch that is required for calibration purposes by Revision 5 section 6.2.7.1 and EPRI ETSS's 20510.1, 20511.1 and 20409.1. For the scheduled 1R14 examinations utilizing these techniques, calibrations were performed utilizing the 100% axial notch. This was considered to be acceptable based on the operating experience of second-generation steam generators. Steam generators with thermally treated Alloy 600 tubing are considered second-generation steam generators that 2
exhibit greater resistance to Primary Water Stress Corrosion Cracking (PWSCC) and Outside Diameter (OD) corrosion mechanisms. Per the EPRI Steam Generator Progress Report, 1000805-R15, no reported circumferential cracking has occurred in thermally treated Alloy 600 tubing therefore for the Rotating Pancake Coil (RPC) examinations performed during 1R14, voltage calibration on the 100% axial notch was evaluated to be acceptable.
Assessment of Examination Results Consistent with the requirements specified in Nuclear Energy Institute (NEI) 97-06, Steam Generator Program Guidelines, the Unit 1 steam generators met the structural integrity, accident induced leakage and operational leakage performance criteria specified in site procedure SC.SA-AP.ZZ-0042(Q), Steam Generator Program for 1R14. The following table summarizes the number of tubes removed from service in each steam generator by degradation mechanism. In addition, cumulative tube plugging levels are provided.
Modes of Degradation 11 12 13 14 TOTAL.
SG SG SG SG Anti-Vibration Bar Wear 4 11 10 4 29 Loose Part Indications 1 0 0 1 2 Unacceptable Data Quality - Permeability 1 0 0 0 1 Variation (PVN)
Unacceptable Data Quality - Low Row 0 1 0 1 2 U-bend Obstructions Unacceptable Data Quality - Preventative 0 0 1 0 1 Tube Plug TOTAL TUBES PLUGGED 6 12 11 6 35 TOTAL TUBES PLUGGED CUMULATIVE 9 15 24 10 58 CUMULATIVE TUBE PLUGGING % 0.160 0.267 0.427 0.178 0.258 Anti-vibration Bar (AVB) Wear Tube wear at the tube/anti-vibration bar intersections has been occurring for many years in essentially all types of Westinghouse design recirculating steam generators. The mechanism is generally seen in peripheral tube regions but is also periodically observed elsewhere in the tube bundle. AVB wear has typically been the most significant cause of tube plugging to date in Westinghouse design Model F type steam generators. As identified in the 1R14 Degradation Assessment, AVB wear was considered the only active degradation mechanism for the cycle.
AVB wear indications were detected by bobbin probes as part of the 100% full-length inspection. The bobbin coil is qualified to size AVB wear indications per EPRI ETSS 96004.3.
AVB wear indications are plugged in accordance with technical specification requirements if bobbin indicates a depth > 40% through wall (TW). For Operational Assessment (OA) purposes, tubes with degradation less than 40% TW may be left in service or removed from service depending on the observed growth rate of the AVB wear degradation in each steam generator.
3
The criterion for calling AVB wear was based on a minimum percent TW depth of 10%. In 1 R14, 952 AVB wear indications were reported during the bobbin coil inspection. This compares to a total of 298 indications reported during 1R1 3 (655 new indications). The table below shows a history of AVB wear indications:
11 SG 12 SG 13 SG 14 SG 1R13 AVB Wear Indications 65 60 107 66 1 R1 3 Total Tubes with AVB Wear 36 37 64 34 1 R14 AVB Wear Indications 176 229 366 181 1R14 Total Tubes with AVB Wear 81 98 144 82 A total of 29 tubes were plugged for this damage mechanism. The table below lists the tubes plugged for AVB wear during 1 R14:
S/G Row Column Indication Location 11 40 17 42% AVB #5 11 41 52 43% AVB #3 11 44 21 46% AVB #2 11 44 78 40% AVB #4 12 39 67 39% AVB #3 12 39 105 38% AVB #5 12 39 106 38% AVB #4 12 40 102 43% AVB #3 12 40 103 40% AVB #4 12 42 99 43% AVB #3 12 42 102 40% AVB #3 12 42 103 64% AVB #4 12 46 82 39% AVB #4 12 47 99 40% AVB #5 12 50 28 38% AVB #5 13 43 58 51% AVB #3 13 43 84 43% AVB #3 13 43 100 40% AVB #3 13 46 61 50% AVB #4 13 50 83 54% AVB #3 59% AVB #3 13 50 46% AVB#5 13 52 90 41% AVB #4 13 53 90 53% AVB #4 42% AVB #3 13 70 54% AVB#4 13 54 74 41% AVB#4 14 40 18 43% AVB#5 49% AVB#2 14 57 25AV# 49% AVB #3 14 47 60 48% AVB #5 42% AVB #3 14 47 72 43% AVB #4 4
Based on these results, AVB wear is considered to be active during Cycle 15 in accordance with Section 3.3.2 of the EPRI PWR Steam Generator Examination Guidelines, Revision 5.
Intergranular Attack I Stress Corrosion Cracking (IGAISCC)
Detection of axial IGA/SCC in freespan dings, non-dented tube support locations and in the sludge pile was accomplished via the 100% full-length bobbin probe examination in each SG.
The following bobbin techniques were site qualified for detection of IGA/SCC at these locations:
= EPRI ETSS 96007.1 Rev 8, Detection of IGA/Outside Diameter Stress Corrosion Cracking (ODSCC) at non-dented drilled tube support plates.
SEPRI ETSS 96008.1 Rev 9, Detection of axial ODSCC at non-dented eggcrate supports and/or sludge pile region.
Potential IGA/SCC bobbin indications received a supplemental rotating probe inspection.
IGA/SCC at expansion transitions, above the tubesheet, at dented locations and within Row 1 and Row 2 U-bends cannot be reliably detected using bobbin probe techniques. Rotating probe techniques were used for detection of IGA/SCC at these locations.
In addition, IGA/SCC at tubesheet expansion anomalies is an area where degradation is likely to occur. For Unit 1, expansion anomalies include under expansions or Expansion Transition Locations (ETL's) and Over Expansions (OXP). An ETL is an area where the tubesheet expansion occurs below the secondary face resulting in an open crevice region where sludge deposits can accumulate. An OXP is an anomaly where the tube was expanded above the tube to tubesheet secondary face, which results in an area of higher stress. All identified expansion anomalies were inspected using a rotating coil technique.
The rotating coil inspections performed during 1R14 for detection of IGA/SCC are summarized below:
0 HL TTS - 50% of the tubes in 12 and 14 steam generators. The inspection extent was +2" above to -3" below the top of tubesheet interface.
- 100% inspection of the Row 1 and Row 2 U-bends in each steam generator. These inspections were performed under the Critical Area (C-A) inspection program described in Rev. 5 of the EPRI PWR Steam Generator Examination Guidelines with Row 1 considered the defined C-A and Row 2 the buffer zone. The basis for defining the C-A was industry experience.
- 100% of the > 5-volt dented HL tube support plate intersections in each steam generator.
