LR-N03-0077, Technical Specification 6.9.1.5 Annual Reports

Technical Specification 6.9.1.5 Annual Reports

ML030630790
Person / Time
Site:	Salem, Hope Creek
Issue date:	02/27/2003
From:	Salamon G Public Service Enterprise Group
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
LR-N03-0077
Download: ML030630790 (112)

Text

SPSEG Nuclear LLC P.O. Box 236, Hanoooks Bridge, New Jersey 08038-0236 FEB 2 7 2003 0 PSEG NuclearLLC LR-N03-0077 U. S. Nuclear Regulatory Commission Document Control Desk Washington, DC 20555 Gentlemen:

TECHNICAL SPECIFICATION 6.9.1.6 ANNUAL REPORTS SALEM AND HOPE CREEK GENERATING STATIONS DOCKET NOS.60-272, 60-311, AND 60-354 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.a 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 2002 data on the number of station, utility, and other personnel receiving exposures greater than 100 mremryear 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-70 and DPR-75. The information pertains to the Salem Unit I and Unit 2 steam generator tube inspections completed in 2002.

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 2002, the SRVs were not challenged by any overpressurization events or transients that would have required the valves to respond.

C-564 95-2168 REV. 7W99

Ji Diument Control Desk 2 FEB 2 7 2003 LR-N03-0077 Should you have any questions or comments regarding this submittal, please contact Mr. Michael G. Mosier at 856-339-5434.

len aSin Manager - Nuclear Safety and Licensing Enclosures (4)

,z Dacument Control Desk 3 FEB 2 7 2003 LR-N03-0077 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. G. Wunder, Licensing Project Manager - Hope Creek U. S. Nuclear Regulatory Commission Mail Stop 08BI 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

ENCLOSUREI PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-07-2003 Page ANNUAL REPORT Salem 1 - Year of 2002 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION I All Personnel (> 100 mrea) II Total Man-Rem I Station I Utility I Contractors II Station I Utility Contractors Work & Job Function I Employees I Employees I and Others II Employees I Employees I and Others RX OPERATION & SURVEILL

-MAINTENANCE 48 0 10 17.547 0.000 3.419

-OPERATIONS PERSONNEL 30 0 1 8.001 0.000 0.640

-HEALTH PHYSICS 18 0 33 5.308 0.000 11.458

-SUPERVISORY PERSONNEL 47 0 171 15.478 0.074 71.249

-ENGINEERING PERSONNEL 0 0 1 0.116 0.000 0.538 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 0.177 0.000 0.830

-OPERATIONS PERSONNEL 2 0 0 0.688 0.000 0.081

-HEALTH PHYSICS 0 0 0 0.055 0.000 0.000

-SUPERVISORY PERSONNEL 3 0 22 1.548 0.179 7.271

-ENGINEERING PERSONNEL 0 0 0 0.095 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 1 0.003 0.000 1.422

-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 WASTE PROCESSING

-MAINTENANCE 1 0 0 0.388 0.000 0.000

-OPERATIONS PERSONNEL 0 0 0 0.014 0.000 0.003

-HEALTH PHYSICS 7 0 4 2.617 0.000 1.509

-SUPERVISORY PERSONNEL 1 0 15 0.688 0.011 4.305

-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 / SALEMHOPE CREEK 01-07-2003 Page 2 ANNUAL REPORT Salem 1 - Year of 2002 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION 1P I I All Personnel (> 100 mrsem) II Total Man-Rem I I SStation I Utility I Contractors II Station I Utility I Contractors I Work & Job Function I Employees I Employees I and Others li Employees I Employees I and Others TOTALS

-MAfINTENANCE 49 0 13 18.112 0.000 4.249

-OPERATIONS PERSONNEL 32 0 1 8.702 0.000 0.724

-HEALTH PHYSICS 25 0 37 7.980 0.000 12.967

-SUPERVISORY PERSONNEL 51 0 209 17.718 0.264 84.247

-ENGINEERING PERSONNEL 0 0 1 0.211 0.000 0.538 GRAND TOTALS 157 0 261 52.723 0.264 102.725 TOTAL DOSE 155.712

ENCLOSURE2 PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-07-2003 Page I ANNUAL REPORT Salem 2 - Year of 2002 NUMBER OF PERSONNEL AND MMN-PEM BY WORK AND JOB FUNCTION II All Personnel (> 100 orero) II Total Man-Rem I Station I Utility I Contractors I I Station I Utility I Contractors Work A Job Function Employees I Employees I and Others II Employees I Employees I and Others RX OPERATION & SURVEILL

-MAINTENANCE 38 0 6 13.210 0.000 1.770

-OPERATIONS PERSONNEL 21 0 0 6.824 0.000 0.113

-HEALTH PHYSICS 18 0 41 5.493 0.000 10.969

-SUPERVISORY PERSONNEL 27 0 168 9.420 0.225 60.142

-ENGINEERING PERSONNEL 0 0 0 0.096 0.000 0.007 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 0.007 0.000 0.010

-OPERATIONS PERSONNEL 4 0 0 0.919 0.000 0.023

-HEALTH PHYSICS 0 0 0 0.000 0.000 0.082

-SUPERVISORY PERSONNEL 3 0 22 0.907 0.134 7.314

-ENGINEERING PERSONNEL 0 0 0 0.054 0.000 0.000 SPECIAL MAINTENANCE

-MAINTENANCE 1 0 1 0.506 0.000 0.249

-OPERATIONS PERSONNEL 0 0 0 0.000 0.000 0.000

-HEALTH PHYSICS 0 0 0 0.003 0.000 0.037

-SUPERVISORY PERSONNEL 0 0 43 0.330 0.006 12.059

-ENGINEERING PERSONNEL 0 0 0 0.061 0.000 0.061 WASTE PROCESSING

-MAINTENANCE 0 0 0 0.118 0.000 0.000

-OPERATIONS PERSONNEL 0 0 0 0.019 0.000 0.000

-HEALTH PHYSICS 2 0 2 1.108 0.000 1.333

-SUPERVISORY PERSONNEL 0 0 6 0.075 0.002 1.660

-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

I PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-07-2003 Page 2 *J ANNUAL REPORT Salem 2 - Year of 2002 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUWNC TION I I All Personnel (> 100 trer) II Total Man-Rem I I Station Utility U I Contractors II Station I Utility I Contractors Work a Job Function I Employees I Employees I and Others II Employees I Employees I and Others TOTALS

-MITENANcE 39 0 7 13.840 0.000 2.029

-OPERATIONS PERSONNEL 25 0 0 7.762 0.000 0.136

-HEALTH PHYSICS 20 0 43 6.604 0.000 12.421

-SUPERVISORY PERSONNEL 30 0 239 10.731 0.366 81.175

-ENGINEERING PERSONNEL 0 0 0 0.211 0.000 0.067 GRAND TOTALS 114 0 289 39.149 0.366 95.829 TOTAL DOSE 135.344

ENCLOSURE3 PUBLIC SERVICE ELECTRIC & GAS / SALEM/HOPE CREEK 01-07-2003 Page ANNUAL REPORT Hope Creek - Year of 2002 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCTION All Personnel (> 100 -rem) II Total Man-Rem I Station I Utility I Contractors [I Station I Utility I Contractors Work & Job Funotion [ Employees I Employees I and Others II Employees I Employees I and Others RX OPERATION & SURVEILL

-MAINTENANCE 18 0 0 7.453 0.000 0.088

-OPERATIONS PERSONNEL 24 0 0 6.119 0.000 0.410

-HEALTH PHYSICS 21 0 0 4.503 0.000 0.111

-SUPERVISORY PERSONNEL 6 1 1 3.991 0.370 1.139

-ENGINEERING PERSONNEL 0 0 0 0.001 0.000 0.016 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

-_TE 0 0 0 0.000 0.000 0.000

-OPERATIONS PERSONNEL 0 0 0 0.046 0.000 0.000

-HEALTH PHYSICS 0 0 0 0.005 0.000 0.000

-SUPERVISORY PERSONNEL 0 0 0 0.045 0.011 0.174

-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 0.138 0.000 0.000

-OPERATIONS PERSONNEL 0 0 0 0.026 0.000 0.001

-HEALTH PHYSICS 2 0 0 0.563 0.000 0.099

-SUPERVISORY PERSONNEL 0 0 0 0.393 0.000 0.074

-ENGINEERING PERSONNEL 0 0 0 0.000 0.000 0.000 REFUELING

-M INTENANCE 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 01-07-2003 Page 2 ANNUAL REPORT Hope Creek - Year of 2002 NUMBER OF PERSONNEL AND MAN-REM BY WORK AND JOB FUNCI ION I I All Personnel (> 100 ram) II Total Man-Rem I I Station I Utility I Contractors II Station I Utility I Contractors I Work & Job Function I Employees I Employees I and Others II Employees I Employees I and Others TOTALS

-MAINTENAvCE 18 0 0 7.591 0.000 0.088

-OPERATIONS PERSONNEL 24 0 0 6.192 0.000 0.411

-HEALTH PHYSICS 23 0 0 5.071 0.000 0.211

-SUPERVISORY PERSONNEL 6 1 1 4.429 0.381 1.387

-ENGINEERING PERSONNEL 0 0 0 0.001 0.000 0.016 GRAND TOTALS 71 1 1 23.283 0.381 2.113 TOTAL DOSE 25.777

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0 CO

Salem Unit 1 and Unit 2 2002 Steam Generator Tube ISI Report Summary In 2002, Framatome Advanced Nuclear Products (FANP) conducted eddy current examinations and primary data analysis on the Unit 1 and 2 steam generators during the 15'h (IRI5) and 12th (2R12) Refueling Outages. 2R12 was completed in the spring and IR15 the fall of 2002. All inspections were performed under the supervision of the station's Steam Generator Group. Zetec Incorporated performed secondary production/resolution data analysis and Moretech Inc.

provided Independent Qualified Data Analysis/Station Level III oversight. Attachment 1 lists the specifics for iR15. Attachment 2 lists the specifics for 2R12. These attachments provide a summary of the in-service inspection results per Technical Specification 4.4.5.5.b (Unit 1) and 4.4.6.5.b (Unit 2), identify the tubes repaired during each outage, and list the NDE techniques utilized.

For each outage, eddy current data acquisition was performed with the ROGER Manipulator using a dual guide tube tool head. Primary and Secondary production data analysis was performed remotely and resolution analysis was performed at the station's off-site data room facility. Primary degradation analysis of bobbin coil data was performed manually by FANP.

Secondary degradation analysis of bobbin coil data was performed using an automated system.

Two-party manual analysis was performed on all rotating coil data.

Site Validation In accordance with Rev. 5 of the EPRI PWR Steam Generator Examination Guidelines a documented review of EPRI Qualified techniques was performed to "site validate" the examination techniques. This review is documented in the following Vendor Technical Documents (VTD):

"* VTD 325276, Salem IRI5 Site Validation of Eddy Current Techniques for the SG Tubing Examination

"* VTD 325657, Salem 1R15 Site Validation of the High Frequency +Point Probe.

"* VTD 325490, Salem 2R12 Site Validation of Eddy Current Techniques for Salem Unit 2; 2R12.

Independent QDA To ensure the resolution process was properly performed and that field calls were properly reported the station utilized experienced Independent QDA personnel per the requirements stipulated in Rev. 5 of the EPRI PWR Steam Generator Examination Guidelines. Independent QDA responsibilities are delineated in site procedures.

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Abbreviations

1. H or #C Tubes Support Plate elevation Hot Leg or Cold Leg side of Steam Generator

1. R# Unt and Refueling Outage Number AV# ~ Anti-Vibration Bar Number designator (e.g. AV1 is Anti-Vibration Bar AVB(( Anti-Vibration Bar C-A II Critical Area CL ICold Leg CLT!I Cold Leg Thinning CM((Z Condition Monitoring DSIiI [ Distorted Support Indication ECTiII Eddy Current Test EDMI] Electro-discharge machining EPR!II]

Eii[I ] [Electric Expansion Power Research Institute I Transition Location (Expansion Anomaly)

ETSS II Examination Technique Specification Sheet FANPI[i Framatome Advanced Nuclear Products Incorporated FDBijI Flow Distribution Baffle FSD[{i Free Span Differential FSHI ] Free Span History FSI ] Free Span Indication FSS I Free Span Signal HL IHot Leg

[1-690 -[Inconel 690

[ID I Inside Diameter I

[IGA ] Inter Granular Attack I

[ISI I1 In-Service Inspection

[AI Z I Multiple Axial Indication

[ MBI I Manufacturer's Burnish Indication

[BIZH Manufacturer's Burnish Mark Mstory

[MBMZ] Manufacturer's Burnish Mark

[BIs I Manufacturer's Burnish Mark with Signal

[ ZNDE Z Non Destructive Examination

[I DD No Degradation Detected

[NEI Nuclear Energy Institute NIU* I] No Tube Expansion (Expansion Anomaly) 2

OA ((IOperational Assessment OBS[Z [ Obstructed OD l Outside Diameter ODSCC. Outside Diameter Stress Corrosion Cracking PAP (( Plug-a-Plug PIP Plug-in-Plug PLIIZ Possible Loose Part Indication PLPI ] Possible Loose Part PODI ] Probability of Detection

[PSI Possible Support Indication PMIP] Partial Tube Expansion (Expansion Anomaly)

[PVN II Permeability Variation PWSCC 71 Primary Water Stress Corrosion Cracking QDA [II Qualified Data Analyst

1. R# II] Unit and Refueling Outage Number R I I Row R2 II Row 2 R3 I [ Row 3 RFOI] Refueling Outage RPC Rotating Pancake Coil SAI I] Single Axial Indication SCC ] Stress Corrosion Cracking SOm ][ Steam Generator

[ ZSLC Suspect Ligament Crack

[SVI I]Single Volumetric Indication TEH [1 Tube End Hot TSH(([ Tubesheet Hot Leg Side TSPiZ [ Tube Support Plate TTS I [ Top of Tubesheet TW I] Through Wall Additional explanation of eddy current analysis code related abbreviations are found in site procedures Sl.SG-ST.RCE-0001, "Salem Unit 1 Steam Generator Eddy Current Examination",

and S2.SG-ST.RCE-0001, "Salem Unit 2 Steam Generator Eddy Current Examination".

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Attachment 1 Salem Unit 1 Refueling Outage Number 15 Summary

OVERVIEW The scope of the inspection were delineated in Engineering Evaluation No.

S-1-RC-MEE-1691, 1R15 Steam Generator Tubing Degradation Assessment. This document identified the degradation mechanisms that have affected or could affect the tubing in the unit steam generators, identified the inspection scopes and techniques to be used, and provided structural limit information that were used to assess tube integrity requirements. The base eddy current examination scope met Salem Unit 1 Technical Specification requirements and was developed and controlled in accordance with SC.SG-AP.ZZ-0001 (Q), Steam Generator Group Conduct of Operations. A summary of the base scope follows:

"* With the exception of those tubes selected for rotating coil inspection per the second bullet below, a full-length bobbin coil inspection was performed on 100% of the in service tubes in each steam generator.

"* Rotating Coil (+ Point) exam of 20% of the Row 1 and Row 2 short radius U-bends in each steam generator.

"* Rotating Coil (+ Point) exam of 30% of the Hot Leg (HL) Top of Tubesheet (TTS) transition regions in 11 and 13 steam generators.

"* Rotating Coil (+ Point) exam of 100% of the >5 volt dented HL Tube Support Plate (TSP) intersections, based on 1R14 bobbin coil data.

"* Rotating Coil (+ Point) exam of 100% of the >5 volt HL free span dings based on 1R14 bobbin coil data.

"* Rotating Coil (+ Point) examination of previous tubesheet expansion anomalies EPRI REV. 5 Technical Deviations Rev. 5 of the EPRI PWR Steam Generator Examination Guidelines allows utilities to deviate from specific requirements through a documented technical justification for each deviation.

Five technical deviations were implemented for 1RI 5. Justification for each deviation is documented in the confirmation for each order. All deviations were reviewed and approved in accordance with station procedures. A summary of the deviations is provided below:

• 80049986 - deviated from the normalization requirements specified in Rev. 5 to provide for more consistent sizing technique for Anti-Vibration Bar (AVB) wear indications.

• 80041191 and 800508461 - deviated from requiring all data analysts to pass the Site Specific Performance Demonstration (SSPD).

• 80041190 and 800408451 - deviated from requiring production data analysts to review overcalls.

• 80049985 - deviated from the process control requirements (e.g. 3 letter codes) delineated in Rev. 5.

• 80041194 and 800508441 - deviated from the volumetric inspection requirements for installed FANP Inconnel-690 rolled plugs

'Second order documents industry review which meets the intent of SGMP Memo dated October 7, 2002 regarding Interim Guidance for Technical Justifications of Deviations from NEI 97-06 and Referenced EPRI Guidelines 1

Assessment of Examination Results and Technical Specification Classification Consistent with the requirements specified in NEI 97-06, Steam Generator Program Guidelines.

the Unit I steam generators met the structural integrity, accident induced leakage and operational leakage performance criteria specified in site procedures for 1RI 5. This is documented in engineering evaluation S- 1-RC-MEE- 1711, 1R15 Steam Generator Condition Monitoring &

Operational Assessment Evaluation. 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 SGn SG12 lSG13 SGI4 1TOTAL Anti-Vibration Bar Wear [l II 11 12 [11111] 33 TOTAL TUBES PLUGGED L I 11 12 IZ] 33 TOTAL TUBES PLUGGED CUMULATIVE CUMULATIVE TUBE PLUGGING % 0.302 0.462 0.640 I0.213 0.404 The categorization of each steam generator is listed in the table below and takes into consideration both the bobbin coil and RPC inspection results.

Technical Specification C-2 Category I 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. AVB wear has been the most significant cause of tube plugging to date in Westinghouse design Model F type steam generators. As identified in Engineering Evaluation No. S-1-RC MEE-1691, 1R15 Steam Generator Tubing Degradation Assessment, AVB wear was considered an active degradation mechanism for the cycle.

During the baseline inspection and the two previous ISI's AVB wear was detected and sized utilizing an absolute mix per EPRI ETSS 96004.3. In an effort to obtain greater consistency in the sizing of AVB indications, for IRI5 the differential mix technique per EPRI ETSS 96004.1 was site validated and used. This required historical indications to be re-sized per technique 96004.1. This work was completed prior to 1R15 by Framatome ANP personnel and is documented in VTD 325625, AVB Resizing Bobbin Differential Depth Sizing of AVB Wear at Salem Unit 1. Changing techniques for identifying and reporting AVB wear did not result in an inspection transient.

2

AVB wear was detected during the bobbin coil inspections. AVB wear indications are plugged if bobbin indicates a depth > 40% through wall (TW). For Operations 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 degradation.

The criterion for calling AVB wear was based on a minimum percent TW depth of 10%.

In 1R15, 1387 AVB wear indications were reported during the bobbin coil inspection.

A total of thirty-three tubes were plugged for AVB wear. The following table lists those tubes plugged for this mechanism during 1RI 5:

3

Tubes Plugged for AVB Wear LShG Lowili Indication and Location 11 39 59 Av2 @44%TW 11 40 54 Av3 @ 42%TW 11 61 @41 AV441%TW&AV5 40%TW 11 43 I61 AV3 40%TW S11 I~I44I 77 AV3 @41%TW 11 50 82 AV2 @ 40%TW 11 53 33 AV5 @ 43%TW 1 II 53 35 AV5 @ 54%TW I 12 17 AV4 @3647%TW & AV5 @ 43%TW 12 36 108 AV5 @44%TW 12 38 106 AV5 @48%TW 12 39 70 AV3 46%TW 12 39 103 Av2 46%TW 12 39 104 AV4 44%TW 12 40 105 AV4 41%TW 12 41 86 AV4@ 40%TW 12 I41 103 AV449%TW 12 43 102 v3@ 45%TW & AV5 @ 43%TW 12 47 97 AV4 46%TW 13 30 AV "114 41ATW 13 38 18 AV5 40%TW 13 39 56 AV4@ 40%TW 13 40 84 AV2@ 45%TW 13 I41 103 AV5 @ 47% TW 13 44 61 AV6 @40%TW 13 45 101 Av5 42% TW 13 46 46 AV4 42%TW S13 I47 83 AV3 51%TW&AV4 @49%TW 13 47 98 AV4 45%TW 13 56 82 AV5 @44%TW 13 57 77 AV3@ 45%TW S14 II28 I I" AV@ 45%TW 14 47 I81 IAV3 @40%TW 4

In accordance with Section 3.3.2 of the EPRI PWR Steam Generator Examination Guidelines, Rev. 5, AVB wear is considered active during cycle 15. The following information was reviewed to make this determination:

11sG 12 SG 113 SG 14 SG

1. Ofnew>_20% TW indications 49 14 33 12

1. Of Previous indications that grew > 10%TW 105 121 216 58

1. Of new or Previous indication that grew > 40% 0 0 0 TW Intergranular Attack / Stress Corrosion Cracking (IGA/SCC)

Detection of IGA/SCC at expansion transitions, above the tubesheet, at dented (both freespan and at structures) locations and within row one and row two u-bends cannot be reliably detected using bobbin probe techniques. Rotating probe techniques were used for detection of IGA/SCC at these locations.

The rotating coil inspections performed during IRI5 for detection of IGA/SCC are summarized below:

e HL TTS - 30% of the tubes in 11 and l3steam generators. The inspection extent was +2 inches above to -3 inches below the top of tubesheet interface.

e 20% inspection of the Row I and Row 2 U-bends in each steam generator.

0 100% of the > 5-volt dented HL tube support plate intersections in each steam generator.

• 100% of the > 5-volt HL freespan dings in each steam generator (HL TTS +0. 5 inches to +2 inches beyond the 7th HL TSP).

• 100% inspection of Hot and Cold leg tubesheet expansion anomalies 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.

OPERA TING EXPERIENCE - ODSCC at the Tube SupportPlate(TSP) Intersections Per OE13898, Seabrook Station identified 15 tubes in the "D" steam generator that had 42 axial outside diameter (OD) indications by bobbin coil (and confirmed with the + point RPC) that were characterized as distorted support indications (DSIs). All axial OD indications found in the "D" steam generator were located between Rows 4 and 9, and between Columns 24 and 88. All these indications were located at the land areas of the quatrefoil tube support plates. Multiple land contact areas at some tube support locations were involved. Axial OD indications were reported on both hot leg and cold leg sections of the tubes. All cold leg indications were on tubes that also had hot leg indications. The tube support plate 5

elevations corresponding to the axial OD indications ranged from 2 to 6 on the hot legs and from 3 to 5 on the cold legs. No axial OD indications were found at top of tube sheet (TTS), in the u-bend areas, or at existing dings or dents. The indications appeared to be OD-originating, crack-like signals, and were confirmed by UT and + point. The maximum bobbin coil voltage was 0.91 volts, and the maximum + point voltage was 1.24 volts. Ultrasonic testing (UT) was performed on six of the tubes having axial OD indications. The UT confirmed all + point OD indications in the six tubes. At this time, these indications appear to be cracking. The flaws were sized to determine if in-situ hydrostatic testing was required. None of the flaws met the criteria of the EPRI guidelines.

PSEG Salem responded to OE13898 and documented this in SAP notification 20106474 and order 80048704. Proactive actions by Salem taken to support outage IRI5 included having Seabrook engineering send the write up that Westinghouse did on the eddy current signature of the degraded tubes. All of the Seabrook degraded tubes were found to display a unique signature or Null shift between the 06H and 06C tube support plates. This signature was easily noticed in the 150 kHz absolute strip chart. Per the Westinghouse write-up, this indicates a different material resistivity.

A review of the Salem 1R14 bobbin coil data was performed for the row 1 through 10 tubes in each steam generator to determine if a similar signature was present in the 150 kHz absolute strip charts. No tubes were found that displayed the Seabrook type eddy current signature between the 06H and 06C tube support plates. There were 3 tubes identified in S/G 14 with an eddy current signature that was not necessarily similar to Seabrook, but different than the bulk of the population reviewed. The tube numbers are R4 C75, RIO C83, and R2 C85. A review of the baseline data (1996) showed that the signature on these tubes has been the same since manufacture. The IRI5 data was reviewed and no change was noted to the signature of these tubes, and no indications were reported.