0 100% of the > 5-volt HL freespan dings in each steam generator (HL TTS +0. 5" to
+2" beyond the 7 th HL TSP).
0 100% inspection of tubesheet expansion anomalies.
The following rotating coil techniques were site qualified for detection of IGA/SCC:
- EPRI ETSS 20510.1, Rev 1, + PointTM, Circumferential Primary Water Stress Corrosion Cracking (PWSCC)
There was no IGA/SCC reported during the inspections; therefore, this damage mechanism is considered NON-active for Cycle 15. These findings are consistent with that seen in the industry for similar design steam generators with low operating time.
Freespan Indications Both Manufacturers Burnish Marks (MBMs) and Free Span Differential (FSD) signals are the result of a light buffing of the tubes to remove small imperfections on the tubing outside diameter (OD). The two are analogous, with the exception that the FSDs are readily discernable in the differential channels, whereas MBMs are called in the absolute channel.
During 1R14, the station used the Free Span Bobbin Coil Indication flowchart in ETSS #1A 1R1 4 Bobbin Analysis for reporting MBMs and FSDs. Resolution analysts performed historical reviews of MBMs and FSDs to determine if the signals had "changed" by more than 15 degrees or more than 0.5 volts since the first In-Service post steam generator replacement (1 R1 3).
Confirmation of "change" required supplemental rotating coil testing. A total of three locations were inspected with rotating coil during 1R14 and anomalies were found.
Loose Parts All bobbin coil data was analyzed for loose part wear. There were no tubes identified as having bobbin coil loose part indications.
Two indications of loose part wear were detected during the low row L-.bend + OointTM inspections. The details of each are described below:
SR1C3 in 11 SG had indication of wear that was believed to be associated with a loose part located above the 7 th Cold Leg (CL) tube support that was :iigned with one of the tube support plate broach contacts. For structural integrity purposes, this indication was sized with + PointTM in accordance with EPRI ETSS 96910.1, Revision
- 4. The estimated depth of the wear indication was 2% TW. This anomaly was evaluated per F ANP Condition Report 6009106 and station Order 80027745. This tube was removed from service and no stabilization was required.
- R2C23 in 14 SG had indication of wear that was believed to be associated with a loose part located below the 7th cold leg tube support that was aligned between two of the tube support broach contacts coincident with an opening. For structural integrity purposes, this indication was sized with + Point'" in accordance with EPRI ETSS EPRI ETSS 96910.1, Revision 4. The estimated depth of the wear indication was 12% TW. This anomaly was evaluated per F ANP Condition Report 6009095 and station Order 70016253. This tube was removed from service and no stabilization was required.
Two tubes in 14 SG, R42C62 and R42C63, had possible loose part calls reported during the HL TTS inspections. No detectable wear was present in the area of the loose part calls. A secondary side visual inspection was not performed. This condition was evaluated per F ANP Condition Report 6009100 and station Order 80028087. Theses were not removed from service and will be monitored for wear during subsequent inspections.
In summary, a total of two tubes were repaired (plugged) due to loose part indications.
6
Data Quality Data quality is an important parameter influencing the overall performance of a steam generator tube examination system as it has an effect on probability of detection of degradation, sizing uncertainties, axial and azimuthal location uncertainties and orientation uncertainties. Through these uncertainties, data quality also becomes a key factor in data repeatability from one inspection to another. Greater emphasis was placed on data quality during 1 R14 in light of the Indian Point-2 tube rupture event. Four tubes were removed from service due to data quality concerns as summarized below:
- 1 tube was removed from service due to unacceptable noise caused by tubing characteristics. This type of noise is typically referred to as permeability variations or PVN.
0 2 tubes removed from service for being obstructed (OBS) to a 0.520" single coil diameter + PointTM probe. Both of these tubes were able to be inspected with a bobbin coil probe; however, they could not be successfully inspected with a surface riding
+ PointTM probe.
- One tube was removed from service due to the 0.520" diameter single coil + PointTM probe skipping or stalling in the low row U-bend region. Acceptable data could not be obtained in the area of interest. This tube was preventatively plugged (PTP).
The table below summarizes the tubes plugged for data quality concerns:
SG Tube ID Indication Location 11 R58C48 PVN 05H +6.69" to +32.09" 12 R1C43 OBS 07H +2.17" 13 R1C4 PTP 07H +5.81" 14 R1C79 OBS 07H +5.74" Tube Plug Inspections During 1R14, F ANP and station steam generator personnel performed a visual inspection of installed steam generator tube plugs to identify any abnormalities that may require further actions. In accordance with station procedures, steam generator tube plugs were visually examined for signs of leakage such as boron rings or moisture and to verify they were installed in their proper location. There were no anomalies noted during these inspections.
Technical Deviation 1R14-01-005 provided the justification for not performing a 20% volumetric (eddy current) inspection of installed F ANP Inconnel 690 rolled plugs based on material properties and industry inspection data.
7
FINAL ECT SCOPE The table below summarizes the final (base scope + special interest and/or expansions) scope performed during 1R14.
Area Probe Inspection Criteria # of Expansion Criteria F IExams Full Length Bobbin 100% of all in-service 22,481 N/A (tube end to tube tubes end) 2 Short Radius + PointTM 100% of all in-service 974 If PWSCC is found in Row 2 U-Bends Row I & 2 tubes inspect 20% of Row 3 in the affected SG. No expansions requiredduring 1R14.
3 HL TTS area @ an + PointMT 50% of the tubes in 12 5626 1. Confirmation of PWSCC extent of and 14 SGs or ODSCC (Axial or Circ.)
+2", -3" in each SG in the 50% sample of the HL tubesheet region in 12 and 14 SGs will require an expansion to 100% in the affected SG AND inspect a minimum of 20% of the TTS in 11 and 13 SGs.
- 2. If C-3 condition '!
identified in arV of the SGs HL TTS ,rogram inspect 20% cf Ci, TTS in affected SG. Ain expansions required
-- during 1R14.
4 Dented TSP I + FPont TM 100% of >5 volt dented 168 Dents & Dings. If C-3 Intersections TSPs and 100% of >5 condition is identified in any
(> 5 volts) and volts dings up to +2" of the SGs inspect 20% of CL Free Span Bobbin beyond the 7 th HL TSP > 5 volt dents and dings in Indications (Dings, in each SG affected SG. No expansions
>5 volts) requiredduring 1R14.
5 Tubesheet + Point TM Inspect all history ETLs 10 Any new ETLs or PTEs will anomalies and OXPs in the area be inspected in the area of of interest, interest. All new tubesheet anomaliesinspected with
+ PointTM probe.
6 Distorted + Point TM 100% of all bobbin 1 NA Tubesheet signals signals (DTI) 7 Distorted Support + Point TM 100% of all bobbin 20 N/A Signals (DSI) signals 8 Free Span Bobbin + Point TM MBMs or FSDs with 3 N/A Indications bobbin voltage greater (MBMs & FSDs) than 2 volts that exhibit growth or change from the baseline and/or 1R13 data will be inspected using
+ PointTM probes.