The station also received a copy of the eddy current data for the Seabrook degraded tubes that were verified by UT as being cracked. This data was incorporated into the Salem Site Specific Performance Demonstration database for training and testing of eddy current data analysis personnel.

Information incorporated into the Salem Unit #1 Data analysis-training manual included the NRC Information Notice 2002-21, the eddy current signature of the degraded tubes, and several examples of the Seabrook bobbin coil data for the cracked tubes.

During the examination a tube with the same type of signature as those displayed in the tube numbers shown above was noted in a higher row tube, R49 C54 in S/G

14. Although it is not clear if this condition can be found in higher rows, this condition was noted. These four tubes in 14-steam generator were documented in the eddy current database with a "FFO" code that means for future observation.

6

This will ensure the station monitors the condition of these tubes during future eddy current inspections.

Wear at Broached Tube Support Plate Intersections As stated in the 1R15 Degradation Assessment, wear at TSP intersections was classified as a potential degradation mechanism. During the course of the inspections in 1R15, wear was detected at one of the quatrefoil contact areas for the 71h TSP on the cold leg side of tube R28C8 in SG14. This was the first occurrence of TSP wear detected at Salem Unit 1. The indication was detected with a single coil Plus-point probe, during the special interest examination of an AVB wear indication in that tube. The bobbin coil inspection did not originally detect the indication during the production analysis of the tube. Further diagnostic testing with a 3-coil probe revealed that the indication was indicative of TSP wear at one of the land areas. A profile of the indication was developed using a broached TSP mix and simulated wear scars as defined by EPRI technique 96910.1 and is contained in Attachment 2. The maximum depth was estimated at 1 %TW. A review of the bobbin coil data was performed to determine if the indication was detectable in previous outages. In the current inspection, the indication was present in the bobbin coil data, however, based on the signal's response, it would not be expected to be detected without having the Plus-point data already available. The bobbin coil sized the indication at 7%TW using a broached TSP mix and simulated wear calibration curve using EPRI technique 96004.3. The signal was also present in the 1R14 bobbin coil data. An AVB wear calibration curve was used to estimate the size of the indication at 8%TW in 1R14. A review of the 1R13 bobbin coil data revealed no signal present at the subject location. This indicates that the indication most likely grew during cycle 14 to its current state, with no significant change during cycle 15. The TSP wear indication could have been left in-service since the sizing technique is qualified and the wear is very minor, but the tube was plugged during the current inspection due to an AVB wear indication >40%TW that also existed in the same tube.

Manufacturing Anomalies Manufacturers anomalies (e.g. MBM's and FSD's) were conservatively reported during the baseline inspection. The only requirement for reporting these anomalies was the indication had to be present in channel 6 (150 kHz absolute). Emphasis was placed on making sure all manufacturing anomalies were identified so they can be tracked during future exams.

During the previous two ISI's (1R13 and 1R14) both MBM's and FSD signals were monitored for change. During these two inspections, when MBM's or FSD's were reported during production data analysis, the resolution process required historical reviews of the anomalies to determine if the signals had "changed" by more than 15 degrees or more than .5 volts since the first ISI post steam generator replacement (1R13).

Confirmation of "change" required supplemental rotating coil testing. This process alone proved to be a tremendous burden to the resolution analysts that resulted in additional 7

resolution resources being added to each outage for what was judged to be low value added work.

Industry experience of cracking at freespan manufacturing anomalies has been limited to non-thermally treated first-generation steam generator tubing. Therefore, based on an assessment performed as a result of the 1R14 outage critique, it was determined that the evaluation of manufacturing anomalies could be streamlined during 1RI 5 without jeopardizing nuclear safety. The process emphasizes screening the data for "degradation" in the primary screening channel rather than monitoring all manufacturing anomalies for change. It was concluded that degradation in the freespan areas, including any degradation as a result of manufacturing anomalies, would be readily seen in this channel. This process is documented in the freespan flowchart of ETSS No. 1, IR15 Bobbin Coil Examination.

Loose Parts All data was analyzed for loose parts. Two tubes in 14 SG, R42C62 and R42C63, had possible loose part calls reported during the 1R14 HL TTS inspections. No detectable wear was present in the area of the loose part calls. These tubes were re-inspected during 1RI 5 and no change or wear associate with the possible loose part was observed. Visual inspections identified the PLP to be a small machine curl that could not be removed considering the location and condition.

Additional possible loose parts were identified at the following locations:

Row- Cofl Find Lo Vn-chý P I-1PL7P TSH 0.3 618 il 12 Fi1-PL-P FTsHT 0.31 1 /2f7 F-3Z]PL7P TSH1 0.1-0.27 F-]3-95 IjFPLP TS-H

[

7 21 59- PLP] FTSH 0.06 113 1F44- FIP LP FT-SH7 0.2 IF4k5- F637PLP TSH00 SjF4-5 -- [W ý]PL T-SH 0.-3 8 PLP locations did not have any associated tube wear identified. These conditions were reviewed and approved by PSEG engineering per Framatome-ANP CR 6018246-01, CR 6018247-01, and CR 6018258-00; for SG 11, 13, and 14 respectively. PSEG documented these in the corrective action program via notifications 20118380, 20118411, and 20118412 8

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 has been placed on data quality in light of the IP-2 tube rupture event. Site-specific data quality parameters were monitored during the analysis process in accordance with the parameters provided in the site ETSS.

There are several conditions that can reduce the data quality. Permeability Variation(PVN) is a condition where the test coil impedance changes due to a change in the tubing material's inherent willingness to conduct magnetic flux lines. PVN is a potential data quality concern that may impact inspection techniques performance indices (e.g. POD). Permeability variation signals are not considered flaws or degradation, but can possibly mask true indications. In accordance with PSEG's data analysis guidelines, corrective actions of PVN calls is based on final disposition of the PVN call with a magnetically biased rotating coil to reduce the eddy current noise levels of the area of interest.

PVN, and other tubing conditions that may reduce the data quality are addressed accordingly in the Data Analysis Guidelines.

During the R15 inspections, only one indication of PVN was identified during the bobbin coil inspection. The location was diagnostically tested with a mag-biased Plus-point probe and no degradation was detected at the location. The data was acceptable for analysis and no further action was required.

Sludge Mapping Sludge mapping of each steam generator was performed via an automated data analysis program utilizing the low frequency bobbin coil data. A total of 197 tubes were called with sludge. A breakdown per SG is provided below:

I sG 12sG 13SG 14 SG No of tubes with Sludge Calls 28 43 I ]L 65 Maximum Height Report 0.84" 0.87" J 1.91"

--Io 9

Tube Plug Inspections Visual Examinations of all hot and cold leg installed tube plugs were performed during 1R15 in accordance with procedure SC.SG-TI.RCE-0002 (Q), STEAM GENERATOR TUBE PLUG VISUAL EXAMINATION. Volumetric Examinations were not performed based on technical deviation 80041194. As a result of the visual inspections one tube plug in SG 14 HL, row 4 column 69, was identified as requiring additional review and evaluation. This location had an accumulation of boron that was slightly more that other tube plugs inspected. This condition was documented on F ANP Condition Report 6018110 and PSEG Notification 20117481 In accordance with the evaluation (CR) and inspections performed by Framatome and PSEG, the conditions identified during the plug visual inspections are acceptable. The minor boron was determined to be typical, subsequent inspections determined that the tube plug was acceptable.

No degradation of the tube plugs was noted in the visual inspections.

FINAL ECT SCOPE The table below summarizes the final (base scope + special interest and/or expansions) scope performed during 1R15:

Area ~Inspection Nof EpninCiei

__________ I___ Criteria irExams Exaso1Ciei Full Full Length engthservice 100% of all inin tubes 1 (Tube end to tube Bobbin each steam 22446 N/A end)eahsen generator 20% of all i- Detection of degradation may Short Radius +Point I and require verification, redefinition, 2 U-Bends TM 2 tubes in each 196 and expansion per Rev 5 of the (07H to 07C) stea gneato EPRI PWR Examination guidelines.

steam generator Expansion was not required.

30% of the HL TTS in-service Detection of degradation may

+Point tubes in SG 11 and require verification, redefinition, Hot Leg Top of TM SG 13. 3439 and expansion per Rev 5 of the Tube Sheet EPRI PWR Examination guidelines.

Extent is +2" Expansion was necessary for PLP above TTS and - bounding inspections.

3" below TTS I I Inspect all IR14 All new ETLs and OXPs will be 4 Tubesheet +Point history ETLs and 13 inspected with +Point in the area of Anomalies TM OXPs in the area interest. Three new tubesheet of interest anomalies were inspected.

100% of the > 5 Detection of degradation may Dented HL TSP +Point volt dented HL require verification, redefinition, 5 Intersections M TSP locations from 196 and expansion per Rev 5 of the

(> 5 Volt) the FDB to 07H in EPRI PWR Examination guidelines.

each SG. Expansion was not required.

10

4 T

SIn- Are ' Criteria peteZZ Exams

1. of Expansion Criteria 100% of the > 5 Detection of degradation may Dings in the Free vot dings in the require verification, redefinition, 6 Span +Point HL Free Span 51 and expansion per Rev 5 of the

(>5 Volt) locations from HL guidelines.

EPRI PWR Examinationrequired.

TTS +0.5" to 07H Expansion was not

+2" in each SG.

117 Visual inspection (Number to of 100% of the to 7 installed tube plugs misdrilled N/A Plugs Visual in each steam tubesheet generator, both hot welded and cold legs. plug in cold leg) 11

I t

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H F4-37 F-6-6-7 F2-3]FA--V5-1 F-0 -1 F13ý F4-3-IF--6-6---] FI-3-1 FA-V-6-] F 1 H F4-3-] F-6-6--] F3-4-ý FA-V4] F-0 -1 H F4-3-] F--6-8--l F3-5--l FA-V-3ý F-07 H F4-3-lF--6 --I F 1--1FAN 5-1a ý1 Fl-31 F4-3-ý F--68--]F-3-2--l FA-V-4] F-0 -]

H FUý F-6-8--jF3-5-TAN-flaff Fl-31 F 4-3-ý F 9 --I F IFA--V-61F -0 ý R13 F4-3 I F--69----l r-1-5-] f-AV-fl F-07 ffý3 F4-3-]F--6-9---l A-V74 F -0

ýF-12-ý H F4-3-]F-6 ] F 1FA-V-3 ] F -0 Fý3 F4-3-]F--7 -lF -lFA-V-51 Nýfl F3 43 72 o Fý3F4-3-IF-7-3--jF-1-9-1 FA-V -31F-0-.3-1 Fl-3lF4-3-]F--73---]FI-3--JFA-V-6-IF-O -1 Fl-31 F4-3-ý F-7-5 --- IF-I 87 FA-V-5 1F ]

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F13 F4-3]F--75-IFI-3-JFA-V-6]FO.-02-1 F13 F4-3-1 F- 1FIT] FA-V-41 aqfl F1-3ý F4-3-1 F-7-7-1 F-I3--lFA--V3jF5.727 FI-3]F4-3 ]F--8-0 1 F-1-9--l FA-V4] -0.13 H F4-31F-8 0-] F 1-7-1 FAV-31 [ýjj]

ý Fý3 F-4-3--]F--80---IF FAW-fl HF-43]F--8-0--IF-172FA-V-21 Fo-.o-fl H F-43 ý F 0- -ý F IFA-V-ll Fo-.761 F13 F4-3-1 F-8-11 F-2-1-]FA-VflFO-.08-ý HETIIý=Eyfl F-ýIll 38

• GCLUM RW  % OCATION 1311 43 81 II18 IIAV5 I-0.11 13143L IIJ 85 II20 ]AV2 LI*

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F13125 43l 97 AV6 113L 3II 97 I 19 I AV5 1-0.021 F133-0.06 4l 97 23 AV2 1314II 97 13 AV1 0.03 3133 F131l 97 AV4 0 13197 43 35 AV3Z-3 R13 43 99 23 Av5L-0 R13 43 99 22 AV3L]-

R13 43 99 34 AV4-o R1314j 25 19 AV2 -0 R13144j 25 18 AV3 -0.07 R13l44 26 20 AV3 -0.1 R13L4Z 26 19 AV2-o 11311 4 I 60 II14 IIAV3 [-0.0 1311 4 l 61 ]140 IAV61[-O-Z

[1314II 61 15 AV1 0.06 R13E4Ij 61 E9Z AV2 -0.02 L4 13331 61 I II 1 I AV5 0.1

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39

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-- ýFA 141 FUýF461F 46 7F28 WIN F3 T4 6

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[1-31 ffý3 rl-31 ffý3 H

F13 Fý3 FI-31 FI-31 F13ý rl-31 H

rl-3ý F131 0 rl-31 FI-31 F13 F13 FI-31 F13ý HEKIE:ýK:]=EYfl9Ej 41

I" SGCOLM]*

RO OCATION 1,31L4 98 37 AV5 0 1131 47 99 21 AV50 n13 47 99 19 AVi 0.14 1131 47 [I 99 II35 IAV611-0.05 n13 48 91 19 AV410 n13 48 95 16 AV3ZI Z n13 48 97 16 AV2L[ Z n13 48 97 21 AV4L1 Z n13 48 97 30 AV5EI-131 48 98 13 AV6 -0.02 1131 49 II 27 II16 IAVi l0.34[

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[13l 49 II 95 121 IAV4[I 0 1131 49 II 96 II30 IAV3Z10 F131 49 96 31 AV4-n13 49 96 35 AV5I[-I n13 49 96 15 AV2 0.03 1131 50 II 28 II20 ]AV4 1-0.6*

1131 50 II 28 II17 IAV5S-.5 n13 50 79 21 AV4Z[

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I13 50 I 92 [31 A 1-4 42

HFOýFýý RN F5-0-1 MTIWO ýOCATioý F-9-3-7-1 77 FAN-fl r-7571 IF31 F 5-OIF-9-4 -]F2-1 ][ýYf]F-07 Fl-31 F5-0-]F-9-4ý F2-3 ] FA-V2] F 1 ff A= F-5-0--]F2--0-] FA-V-61 Rýý]

RA F5-1 -1F-5-0--l F ]FA-V4] gjý FI-31 F5-1 F-19-ý FA-V-5-1 RE PF-5-1 IF-5-7 F 1 1FA-V-5ý FO-.O 3-]

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F,3ýF5-3-]F--33---ýF3-8-]FA-V5-]RE PF ýF p F5-3 ý F--3-3--lF-1 I FA-V-4ý F FO 57 RAF-53-T-3-3---T-31-1 FA-V--61 FO-.03-1 FI-31 F5-3-]F--57---]F-l3- -1FAN-41R F1-31F-5 37 r- -5 7- -ý F 1-6-] FAN 3-1 FBIF-5-37-57--] F IFA--V-2-1a ýj ffý3 F 5-3 ý F-72--ýF-22-ýFANTI Fo-.703 5ý3 F5-3-]F--8 8--ý F-18--l FA-V-4ý F-0 -ý RNF-53--lF--8 -lF-1 1FA--V--51 F ]

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FI3jF-54-]F-6-5-]F2-8-jFA-V-5j 113 Rý3 F lF--6-57EW1FA-V-6] FO-.I ý P F5-4-]F-7-1 -- ] F-17--l FA-V-5-1 gýý]

ff AF5-4--l F-7-2-1 F 1-7 ý FAN 5-1 gýfl RADTIEý FAV-61 43

6 SG RO OLMOCATION 131 54 73 23 AV5L[0 113[ 54 II 73 II19 [AV4[-.2 R13 54 73 21 Av3 0.14 1131 54 II 76 II15 IAV1 I-0.[:02 R13 55 39 19 AV4[

R13 56 66 14 Av3LI 1131 56 II82 IZ44IAV5 IF0-R13 56 82 29 AV40.

[131 56 II82 II 44IAV51 0II 1l3l 56 II82 II35 IAV6110.05 13 57 77 41 AV3I-0.03 131 57 77 26 AV4-0.05 F13 57 77 20 AV5ZIj 113] 571 77 141 IAV311-0.05 313 57 78 16 AV6-0.02 131 57 78 16 AV20.02 1131 57 79 16 AV2-06 1131 58 II47 II31 IAV5 -0.03 1131 58 II47 II31 IAV4 0.06 13 58 IAV1 -9.55 016 131 58 II75 II11 IAV2 Ij-1131 58 II75 l IAV31IFZ 18 1131 58 II76 II14 IAV310.02 1131 58 II76 II14 IAV61 0.0365

[13((58[ 76 II15 IAsIV-L 7 I1~13[591 61 II12 IAV6 0.5 13 5 61 II16 IAVI -0.06 14* 20 I 12 AIF -0.080 14 23 EI6IIt 21 [AVl 0I.58 14'*- 24 I21-] AV1 l-0.39 14- 24 7 17r*] AV6 [-0.22 14 24-] 116 24'* AV1 [-0.42 14 24 116 16 AV 6 -0.2 14~l 25 II19 - -AV6 -0.25 14~l 25 II12 iA- -0.1

@14251 I8I 30 A*i-0.23 44

RW SG COUMN OCATIOI*

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1141126 II114 II13 [AV2[ -0.14 R14126 115 31 AVl R14126 115 18 AV6 R14 26 116 15 Ar1 LI-R14 27 26 5 6AV

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RW SG COUMN OCATIOIN 4070 4l 28 fI 114l 28 II 8IIZ9I 8 I 10 I1 070 -. 41 I-0]'.39 F14 28 II l 10 070 -0.37 F14 28 1 JI9] 070 -0.35 F141 28 II 070 -0.32 F14 28 1141 28 IfIIIIs II J 070 -0.28* 070 -0.

1141 28 IZI sIILIs II 070 -0.26 1141 28 ~I sJI I J 070 1-0.241 114l 28 I JII7j 0I70 l-0.21 1141 28 F14 28 LI 1E2I7 I 070 1-0.19 070 -0.17 1l4l 28 II 8 IIZIZZ 070 [-0.15 141 28 I 07 -0.13 F14 28 I II7II 070 -0.1 1141 2s I8 II3j7 070 1-0.08 F14 28 I 070 -0.06 14 28 I 07 1-00 F14 28 II8 1141 28 LI 8I IIII 6II7j 070 -0.0 070 I-0.01 F14 28 I 8 I6j 070 0.0 F14 28 I II6I 070 0.05

[141 28 EI E I 5Z 070 I0.07 1141 28 II II5 I 070 01-6 F142 8 I 070 0.12

--214 8 II3~ 07 i-' 014--

214 8 I7I3~ 07 0.16*b 214 E8 IE 5 070 I 0.18 F14 8 5 070 0.21 F14 28 070 0.23 14~l 28 IIIs III 4LII 070 I 0.27 1428 II 18 II 07 0.29-6

• 142 ll8 jII 07 0.32*b 214 8 LI iII 1-070 -0.34 214 8 E ]I~I11-0.3-6 0 46

sH RO OUI ý OCATION R14 L28 [2 07C 0.38 114 2j IIi8iII I 8II 22[IIII07c 1141 i1L2 II 0.41 07C 10.43 R14 II Z I1j 07c 0.44 R14 28 9 25 AV20.27 1141 28 1141 28 I ZI~I912 I 12 IAV6-0.18 II17 IAV6 II0.05 11411 28 14 I14 AV6L0Z 1141 28 3 17 Av21j-j 1141 2 38 16 Av5LI Z 114 28 81 AV50.01

-16 F14] 28 109 11 AVl II 141 2 111 14 AV210.0

[141 28 II113 II14 iAV2 -0.17*

1141 28 II113 II10 IAv61 0.01 14 28 113 17 IAV5 o0.01 141 29 109 19 aV6-0.12 F14 29 109 15 AV21-0.05 1141 29 II110 II22 IAV51 -0.141 1*41 29 II110 II14 IAV2110.07 1l4l 29 ]l110 II10 [AVi -l0.12 1141 29 II111 II20 IAv5 I-0.091 1141 30 I~I 9IIZ 19 IAV6 o*o 1141 30 II 9 I 33 IAv21-.0 114l 30 II 9 I 18 IAV_5 -0.0 1141 30 10loI 14 AI -0.03 1!41 30 II 10 36 lAV21 -0.931 1141 30 II 10 II11 IAV50.1*

F14 30 20 AV20. 0.063 1141 30 II 63 II20 IAV50.5 R14 30 63 14 AVZII 11411,30 II 72 II20 AV2 0.2 1141 30 76 13 AV5-0.1 1l4I 30 [ 107 I[17 AV-5 0.01 F1430 111 I16 AV2[ 0 14-30 114 I13 AV2-0.594 47

SEOCATION 14 31 10 26 AV2 0.87 14 31 10 18 IAvl j n141 10 20 AV5 06 n14 31 10 28 AV5 -06 n14 31 10 11 AV51-0.2 n14 31 11 18 AV6 -0.09 n14 32 12 17 AV4 -0.08 14 32 12 24 AV5 0.01 n14 32 84 19 AV5LI n14 32 84 27 AV2-0.0 14 32 109 14 AV2 0.01 1141 32 II 111 II17 IAv2 II0.03 1141 32 II 111 II14 IAV1 01.05 n14 32 111 12 Av6 0.01 n14 32 111 I31 AV5 0.01 n14 32 112 10 av510.37 n14 33 12 16 Av5 0.02 14 33 12 19 AV6 0.03 n14 33 12 22 AV2 1 14 34 108 16 AV2--I 1141 34 108O I 13 IAV3 L[-I 114l 34 [I 108 I 10 IAV4((-0.1 n14 34 109 26 AV4 0.01 n14 34 I23 AV3 0010109 1141 34 II 111 II13 IIAV6 0.25*

1141 34 111l I 15 IAV2 -0.7 n14 37 83 10 AV4EI1 n14 37 I[083 34 Av5 .0

@J 37 83 l10 IAW 0.17 1437 10l3 II17 [AV5 [-0.0 14 38 i16 II24 IIAV6 II0.01 14" 38* 16 II28 IAvS 0.011 1]4]38 16 II35 IAV4 II0.01 14 38l 16 isIAv30.1ool 18 14l 38 [ 32 ((14 [AV3((0.01[

[1ll 38 II 40 II30 AV-*2-1 0.06 48

RW SG COUMN OCATIO F14 3=8 38 40 24 AV3 0.19 F14 38 40 31 AV4-0.0 114ll 3IJ 92 II11 [AV3 IF--

14lf 87l 99 II17 [AV5 [-0.14 1141 I7 101 17 AV5 0.02 14!l38IIJ 101 I 31 lAV31 0.07q_

14l37 101 26 AV4[0.1 II17 IAV21[0.01 11411 87I 101 11411 8 I 104 II17 IAV4 -. 0 114L1 flI 108 I 10 lAV3((-0.24 11411 8ZI 108 II14 IAV2l[-0.46 11411 9 I 37 II24 IAV211-0.091 14ll 9JI 37 II18 IAV61[-0.221 114E1 9 I 37 II36 IAV5 0o.01 11411 39 I 37 II28 ]IAV4110.01 11411 39j 37 II24 IAV3 [I0.01 114L1 9ZI 56 [I20 IAV511-0.13 F14l39 56 25 AV4I0.17 1'4El39II 56 II27 IAV3 II0.27 14[1 9] 68 II16 IAV611-0.22 114L139II 77 II25 iaV411-0.07 141 77 23 AV3 -0.02 F14L3Z 77 12 AV2 0 114K13 II 79 II16 IAV311-0.31 14L1 9II 96 II13 IAVi 1-0.26 114ll 37j 96 II19 IAV21 0.09 1141l 39 Z 96 II18 [AV3 .1 0I 114119 96 16 AV4 0 14L3Z 97 23 AV3 0.03 14413 98 17 AV3 0.14 114L139II 100 [24 [AV3110.01 11411 9jj 100 II16 [AV21 0.01 1411 OZI 48 II22 lAV611-0.22 14140I 48 31 IAV5-0.05 114L140II 48 l[11 lAV411-0.25 14140 IJ 48 II21 IAVl I-0.14 49

HFOýFOL TMIWIO OCATI 0

FI4-1F-47o F-5 -1 1 F ] FA-V-61 FO-.I 6-1 H F4-0-ý F- 1 ý F-V-1FAN-41FO-.3 5-1 F-41r77OF-5-1-IF-12 ]FA-V2]F6.-21j RF-470F--5-l7F-I3 ]FA-Vflgýfl RF4-0-]F-5-1--]F3-4 IFA-V3]FO-.14-]