8
Technical Specification Classification The categorization of each steam generator is listed in the table below and takes into consideration both the bobbin coil and rotating coil inspection results.
11 12 13 14 SG SG SG SG Technical Specification C-2 C-2 C-2 C-2 Category Tube Mis-encode Part of the station's analysis process requires historical indications to be addressed on a tube not by-tube basis. During 1R14, this process identified one tube in 13 SG, R52C74, which did receive a bobbin probe inspection during 1R13. Tube R54C74 was mis-encoded as R52C74.
This mis-encode followed a wrist rotation whereby the guidetube carrying the encode of R52C74 was rotated to the R54C74 position. The other guidetube remained stationary under tube R53C74. This condition was documented under F ANP non-conformance report 6009096 and station notification 20063746.
Per Letter LRN-00-0050 dated February 28, 2000, the station submitted the Technical Specification 6.9.1.5 Annual Reports for the Salem Unit 1 and Unit 2 steam generator inspections completed during 1999. The report stated that a 100% bobbin coil inspection was performed in 11 through 14 steam generators.
This report makes a correction to the referenced submittal for 13 steam generator. Since tube R52C74 in 13 SG was identified as not being inspected during 1R13, the 100% bobbin coil inspection, as previously reported, was not performed. The station has determined there were no changes to the overall C-1 inspection results classification for 13 steam generator, as this tube had no degradation reported during 1R14. In addition, the station has determined there were no Technical Specification Violations due to this tube not being inspected during 1 R1 3.
Attachments The following data management summary reports are grouped as attachments, which provide the in-service inspection results per Technical Specification 4.4.5.5.b (Unit 1):
- Attachment 1- 11SG - 1 R14 Location and Percent Through Wall Indications
- Attachment 2- 12SG - 1R14 Location and Percent Through Wall Indications
- Attachment 3- 13SG - 1 R14 Location and Percent Through Wall Indications
- Attachment 4- 14SG - 1R14 Location and Percent Through Wall Indications
- Attachment 5- Identification of Tubes Plugged During 1R1 4
- Attachment 6- NDE Techniques Utilized for 1 R14 9
11SG 1R14 Location and Percent Through Wall Indications
SG Row Column %TW Location 11 26 91 13 AV1 -0.02 11 26 91 11 AV6 +0.00 11 29 112 11 AV5 -0.04 11 29 112 16 AV2 +0.21 11 31 10 10 AV6 +0.00 11 31 10 24 AV5 +0.00 11 31 10 16 AV2 +0.00 11 32 12 19 AV4 -0.03 11 32 31 14 AV2 +0.00 11 34 109 11 AV2 +0.00 11 35 44 10 AV6 +0.00 11 35 44 15 AV5 +0.11 11 37 79 12 AV4 +0.15 11 38 47 17 AV3 +0.00 11 38 47 11 AV5 +0.00 11 38 51 10 AV4 +0.00 11 38 78 25 AV5 +0.19 11 38 78 12 AV3 -0.13 11 38 105 10 AV2 +0.08 11 38 107 16 AV2 +0.00 11 38 107 19 AV5 +0.11 11 38 107 13 AV4 +0.13 11 38 107 33 AV3 +0.06 11 39 59 13 AV4 +0.00 11 39 59 28 AV3 +0.06 11 39 59 36 AV2 -0.08 11 39 59 10 AV1 +0.00 11 39 66 30 AV3 +0.00 11 39 66 18 AV6 +0.13 11 39 66 23 AV4 -0.09 11 39 99 12 AV2 +0.06 11 40 17 41 AV5 -0.13 11 40 17 22 AV2 +0.08 11 40 18 29 AV5 +0.15 11 40 18 19 AV4 +0.15 11 40 18 21 AV3 +0.17 11 40 43 10 AV6 +0.00 11 40 43 15 AV4 +0.00 11 40 43 25 AV3 +0.00 11 40 43 28 AV2 +0.00 11 40 47 30 AV5 +0.00 11 40 47 13 AV3 +0.00 11 40 47 14 AV2 +0.00 11 40 50 10 AV5 +0.00 11 40 50 11 AV4 +0.00 11 40 50 10 AVl +0.00 11 40 54 11 AV6 +0.00
SG Row Column %TW Location 11 40 54 18 AV4 +0.00
+0.00 37 AV3 40 54 11 11 40 58 11 AV3 +0.00 11 40 60 25 AV5 +0.00 11 40 60 18 AV4 +0.00 11 40 60 34 AV3 +0.00 11 40 60 15 AV2 +0.00 11 40 62 25 AV5 +0.02 11 40 62 19 AV4 +0.00 11 40 62 29 AV2 -0.23 11 40 62 24 AVI -0.02 11 40 78 17 AV3 -0.11 11 40 78 19 AV5 +0.13 11 40 79 17 AV3 +0.00 11 40 81 11 AV5 -0.73 11 40 81 24 AV3 +0.00 11 40 81 24 AV2 +0.00 11 40 84 12 AV4 +0.00 11 40 85 11 AV2 +0.00 11 40 104 14 AV5 +0.00 11 40 105 11 AV6 +0.00 11 40 105 12 AV5 +0.02 11 40 105 10 AV4 +0.00 11 41 19 13 AV6 +0.00 11 41 52 13 AV6 +0.04 11 41 52 15 AV4 +0.15 11 41 52 43 AV3 +0.10 11 41 52 22 AV2 +0.15 11 41 53 14 AV3 -0.15 11 41 53 14 AV2 -0.04 11 41 61 13 AV6 -0.08 11 41 61 27 AV5 +0.04 11 41 61 26 AV4 -0.17 11 41 61 25 AV3 +0.21 11 41 61 17 AV2 -0.08 11 41 61 15 AV1 +0.02 11 41 87 12 AV6 -0.08 11 41 90 13 AV5 -0.17 11 41 90 13 AV4 +0.23 11 41 103 11 AV1 +0.08 11 41 103 19 AV5 -0.02 11 42 19 26 AV6 +0.13 11 42 20 19 AV5 +0.00 11 42 20 20 AV4 +0.00 11 42 20 14 AV3 +0.00 11 42 20 12 AV2 +0.00 11 42 33 21 AV2 +0.09