HF-407--5-2--JF2-2-IFA--V-6-1 Fo-.072 Pý F4-0 ý F-5-2--l F3-5--]FA--V--51 Fo-.072 Fl-4] F4-0-]F--52 -]F2-7-1FA-WýFO-.271 F,4ýF4-0--]F-5-2--JFI-6-]FA-V-21F ]

Pý F4-0]F-52--IF2-0 ]FA-V-IJFO-.09-]

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FI-41 F4-0-1 F -8 0- - I F2-11 FAN 5-1FO-.O 3-ý R F4_07--8 0-- -I r 3- 1 FA-V-4-1R E R F4_0 IF-8-0-T-22-IFA-V-3 I Rýý R F-407 F-8-1--l F-12--lFAV-61 gýý FI-41 F4-0-ý F--8 1F2-4-ý FA-V-5] FO. 3-7]

Fl -41F4-0-]F--8-I - IF 3-1 -I FA-V-4] FO-.3 4-ý

-- ]F-- 81 -lF26TA- --v3l 0.32 14T4 Fl-41 F4-0]F- 1- -I F 3-1TA-V-2-IFO. 2-9 HF-46--] F-81 IF-28 IF-vil A o-o F141 F4-01F-8-1-ýF-ITIFA-V-4ý E F1-41F-47o ý F--85T-2 FA--V-5-1 F14 F-47o F--8-5---IF-31 IFA--V-4ý F050 -2 F14 F-40-ýF-8 5---] F 2-3 1 FA-V-3]1 0.3 4 1 IHEKIýýDK]Eyflgýý 50

HG RO OUM OCATION 1141j40 85 13 AV2 0.15 114Hj~ 80I5 29 IAV21[-0.191 114L1 0ZI 85 II12 IAV6 -0.1 11411 40 I 87 II14 IAV3 -0.0 11411 80I7 II27 IAV50.1*

114L1~1 80I7 I21 IAV40.10-114L1 0 j 87 II10 lAV20.1*

114L11 06 10I II15 IAV6 AV5 0.

0.0 141 40 I106 I12 40 11 AVI 05 1141106 1141 40 II106 II12 IAV3 II0.15 114[ 41 1I00 114 IAV3 [-0.07]

1141 41 100O I 13 IAV5SI*Z 1141 41 II105 II14 IAVl IV'-

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1141 43 II 53 II14 AV2--0.16i 1141 43 II,54 II17 AV60.0 1l41 43 II 54 II16 AV5- 0.21 1141 43 II 54 II17 AV4 0.3 I141 43 II 54 18 AV4 -0.3 1141 43 II 54 II20 AV3 V0.28 1141 43 II 54 II28 IAV210.0 1141 43 II 55 II25 IAVI 0.0 11411 43 II 55 II34 AlwV3-0.

1141 43 II 55 II32 IAV5 -. 0 1141 43 II 55 II23 IAV411-0.24 51

RO SG COLMI* OCATION 141 43 55 35 A2 0.05 14115543 28 AV60.0 114~1 4I 102 II13 lAV2 -0.14 1141 IZ 102 13 AV3 -0.03 1141 45 II 22 II14 IIAV4 1-0.051 1141 45 II 101 II14 iA~i -0.1:'

1141 45 II 101 II16 IAV3 1-0.071 R14 46 24 14 AV6 0.09 14 47 43 19 AV310.01 1141 47 II 48 II14 lAV6 1-0.281 1141 47 II 48 II33 IAV411-0.49 1141 47 II 48 29 IIAV2 I 0.05 1141 47 II 48 II18 IAVliI 0.16 1413847 48 AV 0.16 114 47 48 35 AV5 -0.08 F14] 47 57 17 AV3-0.02 F14 47 57 15 AV2 0.02 14 47 81 40 AV310.31 1141 47 II 81 II21 IAV411-0.241 1141 47 II 81 II17 IAV311-0.2) 1141 47 II 81 II37 IIAV4 II0.291 1141 47 II 81 II40 IAV3 II0.24l 1141 47 II 81 II35 IIAV6 II0.01 1141 47 II 81 II29 IAV5110.011 1141 47 II 81 II36 IAV2110.011 14 47 81 20 IAVi0.01 1141 47 I[ 83 II11 IIAV2 II0.01 1141 47 II 83 II 5IAV2 II0.021 F14 47 83 17 IAV20.01 F14 47 83 32 AV41-0.07 1141 47 II 83 II27 IAVl -0*.021 1141 47 II 83 II37 [AV3 -0.03 1141 47 II 83 II19 IAV6 .11-1141 47 II 83 II38 IAV5 0.1-1141 47 II 83 1I7 IAV2110.01 F14] 47 88 10 AV4 1 52

SG RWOLM %LOCATIO F14 48 26 18 AV2 -0 14 49 95 13 AV3 0.0 14 50 28 19 AV50.

1141 50 II 28 29 IAV610.12 F14] 50 94 18 AV3 -0.0 F14 50 95 11 AV2 -0.03 1141 51 II 31 II13 IIAV4 1-0.05 1141 51 II 31 II14 IIAV6 1-0.25 1141 51 II 31 LIJ9IAV5 1-0.19 F14 52 35 27 Ar3ZI Z F14 53 38 17 AV41-0.13 1413 53 20 AV61-0.35 1141 54 II 86 II17 IAV211-0.15 1141 54 II 87 II13 IIAV6 II0.01 14 54 87 17 AV5 0.01

[14[ 55 l[ 83 ((27 IAV6[ 0.02l F14 55 83 12 Av4LI Z F14 55 83 10 Av2Zl Z 114l 56 II 41 [I27 iaV6110.05 1141 56 II 41 II33 IIAV5 II0.03 14 56 41 20 IAV40.05 F14 56 81 12 AV210.21

[14[ 56 (( 82 ((14 ]AV2[ 0.09*

F14 58 50 AVl7=017 1141 58 I 65 II13 IAV61-0.2]

114l 58 I 70 II13 IAV1 II---

F14 58 Z7E10 AVI -0.

F14 58 74 13 AVl -0.1 F14 58 76 17 AV210.09 1l4l 59 II 55 II23 IAV6 0.22 14416359 11 AV2 F14] 59 63 11 AV6-141 59 68 15 AV -0.51 53

V NDE Techniques Utilized for IR15 54

"LI 11 DL~II

+Point 96703.1 Revision 10 Axial PWSCC Dent Single

+Point Frequency Yes 13 Phase Analysis 11 96511.2 Revision 10 11 55

Attachment 2 Salem Unit 2 Refueling Outage Number 12 Summary

J OVERVIEW The detailed ECT scope was delineated in the 2R12 Steam Generator Tubing Degradation Assessment, Engineering Eval. No. S-2-RC-MEE-1625. This document identified the active and potential degradation mechanisms affecting the tubing in the Salem Unit 2 Steam Generators, identified the inspection scope and techniques to be used, and provided structural limits for each damage mechanism for assessing tube integrity requirements. The base eddy current examination scope met Salem Unit 2 Technical Specification requirements. A summary of the base scope is shown below:

• With the exception of those low row u-bends inspected under the next bullet, a full-length bobbin coil inspection was performed on 100% of the in-service tubes in each steam generator.

• 100% Rotating Coil (+ Point) exam of the row 2 short radius U-bends and 20% of the row 3 short radius U-bends (07C-07H) in each steam generator.

• 100% Rotating Coil (+ Point) exam of the Hot Leg (HL) WEXTEX Top of Tubesheet (TTS) transition regions in each steam generator.

• 100% Rotating Coil (+ Point) exam of the >1-volt dented HL Tube Support Plate (TSP) intersections at 01H and 02H AND 20% of the >1-volt dented HL Tube Support Plate (TSP) intersections at 03H in each steam generator.

& 20% Rotating Coil (+ Point) exam of the >5-volt dented HL TSP population at 05H, 06H and 07H in each steam generator.

• 20%Rotating Coil (+ Point) exam of the >2 volt HL free span dings (TSH +0.5" to 07H

+2.0").

• Rotating Coil (+ Point) examination of previous and new suspect Ligament Indications identified from the 2R1 1 bobbin coil data.

EPRI Rev. 5 Technical Deviations Rev. 5 of the EPRI PWR Steam Generator Examination Guidelines allows utilities to deviate from specific requirements through a documented technical justification for each deviation.

Seven technical deviations were implemented for 2R12. Justification for each deviation is documented in the confirmation for each order listed. All deviations were reviewed and approved in accordance with station procedures. A summary of the deviations is provided below:

• 80041193, deviates from the normalization requirements specified in Rev. 5 to provide for more consistent sizing technique for Anti-Vibration Bar (AVB) wear indications.

• 80041192, deviates from the minimum required EDM notches in the rotating coil calibration standard.

• 80041189, deviates from the voltage normalization requirements specified in Rev 5 for bobbin examinations. Voltage normalization will be based on the transfer values obtained from comparisons to the Westinghouse Mother Standard rather than those specified in Rev. 5.

1

• 8

• 80041191, deviates from requiring all data analysts to pass the Site Specific Performance Demonstration (SSPD).

• 80041190, deviates from requiring production data analysts to review overcalls.

• 80041474, deviates from the process control requirements (e.g. 3 letter codes) delineated in Rev. 5.

• 80041194 deviated from the volumetric inspection requirements for installed FANP Inconnel-690 rolled plugs.

Assessment of Examination Results and Technical Specification Classification Consistent with the requirements specified in NEI 97-06, Steam Generator Program Guidelines, the Unit 2 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 Management Program for 2R12. A complete assessment of the examination results is documented in S-2-RC-MEE-1673, 2R12 Steam Generator Condition Monitoring & Operational Assessment Evaluation. 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 Degdation IG21 SG22 SG23 SG24 TOTA PWSCC @ L TTS (Axial 11 [21] 4* II ] 21 PWSCC @HL TTS (Circ) II o II IILo IIj oII 111 PWSCC HL TTS (olumetric II10 IjIj0I1IIL0III r ODSCC HL rTS Volumetric [I 0 I0 20 EZ0 IIZ2 Anti-Vibration Bar Wear I ][1I0 Z ii1I0 III2 Cold Leg Thinning ]I 0 III2 jjI4IIj66IIj0 PWSCC @HL TSP Axiall i ZLI1 II o IIl1 LII PWSCC @HL TSP (Circ) ][J l]1II0 II III1 ODSCC @HL TSP (Axial) III1 Ii0 IZI3I]LII]0 I PWSCC LOW ROW U-BENDS II]o II]o IZLoZII o Io Loose Part Wear/ Preventative [IIo [II o I II o II 2 I IIIo Unacceptable Data QualityPVN) 1 II0I] 0II l III0II IZLZII]I II]LII II I IZIZIZIZ ZII I TOTAL TUBES PLUGGED 14 E2Z 10 L9Z 41 TOTAL TUBES PLUGGED 2117224 171 0 912 CUMULATIVE I CUMULATIVE TUBE PLUGGING 6.22 It7 ] 5 ]L 3 LI3

• This tube had two indications reported in the HL tubesheet region 2

The categorization of each steam generator is listed in the table below and takes into consideration both the bobbin coil and RPC inspection results.

21S 22G2SG 24 SG Technical Specification F-2 LC-2 -2 Category WEXTEX Tubesheet Inspections The WEXTEX transition is the region of the tube where the tube transitions from the expanded tube diameter to the nominal tube diameter and is typically located near the top of the tubesheet. The bottom of the WEXTEX transition is the first point of contact between the tube and the tubesheet. In this region, both PWSCC and ODSCC have been observed with PWSCC being the prominent damage mechanism at Salem Unit 2.

During 2R12, 100% rotating coil (+ Point) inspections of the HL TTS WEXTEX transition region were performed in each steam generator at an extent of +2" above TTS to - 8" below the TTS. The table below lists all tubesheet indications repaired during 2R12. All indications were sized for tube integrity assessment.

STube Damage ID Indication I Location MeDamage SG]

21 g2Ca4 I SAIj ITSH -1.61" E7 PWSCC 21 ] R5C29 SAI II TSH - 1.59" 1= PWSCC 21 R5C57 EIi SAI-I1 TSH - 7.76" II PwscC 21 IR5C64 I s II TSH -2.50" PwsCC 21I R5C73 II sAII TSH - 9.29" pwscc 21 R9C63 I TSH -7.45" PWSCC 21 R12C38 jIIS II TSH - 1.70" PWSCC 21 R19C49 II SIZII TSH- 2.37" IF PWsCC 21I R22C31 SIjjs7jII TSH - 1.46" I PWSCC 21 R23C32 SAI IITSH - 0.95" I 'WSCC 21 R25C23l SAI IiTSH -6.55" II PWSCC 2 R54A I[ TSH - 1.42" PWSCC SAII(( TSH -1.00 22] RC67 SI (( TSH -6.71" IF Pwscc 22 ]R13C28 SCI 11 TSH -2.16" II PWSCC 3

LII sll TSH-2.88" 22 R29C63 [ SAI TSH -1.40" PWSCC S SAII TSH -1.07"

- _SAI (( TSH - 0.91" 12211 R32C45 J SL II TSH -0.91" ]I PWSCC 23 17C91 JI SAI I TSH -2.43" ' pwscc 123]1 R19C26 II S I TSH -0.45" II ODSCC

_23_ IIR22C31 SVI II TSH -4.18" !I PWSCC 23 11 R31C24 iSI I[ TSH -0.74" I] ODSCC 11I SAi TSH -11.18" PWSCC I 23 IR38C611 SM I TSH -2.20" PWSCC 23I R42C38 I S7 TSH -0.48" I7 Pwscc 1241] R9C51 SAIII TSH -0.31" II PWSCC 24][ R20C49 SA TSH -7.13" II PWSCC Dented IEL TSP Intersection Inspections About 3160 > 1 volt dented TSP's intersections were inspected as part of the base scope and 186 new dents2 were examined with a rotating coil technique. Six tubes were repaired for dented TSP ODSCC or PWSCC indications (see table below). All indications were sized for tube integrity assessment.

Tube TSP 2R12 Bobbin Damage SG ID Indication Locationj Dent Voltage Mechanism 21 R6C9 SI 01H -]1.68 Ir ODSCC 21 R24C10 s I 01H 71 1.67 IF ODSCC 22 SM 01H 0R261 1.56 PWSCC 22 R27c23 SCI 01H 4.08 PWSCC 23 R10C92 OIH1S 5.15 ODSCC IIR6C71 24 SAMI I 01H II 1.31 1I PWSCC Anti-vibration Bar (AVB) Wear During previous ISI's AVB wear was detected and sized utilizing an absolute mix per EPRI ETSS 96004.3. In an effort to obtain greater consistency in the sizing of AVB indications, for 2R12 the differential mix technique per EPRI ETSS 96004.1 was site 2New dents are > 1 volt indications that were reported during the 2R12 bobbin coil inspection at 01H, 02H and 03H that were NOT inspected during 2RI 1.

4

validated and used. This required historical indications to be re-sized per technique 96004.1. This work was completed prior to 2R12 by Framatome ANP personnel and is documented in VTD 325511, AVB Resizing Bobbin Differential Depth Sizing of AVB Wear at Salem Unit 2. Changing techniques for identifying and reporting AVB wear did not result in an inspection transient.

AVB wear indications are plugged if bobbin indicates a depth > 40% through wall (TW).

Tubes with degradation less than 40% through wall may be left in service or removed from service depending on the observed growth rate of the degradation. A total of two tubes were plugged for this damage mechanism. The table below lists the tubes plugged for AVB wear during 2R12:

- Tub~e SG] Tu Indication Location 21I R7c52 40% AV3 23 I 0C631 43% AV2 Cold Leg Thinning (CLT)

Cold leg thinning (CLT) is caused by surface wastage (corrosion) and occurs principally within the confines of the lower cold leg tube support plates on the periphery of the tube bundle. CLT indications are plugged if bobbin indicates a depth of > 40% through wall.

Tubes with degradation less than 40% through wall may be left in service or removed from service depending on the observed growth rate of the degradation. A total of six tubes were repaired for this damage mechanism as shown in the table below.

[SG [ ue ID 11 Indication TSP Location 23 1R2SC0 44% O0C 23 R33C17 41% l0IC F-24 R31C77 40% 01C I F-24 R34C78 45% OlC I I 24 R35c78I 45% olC

[24 R43C60 37% I1 02C Inspection of Small Radius Row 2 and Row 3 U-bends 100% of the Row 2 and 20% of the Row 3 U-bends in each steam generator were inspected with a dual coil + Point probe. The probe contained both mid frequency and high frequency coils spaced 18" apart. No indications were reported during this inspection.

5

Loose Parts All bobbin and rotating coil data was analyzed for the presence of loose parts. The following tubes were identified as having possible foreign material on the secondary side of the steam generator.

SG Tube ID 1 Indication Lon F-21 R19C61I PLP TSH

[ 21 R30C66 PLP TSH I 22 R12C69 PLP TSH 22 R22C32 PLP II s

[ 22 R23C28 PLP T

[ 22 R30C23 PLP TSH S22 t]R31C22 II PLP IITSH I24 R28C55 PLP TSH F 24 R34C61 PLP TSH I24 R34C62 PLP TSH No tube wear was reported; therefore, 1AW with the following Framatome ANP Condition Reports these locations did not require repair.

m Framatome ANP I SG s Condition Report 1 PSEG Notification 121 l 6014762-00 71 20097108

[22 II 6014714-00 7[ 20097109

[24 II 6014764-00 71 20097345 Two tubes in 24SGR3C93 and R9C93, exhibited indications of loose part wear above the HL TTS during 2R7. Secondary side inspections were performed during that outage that confirmed the presence of the loose part that was subsequently removed. These tubes have remained in service since 2R7. Since 2R9 these indications have been sized with + Point technique. A special AVB wear scar standard was used for calibration purposes. The maximum through wall depth of these indications was sized at 21%. These tubes were conservatively removed from service (preventative) during 2R12.

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 6

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. One tube in 22 SG, Row 22 Column 8 was repaired due to Permeability Variation @ 05H+5.12.

Freespan Indications Manufacturer's Burnish Marks (MBM's) and Freespan Differential Signals (FSD)

MBM's are identified during the bobbin coil examination. All freespan indications indicative of an MBM type signal were compared to history data to identify any significant changes in the signal characteristics. Indications not exhibiting change based on the parameters of the freespan flow chart were left in the eddy current database with a "MBH", "MBS" or MBM code. Signal changes meeting the parameters of the freespan flow chart were identified with an "MBI" code that require supplemental +Point examination for characterization. No supplemental +Point inspections were required.

As compared to the MBM signal, freespan differential signals exhibit sharper signal characteristics, which could be indicative of damage mechanisms such as IGA/SCC or pitting. These signals are also identified during the bobbin coil examinations. FSD signals are compared to the historical data to detect change in phase and voltage. If no change was noted, the indication was left in the database as with an "FSH" or "FSS" code. Signal changes meeting the parameters of the freespan flow chart were identified with an "FSF' code that required supplemental +Point examination for characterization. Seven tubes (8 locations) were identified with "FS!" codes and none of these indications confirmed to be crack-like when examined with the +Point probe. These locations are shown below:

]Tube ID Bobbin Coil Analysis Code Location + Point Analysis Code R9C88 L FSI I TSC +35.86" MBM I FSI TSC +22.88" MBM 21 R40C53 FS! I 07H +23.77" MBM 22 R25C43 FS! TSC +24.29"-ND F24] R5C13 ES TSH+41.38" NDF 24 R7C17 FSI [ TSH +48.99" NDF 24 R9C20 FS! 01C +14.58" NDF 24 R43C43 ES! 02H +1.13" NDF 7

4 4 Tube Support Plate Integrity Inspections All bobbin coil and TSP rotating coil data was analyzed for Suspect Ligament Cracking (SLC) in accordance with the station's eddy current data analysis guidelines and ETSS.

The acceptance criteria for SLC indications are that missing ligaments measured less than the 145-degrees are not required to be repaired.

Eleven new bobbin SLC's were detected during the outage, 10 at HL TSP's and 1 at a CL TSP. Of the 11 new indications detected, only 1 could be traced back to 2R1 by doing a bobbin coil comparison. Based on historical looks, all HL TSP SLC's were judged to be present in the 2R9 (1996) rotating coil data. Historical data for the CL TSP indication was not available. The maximum extent of missing ligament for the "new indications" was 31 degrees. The remaining 10 locations were single indications (no measurable gap).

The table below provides a cumulative listing of all SLC indications:

SIZING SO AIOG SG ROW COL CHN IND LOCATION INFORMATION.

21 20 53 7 SLC 05H +0.18 SINGLE 21 31 79 7 SLC 06H +0.21 SINGLE 21 35 54 7 SLC 03H +0.18 SINGLE 21 36 40 7 SLC 06H -0.06 SINGLE 21 37 40 7 SLC 06H +0.13 SINGLE 21 37 40 7 SLC 05H +0.22 SINGLE 21 42 34 7 SLC 06H -0.30 SINGLE 21 42 36 7 SLC 06H -0.25 SINGLE 21 43 40 7 SLC 06H +0.03 SINGLE 21 45 41 7 SLC 06H +0.00 DOUBLE 22 37 54 7 SLC 03H +0.01 SINGLE 22 37 54 7 SLC 03H +0.03 SINGLE 22 41 54 7 SLC 03H -0.22 SINGLE 23 3 56 7 SLC 06C +0.00 46 DEG 23 6 27 9 SLC 04H -0.12 46DEG 23 9 40 7 SLC 06C -0.22 47 DEG 23 9 55 9 SLC 02H -0.02 51DEG 23 9 55 9 SLC 03H -0.10 82DEG 23 14 37 9 SLC 04H +0.26 37DEG 23 14 38 9 SLC 04H +0.04 54DEG 23 14 57 7 SLC 05C +0.00 61 DEG 23 17 27 9 SLC 04H -0.01 64DEG 23 22 75 7 SLC 0111 -0.00 51DEG 23 22 75 7 SLC 07H -0.10 11IDEG 23 25 87 7 SLC 07C -0.04 SINGLE 23 29 81 7 SLC 01C +0.01 40 DEG 23 29 81 7 SLC 07C -0.00 71 DEG 8

23 39 56 7 SLC 07H -0.22 SINGLE 23 42 59 7 SLC 04H +0.13 SINGLE 23 45 54 7 SLC 07H +0.18 SINGLE 23 46 54 7 SLC 07H +0.21 SINGLE 24 20 29 7 SLC 07C +0.32 SINGLE 24 26 9 7 SLC 05C +0.01 31DEG 24 34 46 7 SLC 02C +0.01 SINGLE 24 41 39 7 SLC 02C +0.09 SINGLE 24 45 41 7 SLC 07H -0.00 SINGLE 24 45 57 7 SLC O1H +0.19 32DEG 24 46 41 7 SLC 01H +0.03 29DEG 24 46 41 7 SLC 07H -0.03 SINGLE 24 46 54 7 SLC 07H +0.24 DOUBLE Free Span Ding Inspections

+ Point inspections were performed on a 20% sample of the HL >2-volt free span dings in each steam generator to identify potential PWSCC and/or ODSCC. The 20% sample of free span dings was inspected up to the 7th HL TSP (TSH +0.5" to 07H +2.0"). About 63 dings were inspected as part of the base scope and 63 new dings 3 were examined. No anomalies were noted.

Sludge Mapping The station performed sludge mapping utilizing a Computerized Data Screening (CDS) sort of the low frequency bobbin coil data. Sludge analysis provides the information necessary for assessing the positive inspection height for HL TTS rotating coil inspections.

For 2R12, the results of the HL sludge screening show the average sludge height per SG to be < 2 inches. Seven tubes in 23 SG had sludge reported in excess of the +2 inch planned extent for the HL rotating coil inspections. The 2R12 rotating coil data for these tubes was reviewed and found to bound the maximum height of the sludge reported. The table below summarizes the sludge analysis results.

SG 21 22 23 24 Count 181 179 160 127 Max II 1.56" I1.44" 2.53 1.46" Min 0.37" 0.15" 0.0 0.42" Average 0.73" 0.72" 1 0.86 951h 1.27" 1.12" 1.3 1.25" 3New dings are > 2 volts indications that were reported during the 2R12 bobbin coil inspection from TSH +0.5' to 07H +2.0" that were NOT inspected during 2RI 1.