SG Row Column %TW Location 11 42 33 14 AV3 +0.09 11 42 59 23 AV4 -0.36 11 43 23 10 AV5 +0.00 11 43 23 23 AV4 +0.00 11 43 23 12 AV3 +0.00 11 43 23 12 AV2 +0.00 11 43 25 14 AV5 +0.00 11 43 25 15 AV4 +0.00 11 43 25 10 AV3 +0.00 11 43 34 30 AV4 +0.13 11 43 34 13 AV5 +0.02 11 43 38 16 AV3 +0.00 11 43 38 15 AV2 +0.02 11 43 41 12 AV2 -0.10 11 43 41 21 AV3 +0.02 11 43 41 21 AV4 -0.10 11 43 43 17 AV3 -0.08 11 43 43 17 AV5 -0.08 11 43 44 15 AV3 -0.02 11 43 44 21 AV2 -0.06 11 43 46 26 AV6 +0.36 11 43 46 12 AV4 +0.00 11 43 49 11 AV4 -0.12 11 43 61 10 AV4 -0.25 11 43 61 27 AV3 -0.15 11 43 61 22 AV2 -0.13 11 43 64 31 AV3 +0.08 11 43 64 14 AV4 +0.08 11 43 75 12 AV1 +0.06 11 43 100 12 AV2 +0.00 11 43 100 17 AV3 +0.06 11 44 21 47 AV2 +0.13 11 44 21 30 AV3 +0.06 11 44 21 22 AV4 +0.15 11 44 21 22 AV5 +0.09 11 44 22 20 AV5 +0.00 11 44 23 15 AV2 +0.11 11 44 57 30 AV4 +0.02 11 44 57 18 AV3 +0.04 11 44 57 12 AV2 -0.02 11 44 67 11 AV2 -0.04 11 44 67 10 AV6 -0.13 11 44 67 18 AV4 -0.06 11 44 67 12 AV3 +0.02 11 44 68 12 AV5 -0.08 11 44 73 16 AV6 +0.04 11 44 74 11 AV6 -0.21
SG Row Column %TW Location 11 44 74 24 AV3 +0.00 11 44 77 20 AV6 +0.08 11 44 77 13 AV5 +0.15 11 44 77 18 AV4 +0.04 11 44 77 34 AV3 +0.08 11 44 78 27 AV6 +0.00 11 44 78 28 AV5 +0.17 11 44 78 40 AV4 +0.19 11 44 78 19 AV2 +0.04 11 44 78 19 AVl -0.27 11 44 100 16 AV5 +0.00 11 44 102 10 AV6 +0.00 11 47 99 10 AV3 +0.06 11 48 47 17 AV5 +0.28 11 49 29 10 AV5 +0.00 11 49 39 13 AV2 +0.00 11 49 43 16 AV4 +0.02 11 49 85 16 AV4 +0.08 11 49 85 10 AV3 +0.13 11 49 93 19 AV5 +0.15 11 50 82 14 AV6 +0.10 11 50 82 17 AV5 +0.08 11 50 82 20 AV4 +0.08 11 50 82 23 AV3 +0.06 11 50 82 34 AV2 +0.06 11 50 93 11 AV6 +0.00 11 53 33 33 AV5 +0.09 11 53 33 24 AV3 +0.17 11 53 35 13 AV6 +0.15 11 53 35 33 AV5 +0.00 11 53 35 21 AV4 +0.00 11 53 90 25 AV5 -0.04 11 53 90 16 AV4 -0.02 11 53 90 14 AV2 -0.15 11 54 86 13 AV3 +0.00
Attachment 2 12 SG I RI 4 Location and Percent Through Wall Indications
SG Row Column %TW Location 17 AV6 +0.00 12 23 91 12 AV6 +0.00 12 26 74 13 AV2 +0.00 12 26 103 11 AV3 +0.02 12 27 8 13 AV2 +0.00 12 27 115 13 AV5 +0.27 12 29 13 10 AV6 +0.00 12 29 39 16 AV2 -0.02 12 29 39 15 AV5 +0.11 12 29 86 12 AV2 +0.00 12 29 108 17 AV5 +0.14 12 29 112 17 AV5 -0.17 12 30 12 11 AV2 +0.00 12 30 13 15 AV2 +0.00 12 30 107 15 AV6 +0.00 12 32 109 21 AV4 +0.00 12 32 108 16 AV2 -0.02 12 36 15 15 AV3 +0.00 12 36 107 35 AV2 -0.04 12 36 107 34 AV5 +0.02 12 36 108 34 AV2 +0.11 12 36 108 28 AV5 +0.02 12 36 110 15 AV3 +0.13 12 38 104 12 AV2 +0.10 12 38 105 21 AV1 +0.10 12 38 105 22 AV2 -0.02 12 38 105 36 AV3 +0.00 12 38 106 21 AV6 +0.00 12 38 106 26 AV2 +0.29 12 38 106 36 AV5 +0.00 12 38 107 24 AV2 +0.00 12 38 107 20 AV3 +0.19 12 39 54 24 AV6 +0.00 12 39 63 31 AV2 +0.29 12 39 63 14 AV3 +0.02 12 39 65 25 AV3 -0.04 12 39 65 18 AV4 +0.02 12 39 67 24 AV5 -0.02 12 39 67 19 AV2 +0.00 122 39 67 39 AV3 +0.21 12 39 67 25 -AV4 +0.08 12 39 70 35 AV3 +0.19 12 39 70 18 AV4 +0.02 12 39 70 13 AV5 -0.04 12 39 103 37 AV2 +0.00
SG Row Column %TW Location 12 39 103 32 AV4 +0.00 12 39 103 31 AV5 +0.00 12 39 104 17 AV2 +0.17 12 39 104 27 AV4 -0.02 12 39 105 15 AV2 -0.06 12 39 105 21 AV4 -0.02 12 39 105 38 AV5 +0.04 12 39 105 19 AV6 +0.00 12 39 106 15 AVI -0.02 12 39 106 36 AV3 -0.06 12 39 106 38 AV4 -0.06 12 39 106 17 AV5 +0.00 12 40 24 15 AV4 +0.09 12 40 24 13 AV5 +0.00 12 40 45 11 AV3 +0.24 12 40 45 16 AV5 +0.22 12 40 45 16 AV6 -0.09 12 40 47 27 AV2 +0.00 12 40 47 15 AV4 +0.00 12 40 47 21 AV5 +0.00 12 40 62 24 AV3 +0.42 12 40 62 15 AV4 +0.13 12 40 78 11 AV4 +0.00 12 40 80 23 AV2 -0.06 12 40 80 27 AV3 +0.00 12 40 80 22 AV4 +0.00 12 40 80 14 AV5 +0.00 12 40 82 15 AV5 +0.00 12 40 82 11 AV4 +0.00 12 40 82 21 AV3 +0.00 12 40 83 21 AV6 +0.00 12 40 83 30 AV5 +0.00 12 40 83 17 AV4 -0.02 12 40 83 19 AV3 +0.00 12 40 83 15 AV2 +0.00 12 40 83 12 AVI +0.00 12 40 87 19 AV2 +0.10 12 40 87 18 AV3 -0.15 12 40 87 16 -0.02 AV4 +0.02 18 AV5 40 87 12 12 40 88 21 AVI +0.00 12 40 88 18 AV2 -0.04 12 40 88 25 AV3 +0.00 12 40 88 16 AV5 +0.00 12 40 91 27 AV2 -0.19
SG Row Column %TW Location 12 40 91 18 AV3 -0.02 12 40 91 25 AV4 -0.21 12 40 91 28 AV5 -0.17 12 40 91 19 AV6 -0.10 12 40 94 10 AV2 -0.13 12 40 94 16 AV3 -0.19 12 40 94 12 AV4 -0.27 12 40 95 19 AV2 -0.15 12 40 95 14 AV3 -0.27 12 40 95 17 AV5 -0.29 12 40 96 16 AV2 -0.15 12 40 100 13 AVI -0.15 12 40 100 24 AV2 -0.19 12 40 100 24 AV3 -0.02 12 40 100 18 AV5 +0.04 12 40 102 19 AVI +0.00 12 40 102 24 AV2 -0.12 12 40 102 43 AV3 -0.02 12 40 102 23 AV4 +0.02 12 40 102 19 AV6 +0.06 12 40 103 21 AVI +0.00 12 40 103 34 AV2 +0.02 12 40 103 40 AV4 +0.10 12 40 103 21 AV5 +0.02 12 40 105 18 AV1 +0.00 12 40 105 28 AV4 +0.00 12 40 105 21 AV5 +0.00 12 40 106 13 AV1 +0.02 12 40 106 28 AV3 +0.00 12 40 106 26 AV4 -0.04 12 40 106 27 AV5 +0.04 12 41 86 16 AV2 +0.09 12 41 86 16 AV3 +0.00 12 41 86 36 AV4 +0.00 12 41 86 19 AV5 +0.00 12 41 86 16 AV6 +0.00 12 41 87 19 AV3 -0.02 12 41 87 27 AV4 -0.06 12 41 87 21 AV5 -0.02 12 41 90 12 AV1 +0.30 12 41 90 19 AV2 -0.06 12 41 90 15 AV5 +0.04 12 41 92 15 AV2 -0.11 12 41 92 16 AV3 +0.00 12 41 92 21 AV4 +0.00
SG Row Column %TW Location 12 41 92 23 AV5 +0.00 12 41 94 12 AV5 -0.06 12 41 97 15 AV4 +0.13 12 41 98 17 AV6 -0.04 12 41 98 23 AV2 +0.06 12 41 101 15 AV1 +0.02 12 41 101 17 AV2 +0.08 12 41 101 21 AV5 +0.27 12 41 101 19 AV6 +0.21 12 41 102 15 AV5 +0.06 12 41 103 35 AV4 +0.08 12 41 103 29 AV5 -0.02 12 42 24 20 AVI +0.28 12 42 46 23 AV5 +0.02 12 42 47 13 AV1 +0.00 12 42 47 12 AV2 +0.00 12 42 47 22 AV3 +0.00 12 42 47 17 AV4 +0.00 12 42 47 21 AV6 +0.00 12 42 55 18 AV2 +0.00 12 42 55 19 AV3 +0.07 12 42 55 17 AV4 +0.09 12 42 55 28 AV5 +0.00 12 42 62 31 AV3 +0.04 12 42 62 36 AV4 -0.08 12 42 62 18 AV5 -0.02 12 42 62 16 AV6 -0.04 12 42 64 23 AV5 +0.00 12 42 64 11 AV3 -0.02 12 42 64 18 AV2 +0.21 12 42 99 17 AV1 +0.00 12 42 99 28 AV2 +0.00 12 42 99 43 AV3 +0.00 12 42 99 27 AV4 +0.00 12 42 102 13 AV2 +0.00 12 42 102 18 AV4 +0.04 12 42 102 24 AV5 +0.04 12 42 102 40 AV3 -0.04 12 42 103 64 AV4 +0.06 12 42 103 23 AV5 +0.04 12 43 27 18 AV2 +0.00 12 43 45 20 AV4 -0.19 12 43 45 13 AV5 +0.41 12 43 87 12 AV2 +0.11 12 43 87 26 AV3 -0.09
I SG Row IColumn %TW I Location__
12 52 80 20 AV2 +0.00 12 53 33 12 AV3 +0.09 12 56 77 14 AV4 -0.17 12 57 44 13 AV4 +0.06
.Attachment 3 13 SG 1R14 Location and Percent Through Wall Indications
SG Row Column %TW Location 13 19 80 13 AV6 +0.00 13 20 81 13 AV2 +0.37 13 23 117 14 AVl +0.74 13 25 38 13 AV2 +0.09 13 26 43 14 AVl +0.13 13 26 80 12 AV2 -0.04 13 27 115 10 AV6 +0.15 13 27 115 29 AV1 +0.22 13 30 114 32 AV5 +0.00 13 30 114 30 AV2 +0.00 13 31 32 10 AV5 +0.00 13 32 15 16 AV2 -0.09 13 32 16 13 AV2 +0.00 13 32 48 14 AV2 -0.06 13 32 108 16 AV5 +0.09 13 32 111 14 AV6 +0.02 13 32 111 24 AV5 +0.00 13 32 111 14 AV3 -0.07 13 34 48 22 AV4 +0.00 13 34 48 18 AVM +0.00 13 34 111 10 AV5 +0.18 13 34 111 11 AVI +0.13 13 36 80 14 AV5 +0.15 13 36 80 16 AV4 -0.17 13 36 80 25 AV3 -0.07 13 36 87 11 AV3 -0.15 13 36 87 14 AV2 +0.04 13 36 88 11 AV6 -0.04 13 36 88 20 AV4 +0.11 13 36 88 12 AV3 +0.04 13 36 88 12 AVM +0.13 13 36 97 21 AV3 +0.00 13 36 97 15 AV2 -0.09 13 36 109 13 AV2 -0.11 13 36 110 16 AV6 -0.04 13 37 58 20 AV2 +0.09 13 37 58 23 AV3 -0.04 13 37 100 21 AV5 -0.13 13 37 100 30 AV3 +0.04 13 37 100 12 AV2 +0.22 13 38 18 24 AV5 -0.02 13 38 18 20 AV4 -0.04 13 38 18 11 AV3 -0.07 13 38 18 10 AV2 +0.00 13 38 19 17 AV4 +0.00