9

ts

• P Percentile III II II .1111 IiJ Tube Plug Inspections During 2R12 station SG engineering performed a remote visual inspection of installed steam generator tube plugs to identify any abnormalities that may require further actions. Plugs were visually examined for signs of leakage such as boron rings or moisture in accordance with station procedure SC.SG-TI.RCE-0002 (Q), STEAM GENERATOR TUBE PLUG VISUAL EXAMINATION. The following anomalies were noted during the inspection:

10

t

• r, Framatome PSEG Nuclear ANP Notification SG Anomaly Condition Number Disposition Report Number R1C77 - Wet PIP with no significant boron deposits No action 211110172.0905 eqie required R1C24 - Wet PIP with small amount of boron deposits

[R1C31 -Wet PIP with small 22 L [amount of boron deposits J 6014733 0[7 1 2 20097039 No action required 23 HL R1C65 - Wet PIP (recessed) No action significant amount of 6014734 20097037 required boronnodeposits with RIC13 - PIP with small amount of boron deposits No action R1C65 - Wet PIP with small required amount of boron deposits Technical Deviation 80041194 provided the justification for not performing a 20% volumetric (eddy current) inspection of installed FT1 690 rolled plugs.

Repair Techniques and Equipment All repairs were performed utilizing the Framatome ANP mechanical rolled plugs (material master 5006402). The plugs were installed in accordance with the stations work control process utilizing the ROGER fixtures and associated remote plugging equipment.

Two cable stabilizers (material master 5006264) were installed in locations with circumferential indications (see table below):

SG I LOCATION INDICATION LOCATION 2271 RI3C2] SCI d [ TSH -2.16"

[22][ R27C23 SCI __ OlH +0.12" 11

4 &

4 FINAL ECT SCOPE The table below summarizes the final (base scope + special interest and/or expansions) scope performed during 2R12.

F171Exams IF #of IF Exaso Ciei Expansion Criteria

- Area [ Inspection Criteria Full Length 100% of all in-service 1 (Tube end to tube Bobbin tubes in each steam 12264 N/A end) generator in-service of all20%

100%2 and Detection of degradation may Short Radius S U-Bhnds +PointTM Row 3 2 and Row 20% of Row 420 require and verification, expansion of C-Aredefinition, and Buffer (07H to 07C) geneator EPRI zones perRev PWR Examination 5 guidelines.

generator 100% of all in-service tubes in the HL in each Detection of degradation may

+Pointm steam generator require verification, redefinition, 3 WEXTEX 177S 12684 and expansion of C-A and Buffer Extent is +2" above zones per EPRI PWR Examination TTS and -8" below Rev 5 guidelines.

ITIS Tubesheet Inspect all 2R1 I history All new expansion anomalies Will Anomalies +PointTm expansion anomalies in 72 be inspected with +Point in the area Anomaliesof interest of interest.

Defined scope from Degradation 1000/ of the > 1 volt Assessment of dented TSP locations at Detection of degradation may PWSCC +PointTm 01H and 02H, 20% 3344 require verification, redefinition, for sample of 03H in each expansion of C-A and Buffer Dented TSP SG. zones per EPRI PWR Examination Intersections Rev 5 guidelines.

Defined scope from Degradation Assessment of 2Critical area (C-A) will need to be ODSCC +Pointm 20% of the >5 volt defined after detection of ODSCC for dented TSPH locations at 930 at TSP dented location. Expansion Dented TSP will be based on the C-A.

Intersections HSV)

Suspected TSP Bobbin and 100% of all previously Any new PSI will be +Point Ligament Cracking identified bobbin PSIs / 39 i e (PSI or SLC) +Point SLC inet ....

206 iIf PWSCC or ODSCC isdetected 1812Free Span Bobb in 20% inspection of the in 20% sample, evaluate the need SIndications (Dings) +Point >2 volt L dings in 126expand AW EPRI PWR di t)each SG Examination Rev 5 guidelines.

Visual inspection of Plugs Visual 100% of the installed 1742 N/A tube plugs in each steam generator.

12

2R12 Location and Percent Through Wall Indications ROW ]F LOCATO 21 LjfJj~Ij~jf AV4 05

[21 F1 Li25AV4, -0.38 KILLEDAV3 F2,157I 3]97 ELI AV2 -0.841 21 E~Z~Z LI~~AV3-00

[21M 5-23Zf~f A] 1.01

-7 EF-iiL-iF-II1 fAV2 -0.261 F2-1]FI F211F1 I30ll1L-Ij AV3 --0.818

[2JWII5W EZZZ LJZLDIF Z 132

s[ROW COLUMN I LOCATION 21] 9 IL 66[13 JAVI -0.44 F21] 1 II 66 IIJ6 AV4 -0.02 AV3 P21 1+0.04 AV3 R21 +0.33 1211 21 IIJAWII AV4 -0.53 21fl III60liI12 AV3 -0.44 21] 2 IIL6 I AV2 -0.27 211 [II6 II1 L60 [AV2 -0.33 AV3

[21] 2+0.19 21] 23L 67]jI AV3 -0.17 21 2 67 2AV2 -0.25 21 2 AVI -1.01 21fl 3 6 If AV4 -0.23 AV3

[212 8 2 +0.00

[211 [3 II 68 II AV2 -0.44 AV4 21 2 7+1.26 21] 24J Jf4AVI -1.64 AV2 P21 2+1.25 AV3 n21 4 5 +1.20 AV4

[ 242 2 +0.52 21 2 7 II 19] AV2 -0.27 AV2 F21 24 6 7 +0.81 AV3 F21 24 6 6 +0.13 AV1 F2 1]2 7 +0.40 AV2 WIZEZ4 1 +0.30 14

sGROW ILOCATION F21] 26I 6II I 0 AV4 -0.681 AV3

[2 WL I 2 +0.11 AV2 P21 26:165] +0.02 AV1 P21 26 5 6 +0.26 1211 26 LIII58 LPI1 [Ag2 -0.48]

21I26 Ij 58I J AV3 -0.72 21 26 AV4 -0.44 AV3 F21 26 5 3 +0.36

[21]2 F21] 26 1 -9 0.5 F211 26 63 II1AV4 -0.59 AV2 21 26 64 1 1 +0.11 AV3 R21 26 6 2 +0.20 211 26 I 67 I 231AV1 -0.75 AV2 F2112 4 3 +0.00 AV3 21 27 4 31 +0.00 AV4 21 27 4 24 +0.78 FE I271(( 4 [1 AV1 -0.5 AV4 F21 27 4 2 +0.11 AV3

[212 6 3 +0.69 F121]1 27J4 5]AV4 -0.37.

2111 27 fII4 II J AV2 -0.22 AV2 F21]2 6 3 +0.33

[2111271[ 47 IL 2__ AV2? -04 15

SGROW COLUMN ITw LOCATION 12111 27 47 II 3 AV3 -0.81 1211 2f7l 4 JAV4 -1.40 AV4 F21]2 2 2 +0.54 AV3 P21 27 5 0 +1.41 21 7flE 2II5III14AV3 -0.95 AV2 P21 27 5 0 +1.35 F21] IAV2 -0.99 12111 2f7l1 L51[1 [AVI -1.74 AV3

[212 6 2 +0.06 AV2 P21 27 5 4 +0.06 AV1 P21 27 5 3 +0.27 AV4 F21 27 5 6 +0.00 F2-111 9 I 5 J7I

[Ag4 -0.-33]

AV1 R12 421 +0.00 AV2 P21 27 6 6 +0.08 AV3 P21 27 6 3 +0.17 F21]II2 I 46 I 5[Ag1 -0.-44]

AV21 P21 29 4 3 +0.37 AV31

[212 6 3 +0.37 F2-111 2JI6 I1 AW4 -0.151 F21] I57I9[AV4 JI2 -0.041 AV3 P21 29 5 0 +0.001 AV2 P21 29 5 7 +0.08

!21II29 I 5 I 2 [Ag4 -0.401 16

2 AV r12 65 5101 +0.50 AV2

[213164 2 +0.00 AV2

[213167 1 +0.48 AV4

[213 9 1 +0.02 AV3 n212 48 2 +0.27 AV2

[213 8 1 +0.09

]21] O 4A -0.20L AV3

[213 1 1 +1.71 AV3 n21 32 5 2 .35 F21fl 3=2 II5 [ 3AV3 -1.270 AV2

[213 1 1 +1.35 AV3 n21 2 54 +0.00 AV2 n213 41 1 +0.00 F2111 33I 1 I1 AV3 -0.177 AV4 F2113 1 1 +0.080 AV3 F21]3 0 2 +0.44 AV1 F21]3 0 2 +0.521 N1[3I 36 115 [AV3 -0.2 1 21i [I3 I 36 I 8iAV2 -0.477 i211i 34IF 36 I 2 [ V 17

[s]GR LLOCATION IR FI I I I1I+0.34 F21] 3, 6 I 1AVI -0.26 AV4

[21] 34E3IE +0.17 AV3

[21 1L 1 +0.28 AV2

[2IJ3i 3EZ] +0.15 AVI F21] 3+0.28 AVI F21 3 4+0.45 21 [3l 4 I j AV2 -0.02 AV3 F21]3 4 3 +0.11 AVI F21 34+0.17 211[ 3 L[ 16AV2 -0.04 21 JAV4 -0.17 21 L1 4 I 29AV3 -0.50 AV3 P21 3+1.28

[213 4 10 +0.00 AV3

[21 3 5+1.24 AV2 213 51 Z+1.28 AV1 21 3AV42-+0.00 AV2

[213 2 1 +1.03 1211 34L6i 2 AV3 -0.29 F21 J3i6l AV2 -0.295 F21]1 3F Jj68AVI -0.481 1211 F35 I 76fI I 02c -0.101i 18

sc ROW ICOLUMNITWLOCATION 21F AV3 6 41 2 +0.00 AV3

[213 3 1 +0.77 E21] 36 L 752_ 3=0 1IAV2 -0.71 AV2 R21 36 5 4 +0.00 f21 LII3 II75i 19AV3 -0.42 AV2 F2] 6 15 +0.52 F21fl 7I5 I8 AV2 -0.46 AVi1 21 3 +0.31 AV2 21 40 37 E 28 +0.00 AV3 21 39 37 1C +0.33 F2-1]1 39J 4 ] 0 AVl -0.177 E2 3 ZEZ6IZ I -0.59 2211 39 II61 I31 AV2 -0.48 F2-1] 4 1 5 11 0 [JAg2 -0.3-1 22 E I 31 I111 AV3 -0.02 F21 6iI 4 I 101oC +0.378 AV2 22 1668 19 +0.28 AV3

[22 16 8 1 +0.18 F22]1 18J 5I 3)AVI -0.975 F22]1 18I 5I 7AV2 -0.670 AV2

[22 18 5 2 +0.82 AV3 n22 18 6 9 +0.09 221 1 j 65JII AV4 -0.80 221 8III65ZL 1h AV4 19

I ZAV 11 ZZjj Z9 9z I zz 179'0+ 8z IAV 11 1 rl 00*0+ 91 cz 9z zz EAV 11 1 rl LVO+ IL z zz EAV 91'0+ 69 EAV 00*0+ 69 z zz ZAV VE EAVI Fqz OL*I+

TAV 11 9Z*O+ zz EAV 5Z OE -- ýZlm zo-o- z Fz-zl 00*0+ 6 9z zz EAV =MM 6E*O+ 5z zz ZAV 00,0+

VAV 89*0+ ft z zz ZAV 6Z-O+ zz VAV -9111 i7E*O+ zz EAV 00*0+ IL IAV 111,0+ D zz zz 00'0+ zz Z9 CAV IM rl 190 ZAVI zz zz 89*1+ t1l 59 IAV 68'0+ F-1

SGROW O LOCATION F 1 +0.13 F22] 26_ 6 2J_ AV3 -0.17

[221 +0.49 F22] 27 15AV2 J -0.11 AV3

[22 P22 2

31 SI 2+0.28 2

II 0 I[ AV2

+0.00

[2231 EJEIJ~iEI]AVI II IIAV2 +0.74 SI

[223128 2 +0.29 F22 3 Jj AV3 -0.19 22 7 IL__ 102C -0.04 F22ý 32 7 L_103C -0.15 2-2J 103C +0.00 P22 EJEILJEI]AV2 +0.00 22] 30_III76 J 1C -0.24 F2-2][ 33c I[ 7 [2 -0.09i 22 3 32 7j +0.00 F22]3 2 2 +0.00 F22]3 2 2 +0.00 22 34 39 AV +0.00