SG Row Column %TW Location 13 38 19 13 AV5 +0.15 13 38 19 18 AV3 +0.00 13 38 28 12 AV4 +0.17 13 38 28 14 AV3 +0.11 13 38 39 13 AV5 +0.00 13 38 39 12 AV3 +0.15 13 38 53 11 AV2 -0.24 13 38 58 15 AV6 +0.00 13 38 58 20 AV5 +0.00 13 38 60 34 AV2 +0.19 13 38 60 30 AV3 -0.02 13 38 60 21 AV4 +0.00 13 38 60 17 AV5 +0.13 13 38 60 14 AV6 +0.09 13 38 66 17 AV5 +0.04 13 38 66 26 AV4 +0.04 13 38 66 11 AV3 +0.04 13 38 68 17 AV5 +0.00 13 38 70 17 AV5 +0.00 13 38 70 14 AV4 -0.09 13 38 72 28 AV4 +0.33 13 38 72 20 AV3 +0.26 13 38 72 22 AV2 +0.22 13 38 83 16 AV5 -0.11 13 38 83 20 AV3 -0.24 13 38 85 14 AV3 +0.00 13 38 86 16 AV6 -0.33 13 38 86 19 AV5 -0.15 13 38 86 20 AV4 -0.04 13 38 86 14 AV2 +0.04 13 38 86 13 AV1 +0.04 13 38 91 18 AV5 -0.15 13 38 91 15 AV2 -0.02 13 38 93 34 AV5 -0.02 13 38 93 23 AV4 +0.00 13 38 93 19 AV2 +0.02 13 38 94 24 AV2 +0.15 13 38 94 26 AV3 +0.07 13 38 94 11 AV4 +0.04 13 38 98 24 AV3 -0.07 13 38 98 19 AV2 +0.15 13 38 106 25 AV6 +0.00 13 38 106 18 AV5 +0.04 13 38 106 22 AV4 +0.00 13 38 106 28 AV2 +0.04
SG Row Column %TW Location 13 39 33 22 AV5 -0.04 13 39 33 10 AV2 -0.02 13 39 38 16 AV2 +0.09 13 39 38 12 AV3 -0.26 13 39 38 16 AV5 -0.06 13 39 47 16 AV6 +0.00 13 39 47 27 AV5 +0.00 13 39 47 20 AV4 +0.00 13 39 47 17 AV3 +0.00 13 39 47 27 AV2 +0.00 13 39 51 25 AV2 +0.19 13 39 51 26 AV3 +0.11 13 39 51 13 AV4 +0.09 13 39 51 11 AV5 +0.32 13 39 51 32 AV6 +0.09 13 39 54 23 AV3 +0.13 13 39 56 28 AV1 +0.06 13 39 56 11 AV2 +0.13 13 39 56 26 AV3 +0.19 13 39 56 33 AV4 +0.13 13 39 56 27 AV5 +0.09 13 39 58 21 AV1 -0.28 13 39 58 27 AV3 +0.04 13 39 58 18 AV4 +0.02 13 39 58 26 AV5 +0.24 13 39 58 19 AV6 +0.00 13 39 58 17 AV2 +0.15 13 39 65 10 AV4 +0.00 13 39 65 15 AV3 -0.09 13 39 65 16 AV2 -0.09 13 39 65 12 AV1 +0.07 13 39 66 11 AV3 +0.00 13 39 66 31 AV2 +0.00 13 39 66 13 AV6 -0.09 13 39 66 16 AV4 +0.00 13 39 70 20 AV5 +0.00 13 39 70 27 AV4 +0.26 13 39 70 13 AV2 -0.26 13 39 76 28 AV6 +0.00 13 39 76 18 AV5 +0.00 13 39 76 18 AV3 +0.37 13 39 76 30 AV2 -0.11 13 39 76 16 AV1 -0.09 13 39 80 15 AV2 +0.04 13 40 19 19 AV3 +0.00
SG Row Column %TW Location 13 40 62 18 AV2 +0.00 13 40 62 21 AV3 +0.00 13 40 62 28 AV4 +0.00 13 40 62 30 AV5 +0.00 13 40 82 10 AV6 -0.13 13 40 82 16 AV5 -0.07 13 40 82 25 AV4 -0.02 13 40 82 23 AV3 +0.26 13 40 82 30 AV2 +0.04 13 40 82 13 AV1 +0.02 13 40 84 28 AV2 -0.22 13 40 84 14 AV5 +0.00 13 41 20 24 AV4 +0.15 13 41 20 14 AV3 +0.17 13 41 31 19 AV4 +0.00 13 41 31 18 AV5 -0.15 13 41 85 21 AV2 +0.07 13 41 85 18 AV5 -0.07 13 41 85 14 AV3 -0.09 13 41 92 16 AV3 +0.04 13 41 96 20 AV3 -0.02 13 41 96 10 AV2 -0.09 13 41 103 17 AV6 +0.04 13 41 103 29 AV5 +0.00 13 41 103 17 AV4 +0.09 13 41 103 19 AV2 +0.02 13 41 104 16 AV3 -0.07 13 41 104 18 AV2 -0.04 13 42 33 18 AV4 +0.11 13 42 41 23 AV4 +0.00 13 42 41 19 AV2 +0.00 13 42 42 22 AV5 +0.11 13 42 42 22 AV4 -0.02 13 42 42 18 AV2 -0.11 13 42 44 28 AV6 +0.00 13 42 44 29 AV4 +0.00 13 42 44 35 AV3 +0.00 13 43 41 23 AV6 +0.13 13 43 41 23 AV5 +0.00 13 43 41 17 AV4 +0.00 13 43 41 20 AV3 +0.00 13 43 41 32 AV2 +0.00 13 43 41 18 AV1 +0.00 13 43 58 15 AV6 +0.26 13 43 58 34 AV5 +0.22
SG Row Column %TW Location 13 43 58 27 AV4 +0.13 13 43 58 51 AV3 +0.35 13 43 58 34 AV2 +0.13 13 43 62 14 AV5 +0.16 13 43 64 19 AV4 +0.07 13 43 66 17 AV5 +0.18 13 43 66 35 AV4 +0.11 13 43 66 20 AV2 +0.00 13 43 68 18 AV5 +0.00 13 43 68 24 AV4 +0.15 13 43 68 27 AV3 +0.07 13 43 68 33 AV2 +0.00 13 43 71 13 AV5 +0.09 13 43 72 17 AV6 +0.11 13 43 75 13 AV5 +0.09 13 43 80 10 AVI +0.00 13 43 84 15 AV6 -0.09 13 43 84 13 AV4 +0.18 13 43 84 30 AV2 -0.24 13 43 84 42 AV3 +0.13 13 43 84 17 AV5 -0.13 13 43 85 15 AV2 +0.13 13 43 86 20 AV6 +0.15 13 43 86 22 AV4 -0.04 13 43 86 15 AV3 -0.02 13 43 86 17 AV2 -0.09 13 43 87 22 AV6 -0.22 13 43 93 15 AV2 -0.13 13 43 97 15 AV5 -0.02 13 43 97 13 AV6 -0.02 13 43 97 16 AV4 -0.04 13 43 97 23 AV3 -0.07 13 43 97 18 AV2 -0.09 13 43 99 20 AV5 +0.04 13 43 99 33 AV4 +0.07 13 43 100 21 AV6 -0.02 13 43 100 34 AV4 -0.02 13 43 100 40 AV3 +0.00 13 43 100 30 AV2 -0.11 13 44 25 11 AV2 +0.00 13 44 61 26 AV6 +0.11 13 44 61 11 AV5 -0.27 13 44 61 24 AV4 +0.24 13 44 61 37 AV3 +0.11 13 44 61 13 AV2 -0.04
SG Row Column %TW Location 13 46 75 16 AV1 +0.00 13 47 24 28 AV5 -0.11 13 47 25 21 AV5 +0.00 13 47 26 13 AV6 +0.00 13 47 83 20 AV2 +0.11 13 47 83 35 AV3 +0.02 13 47 83 29 AV4 +0.07 13 47 83 20 AV5 +0.13 13 47 83 17 AV6 +0.13 13 47 96 15 AV4 +0.02 13 47 96 13 AV2 -0.09 13 47 98 14 AV6 -0.07 13 47 98 26 AV5 +0.00 13 47 98 32 AV6 +0.04 13 47 99 19 AV5 -0.04 13 47 99 34 AV6 +0.04 13 48 95 16 AV3 +0.00 13 48 97 22 AV6 -0.09 13 50 31 17 AV5 +0.06 13 49 94 18 AV6 +0.00 13 49 95 15 AV3 +0.13 13 49 96 22 AV3 -0.00 13 49 96 20 AV4 +0.00 13 49 96 28 AV5 -0.07 13 50 28 16 AV6 +0.00 13 50 79 12 AV2 +0.04 13 50 79 33 AV3 +0.15 13 50 79 28 AV2 +0.09 13 50 79 10 AV2 +0.00 13 50 83 13 AV1 +0.00 13 50 83 24 AV2 +0.00 13 50 83 54 AV3 +0.00 13 50 83 39 AV4 +0.00 13 50 83 22 AV5 +0.00 13 50 83 25 AV6 +0.00 13 50 84 32 AV3 +0.20 13 50 84 14 AV2 -0.09 13 50 92 25 AV4 +0.00 13 50 92 26 AV5 -0.02 13 50 92 26 AV6 -0.04 13 50 94 15 AV2 -0.04 13 50 94 15 AV1 +0.02 13 50 95 24 AV1 +0.04 13 50 95 10 AV2 +0.04 13 50 95 59 AV3 +0.02
SG Row Column %TW Location 13 50 95 20 AV4 +0.04 13 50 95 47 AV5 -0.13 13 50 95 27 AV6 +0.02 13 52 33 29 AV6 +0.00 13 52 33 21 AV5 +0.00 13 52 33 25 AV4 +0.00 13 52 33 19 AV3 +0.00 13 52 34 21 AV6 +0.11 13 52 89 15 AV2 +0.11 13 52 90 27 AV2 -0.02 13 52 90 31 AV3 +0.02 13 52 90 42 AV4 +0.02 13 52 90 16 AV5 -0.02 13 52 90 29 AV6 -0.02 13 53 33 23 AV6 +0.13 13 53 33 25 AV5 +0.13 13 53 57 13 AV2 +0.02 13 53 72 21 AV4 +0.13 13 53 88 12 AV4 +0.02 13 53 88 11 AV5 -0.09 13 53 90 33 AV3 -0.04 13 53 90 54 AV4 +0.07 13 53 90 29 AV6 +0.02 13 54 55 19 AV6 +0.19 13 54 55 24 AV5 +0.15 13 54 55 26 AV4 +0.04 13 54 55 11 AV3 +0.09 13 54 65 16 AV4 +0.00 13 54 65 20 AV5 +0.22 13 54 65 18 AV6 +0.18 13 54 70 30 AV5 +0.11 13 54 70 55 AV4 +0.22 13 54 70 43 AV3 +0.35 13 54 70 27 AV2 +0.00 13 54 70 20 AV1 +0.07 13 54 71 17 AV5 -0.09 13 54 72 12 AV5 -0.04 13 54 74 17 AV5 +0.02 13 54 74 28 AV3 +0.00 13 54 74 40 AV4 +0.00 13 56 66 10 AV3 +0.00 13 56 82 33 AV6 +0.09 13 56 82 39 AV5 +0.09 13 56 82 25 AV4 +0.09 13 57 77 22 AV5 -0.09
SG Row Column %TW Location 13 57 77 19 AV4 -0.18 13 57 77 35 AV3 +0.00 13 58 47 21 AV5 +0.00 13 58 47 25 AV4 +0.00 13 58 76 13 AV5 +0.11 13 58 76 18 AV3 +0.00 14 SG 1R14 Location and Percent Through Wall Indications
SG Row Column %TW Location 14 23 6 13 AVI +0.31 14 24 6 19 AVI -0.11 14 24 7 13 AV6 -0.20 14 24 116 19 AVI +0.00 14 24 116 11 AV6 +0.03 14 25 7 11 AV6 -0.11 14 25 8 20 AVI -0.13 14 25 36 17 AV6 +0.05 14 25 44 14 AV5 +0.00 14 25 115 15 AV6 +0.00 14 26 7 20 AVI +0.02 14 26 8 13 AVI +0.02 14 26 8 11 AV6 -0.22 14 26 114 12 AV3 -0.12 14 26 115 21 AVI +0.07 14 27 8 13 AVI -0.22 14 27 8 14 AV1 +0.20 14 27 8 12 AV6 -0.26 14 27 79 12 AV2 +0.09 14 27 79 16 AV5 +0.61 14 27 114 14 AV2 +0.00 14 28 8 36 AVI -0.07 14 28 8 12 AV6 -0.26 14 28 9 13 AV2 +0.28 14 28 12 11 AV6 +0.16 14 28 81 14 AV5 +0.17 14 28 111 13 AV2 +0.00 14 28 113 12 AV2 +0.00 14 28 113 16 AV5 +0.00 14 29 109 11 AV6 -0.15 14 29 110 14 AV5 +0.00 14 30 9 28 AV2 +0.07 14 30 9 12 AV6 +0.33 14 30 10 23 AV2 -0.11 14 30 63 13 AVI -0.07 14 30 72 17 AV2 +0.08 14 30 76 10 AV5 -0.38 14 30 107 13 AV5 +0.19 14 31 10 17 AV2 +0.00 14 31 10 17 AV5 -0.83 14 32 12 15 AV5 +0.00 14 32 84 21 AV2 +0.02 14 32 109 14 AV2 +0.00 14 32 111 11 AVI +0.00 14 32 111 10 AV2 +0.00
SG Row Column %TW Location 14 32 111 20 AV5 +0.00 14 32 111 11 AV6 +0.00 14 33 12 14 AV2 +0.07 14 33 12 12 AV5 +0.09 14 33 12 12 AV6 +0.11 14 34 109 17 AV3 +0.00 14 34 109 14 AV4 +0.00 14 37 83 34 AV5 -0.09 14 37 83 18 AV1 +0.22 14 38 16 32 AV4 -0.06 14 38 16 21 AV5 -0.02 14 38 16 21 AV6 -0.13 14 38 32 14 AV3 -0.09 14 38 40 22 AV2 +0.41 14 38 40 18 AV3 +0.13 14 38 40 29 AV4 +0.24 14 38 99 15 AV5 +0.00 14 38 101 19 AV2 +0.11 14 38 101 24 AV3 +0.04 14 38 101 20 AV4 -0.02 14 39 37 22 AV2 +0.00 14 39 37 21 AV3 +0.00 14 39 37 21 AV4 +0.00 14 39 37 32 AV5 +0.00 14 39 37 13 AV6 -0.22 14 39 56 15 AV3 +0.00 14 39 56 14 AV4 +0.00 14 39 56 13 AV5 +0.00 14 39 77 12 AV3 +0.00 14 39 77 15 AV4 -0.04 14 39 79 14 AV3 -0.26 14 39 96 17 AV4 -0.17 14 39 96 22 AV3 -0.20 14 39 96 19 AV2 -0.15 14 39 96 12 AV1 -0.20 14 39 97 20 AV3 -0.09 14 39 98 12 AV3 -0.13 14 39 100 22 AV3 +0.00 14 40 18 31 AV4 -0.09 14 40 18 43 AV5 -0.06 14 40 18 11 AV2 +0.04 14 40 48 14 AVI +0.00 14 40 48 20 AV5 +0.00 14 40 48 14 AV6 +0.00 14 40 51 31 AV3 +0.24
SG Row Column %TW Location 14 40 51 21 AV4 +0.09 14 40 51 15 AV6 -0.04 14 40 52 12 AV1 +0.00 14 40 52 16 AV3 +0.00 14 40 52 10 AV4 +0.00 14 40 52 26 AV5 +0.00 14 40 52 15 AV6 +0.00 14 40 56 11 AV3 +0.00 14 40 56 10 AV5 +0.00 14 40 60 15 AV3 +0.00 14 40 76 24 AV4 +0.00 14 40 76 21 AV3 -0.02 14 40 76 13 AV2 -0.15 14 40 80 16 AV3 +0.00 14 40 80 15 AV4 -0.24 14 40 80 12 AV5 +0.19 14 40 81 21 AV1 +0.04 14 40 81 20 AV2 +0.24 14 40 81 12 AV3 +0.37 14 40 81 20 AV4 +0.35 14 40 81 15 AV5 +0.33 14 40 81 10 AV6 -0.09 14 40 85 12 AV3 -0.30 14 40 85 13 AV3 +0.37 14 40 85 23 AV4 +0.32 14 40 85 16 AV5 +0.04 14 40 85 19 AV2 -0.17 14 40 87 12 AV2 +0.13 14 40 87 12 AV3 -0.04 14 40 87 12 AV3 -0.02 14 40 87 18 AV5 -0.02 14 40 106 10 AV3 -0.09 14 40 106 11 AV5 +0.00 14 40 106 11 AV6 +0.63 14 42 30 20 AV3 -0.24 14 42 30 24 AV4 -0.13 14 42 30 12 AV5 -0.02 14 43 54 26 AV2 -0.22 14 43 54 11 AV5 +0.00 14 43 55 29 AV3 +0.00 14 43 55 13 AV1 -0.04 14 43 55 31 AV2 +0.02 14 43 55 20 AV5 +0.13 14ý: 43 55 26 AV6 +0.11 14 1 43 55 13 AV4 +0.28
SG Row Column %TW Location 14 46 24 18 AV6 -0.19 14 47 25 22 AVI -0.06 14 47 25 49 AV2 -0.11 14 47 25 51 AV3 -0.11 14 47 25 31 AV4 -0.04 14 47 25 32 AV5 +0.26 14 47 25 18 AV6 +0.00 14 47 43 17 AV3 +0.04 14 47 48 22 AV2 +0.09 14 47 48 33 AV3 +0.06 14 47 48 23 AV4 -0.48 14 47 48 28 AV5 -0.11 14 47 48 18 AV1 +0.06 14 47 60 24 AV2 +0.02 14 47 60 12 AV3 +0.06 14 47 60 33 AV4 +0.62 14 47 60 48 AV5 +0.00 14 47 60 16 AV6 +0.02 14 47 72 44 AV3 +0.00 14 47 72 42 AV4 +0.00 14 47 81 20 AV1 +0.09 14 47 81 32 AV2 -0.02 14 47 81 36 AV3 +0.48 14 47 81 31 AV4 +0.48 14 47 81 17 AV5 +0.00 14 47 81 34 AV6 +0.00 14 47 83 19 AVI +0.00 14 47 83 36 AV3 +0.00 14 47 83 22 AV4 -0.19 14 47 83 28 AV5 +0.00 14 47 83 12 AV6 +0.00 14 50 28 21 AV5 -0.13 14 50 28 25 AV6 -0.15 14 51 31 15 AV5 +0.00 14 51 31 12 AV6 -0.13 14 53 38 15 AV6 -0.11 14 54 87 20 AV3 +0.06 14 54 87 27 AV4 +0.00 14 54 87 26 AV5 +0.00 14 54 87 21 AV6 +0.00 14 55 83 22 AV6 -0.13 14 56 41 16 AV4 +0.00 14 56 41 26 AV5 +0.00 14 56 41 21 AV6 +0.00 14 57 44 13 AV2 -0.11
SG Row Column %TWI Location 14 58 76 16 AV2 +0.04 11 I 4SG Identification of Tubes Plugged During 1R14
SG_ _Row Column 11 1 3 11 40 17 11 41 52 11 44 21 11 44 78 11 58 48 12 1 43 12 39 67 12 39 105 12 39 106 12 40 102 12 40 103 12 42 99 12 42 102 12 42 103 12 46 82 12 47 99 12 50 28 13 1 4 13 43 58 13 43 84 13 43 100 13 46 61 13 50 83 13 50 95 13 52 90 13 53 90 13 54 70 13 54 74 14 1 79 14 2 23 14 40 18 14 47 25 14 47 60 14 47 72 NDE Techniques Utilized for 1R14
Attachment 6 1RM4 NDE TECHNIQUES Degradation Detection Sizing Mechanism, Probe Technique Technique Orientation and ETSS # ETSS #
Location Axial PWSCC Tubesheet Region + PointTM 20511.1 Rev 1 96703.1 Rev 10 Circumferential PWSCC + PointTM 20510.1 Rev 1 96701.1 Rev 7 & 20510.1 Rev 1 Tubesheet Region Axial ODSCC Tubesheet Region + PointTM 20409.1 Rev 3 96703.1 Rev 10 Circumferential ODSCC + PointTM 20409.1 Rev 3 96701.1 Rev 7 & 20510.1 Rev 1 Tubesheet Region IGA/ODSCC Sludge Pile region Bobbin 96008.1 Rev 9 96703.1 Rev 10 Axial PWSCC in Freespan dings + PointM 20511.1 Rev 1 96703.1 Rev 10 Circ PWSCC in 96701.1 Rev 7 & 20510.1 Rev 1 Freespan dings + PointTM 20510.1 Rev 1 Axial PWSCC @
Dented TSP + PointTM 20511.1 Rev 1 96703.1 Rev 10 Circ PWSCC @
Dented TSP + PointTM 20510.1 Rev 1 96701.1 Rev 7 & 20510.1 Rev 1 Axial ODSCC @
Dented and non-dented TSP + PointM 20409.1 Rev 3 96703.1 Rev 10 Circ ODSCC @
Dented and + PointTM 20409.1 Rev 3 96701.1 Rev 7 & 20510.1 Rev 1 non-dented TSP IGA/ODSCC @
non-dented TSP Bobbin 96007.1 Rev 8 96703.1 Rev 10 AVB Wear in U-bend Region Bobbin 96004.3 Rev 7 96004.3 Rev 7 Axial PWSCC in Low Row U-bends + PointM 96511.2 Rev 10 96703.1 Rev 10 Circ PWSCC in Low Row U-bends + PointTm 96511.2 Rev 10 96701.1 Rev 7 & 20510.1 Rev 1 Flow Distribution Baffle (FDB) Wear Bobbin 96004.3 Rev 7 N/A N/A N/A Loose Parts - Bobbin Anywhere + PointTM N/A ETSS 96910.1, Rev 4