[2213 1 1 +0.00 P22 34 4 2 +0.00 F22]* 13 1 I[_-0.71 JAW AV3 n22 3 5 12 +0.00 I [1 [ I1 AV3 225 27 +0.28 21

Row I[jOL 1iNI% OCATION P22 34 50 20] LAV4

+0t.91 AV2 F22]3 0 1 +0.001 AV2 F22]3 5 +0.02 AVI

[2213 6 1 +0.11 AV2 P22 3 26 9 +0.07 AV2 F22]3 3 1 +0.07 22] 35 IIZ II AV3 -0.11 AV3 F2213 4 2 +0.00 221 3l IIIIZ 0C -0.04 AV4 F22]4 6 2 +0.00 AV2 F22]4 7 2 +0.00 AV1 F2]2 40 3 5 +0.00 AV2 F22]4 4 3 +0.00 AVI F2]2 40 4 1 +0.00 F2-2]1 40I 2 I 3 AV1 -0.09]

F2-21 40I 2 I 7[AV2 -0.o F2211 0II 6 II2 1102C +0.1-7 AV3 P22 41 3 2 +0.00 F2-2][4 I6 2 1[02C +0.173 F22(( 2 [ 1 I 19[02C +0.001 F2-21 I 61 I I02C -0.09 14 F22114 I 2 I 1 0I2C -0.0o4]

F2-2]1 42II 65 I1 I0c +0.3 22 II43 II 37 I125 II 2q__-0.09 22

ROW %TW LOCATION 22 43 [51 15 020 +0.04 22 4 6 27 102C -0.07 2-2 43 2II -0.11 02c F2]2]6 43 13 02C +.o07 F22]43 6 25020 +0.11 22] 44 10 02C -0.13 2-2] 44 [I 38 17 OIC +0.04 F-221 44 3I 28 1C +0.17 22] 44 20 02C +0.15 22] 44102C +0.211 22] 44 5 II 102C +0.11 F22 44 102C -0.17 F22] 44 II I [1102C -0.09 22] 44 9 I 102C -0.11 22]44 102C +0.071 2F2 ] 44 ]Lj 040 +0.17

[22] 44 62[ -030 -0.21 F22] 45 402 +0.18 F22- 45 T20

+0.22 22 45 - 102C +0.15 F2245] 55 1-2I1020 +0.112 2F2 451 i 16jf 02C +0.15 22** 5 II*]olc +0.15 F224] [1-]- 02C +0.04 2241 [1j51 j-*o02C +0.13 22* - 2 102C +0.17 2-2-] I 102C -0.11 1IIL F2**] [4 jI 01c +0.15

-23l 3 II 01c +0.23 2-3 - 3 JI I10c +0.06 23 -] 2Fjjf O110C +0.23 F2-3ý Eoi-l3 Z 0oc +0.15 F231 [FJ2I 10 C +0.04 23ý ]II]2 01c 3[IZE +0.07 23

[l]Ro~w CFOLUMNlLOCATION F231 16 ILZA4-0.811 23 -16F IF2--I AV3 -0.471 F2-3ý F16F 57f -- -1j4-AV2 -0.24 F2-31 20 Lýý -iLIJZAV4 -1.7:7]

23 20 L I6-7IIII13i-IIIAVI -0.:9]2 DEEIEEAV2 P23 F21 El2 ilij0A1i 0.07 F231 2-1 ~]L--aI7IAV2 -0.06]

LIEZZIZIEZI P2 [273 Ful 0 LIDEZEE DEJEZIJEZI I0+0;70

~JL~IJ~LJLAV 23 ~flZ8ZL1EAVi 02 EJEIJEIJEZI-6 0.0 24

SG 1ROW OILOCATION AVI P2324L 48J 12 +0.00 AV2 F23] W] +0.00Z AV3 P23 24 53 +0.06[

AV1

[2312 5 1 +0.981 AV4 F23]2 5 1 +0.02 23 24 I5 jfAV4 18 -1.64 AV3 23 24]56I 23 +0.77 AV2 F23]2 6 1 +1.15 F2-311 241 6 1 1 AV2 -1.-301 231 2 AV3 -0.81 23r 25 II 300C +0.13 F2-3112 [0C OII6 +0.301 AV2 23 25 44 10 +0.00 AV4 L23IZI +0.00 AV3 F23]2 4 2 +0.00 AV2 F23]2 4 2 +0.00 AV1 P23 26 4 2 +0.00 AV21 P23 26 4 9 +0.00 AV4 F23 26 4 4 +0.55 F2-31[ 26J 5 [ 2 AV3 -0.061 AV2

[2312 5 2 +0.55 1 23II2 5 J2zAV1 25

' I, SGlROW OITW LOCATION 23ý 27f 4 I AV3 -0.17 AV2 F23]2 1 3 +0.00

[232 5=1 33 +.0.....

23] 27 II1LII AV4 -0.33 23 27 1 IZ fI 2AVI -0.99 AV1 F23]2 9 2 +0.24

AV20

[231 27 5 7 +.22 AV3 F23]2 9 1 +0.351 AV2 F2]3 27 6 5 +0.15 AV3

[2312 3 2 +0.31 F23-1 3 [ J7I 8]AV4 -0.541 AV1 F23]2 3 2 +0.00 F23-1 27] 4 I1 Ag1 -0.74f F23-1 27J 4 I 0[AV2 -0.02]

AV4 P23 27 6 7 +0.96 AV3

[23]2 5 1 +0.28 F23ýII2 ] 65 I 3]Ag3 -0.281 F212 II2 I 65 I 3 AV2 -0.-071 F23[-281[ 0I 4loac +0.97o F2-311 28 5 I 7 ]Ag2 -0.151 F2351 29JO2II 5]0C +0.274 AV4 n23 30 3 6 +0.00 AV3 23 30 35 2L +0.00 26

S(( ROW C MLOCATION LLLI AV2

+0.00 AV2 F23]3 5 3 +0.75 AV3 R23 30 3 2 +0.00 23] IIL57 II AV2AV4-0.17

[2313 5 1 +1007 AV1 23 30 7 15 +0.02 AV3 23] 3

[2313 I 633 II 43 1 JAV4+0.251-0.76 F2311 30i 6 I7 [V +I0.761 231 L1 II 14I~I20II o1cAV4+0.09

[2313 231 IIZ153 1 II ole+0.00

+0.00 AV2

[233163 1 +0.00 AV3

[2313 1 3 +0.00 AV2 23 3241 15 +0.00 AVI 23 3245 28 +0.00 AV2 3 +0.48

[2313

[231 32 III455 IIIi9]AV4 -0.55 AV3 23 32 4=5 24 +0.48 27

sIROW COLUMNTILOCATION 23 JAV4 -0.55 AV3 F23]

AV2 23 32 4=5 39 +0.00

+0.00 AV1 23 32I 45 31 +0.00 AV3 L23 32 55 0.13 AV4 23 32 59 I17 +0.34 AV1 23 A4 +321-0.32 F2-3[ 33 I 17 4 1oc -0.02]

AV3 F23]W2 E0.00 AV2 23 33 6 21 0.00 AV1

[2313 2=6 12 0.00

_AV=1 F23] 33 5 1 0.00 F23113-]7 II2 i~C +0.00-q F2-3]1 3 1 J4[

Ag4 -0.1-11 AV3 F2]3 34 3 1 0.00 AV4

[231 34 5 1 0.00 AV4 r213 34 5 1 0.00 AV3 F23] 35 5 1 0.00 AV4 F2]3 35 5 2 0.00 AV4 F23] 35 5 1 0.00 AV4 23 3644 19 +0.00 28

WFRo-w-]ýýF/;T7W ILOCATION]

F2 -3]F-36-]F--4-5 -- ]F-13-ý FK-V3 -0.021 F2-3jF-376F--4-5--]F-I5-ýJAV4 -1.181 F2-3ý F-376F--4-5 -- ý F-10 JJAV4 -O.TOI

-ý F--1 F----] Fffý FA-v---o-151 23 36 58 F2-3]F367F--63 F21 AV2 -0*66, lo:]F -AV R23 F36 7 _ 1 +0.00 M7 JFIF6ý 4 23 37F 19 AV3

[2j 371F 42 D15 +010 IF AW

[21357IF42 18] +Oko AW

[2 31 F37 F 457 273 +0.00

[213F371F-45-1 Fl 4 +0.00 AW

[21357IF52 ] 371 +000 AW

[2 3] [ 378 F 477 174 +0.00 AV3

[2 31 F38 F-47-] Fl ý9 +010 F-48 -] F27ý AV

[2 31 F38

[-+AVI0.00 n23 [ 397 50 +0*00 AV2 P23591F 5o--15ý31 +000 F23IF391F751 [ 137 1 +0.44 F+AVI F2]3F39IF52--]F251 000 AV2

[213[ 39]F 752 [ 21 +O.OL-ý AV2 n23F39IF58 274 +0 .21 7AV_+O.oo 29

sG ROW ILOCATION

~ AV3 323L3 9 601 +0.00 123 J6III17iJAV4

-0.39

[J]L111L7][_AV2 AV2 F23]4 0 2 +0.17 AV3 23 0 51+0.00 AV2 F23] 4 1 2 +0.00 AV1 F23]4 1 2 +0.00 AV3 n34 423 +0.00 AV2 F231 4 4 3 +0.00 AV1 F231 4 4 3 +0.00 EJEZEZZI V-0.35 23 40 6 1 3

-0.0 AV1 AV2 F231 4 6 2 +10.00 AV3

[234152 2 +0.00 AV2

[234152 1 +0.00 AV21-0 23I 41 II 55 II 33 [AV1 -0.65 AV1

[23] 4 5 1 +0.59 AV2

_ _ _ _ _ 1+0.00 30

ISGI ROW OILOCATION AV2 341][ _3 +0.00 AVI

[2314 2 1 +0.00 23 42 [ 0 1[11 l AV3 -0.04 A-V2-23 26 24 +0.00 1 F2L3ý Z IIj66 7IAV2 -0.041 23 42 IZ166 II1 AV3 -0.094 42]= AV1 23 42 67 A3 +0.00 AV2 P23 2+0.02 F23] 42 [E 6=7 I AV3 -0.13 AV2 F23 43 6 9 +0.00 F23 II jI 3 3 JI 1C -0.07 F23 I4 3I 2 1C -0.13 F23[Z I Z4JF[4 AV4 -0.08 AV4 R23 45 5 9 +0.00 AV3 R23 4 58 9 +0.00 240 1Clc +0.14 F2-4-] 15I 3I0]Ay3 -0.271 24] 1 AV3 -0.40 AV2 24 1 +0.09 AV2

[24Z1I +0.00 AV2 F24] +0.37 AV4

[24 18 5 +0.59 AV3

+0.15 AV2 24 18 55 19 +0.18 31

s1ROW OIITW LOCATION F24 [ 557][j AVI -0.04 AVI P24 2+0.07

+0.00

[24112 [ 2 [1 2 AV3 -0.30 AV4 Q4 2I 2I 9L +0.40 F24] 2J AVI -0.14 EIIZJZIJLI]AV2

+0.63 241 21 30] 1AV3 -0.68 24 JAV4 -0.74 AV2

[2427 +0.17 AV3

[24 2 2+0.16 241 [3] 33 [j AVI -0.33 AV2

+0.21 AV3 R24 23 3 6 +0.00 241 23 I 5 If AV4 -0.15 AV4

+0.24 241 23 II 57IIZ13 lAV2 -0.43 24 2 AV3 -0.65 24] 23 ZII 5 If 3AV4 -0.17 AV1

[2412 7 1 +0.111 24E 23 AV4 -0.20 24[1 2l 57 I JAV3 -0.61 AV2 F24]23 I59 5 +0.28 AV3 32

[sjGlow iiOIITW LOCATION FI II [ +0.2Z47 24] 23 59 I[JLI4l AV3 -0.35 AV3 F24]2 9 2 +1.15 AV4 Q4 3+0.00 AV3 24244 62IiI 2L +0.00 AV2 224 4 20 +0.00 AV1 24 24 6 2 +0.03 AV4 24 23 7 0 +0.00 AV2 R24 23 7 2 +0.00 F24]1 JAV -0.76 F2-411 24 [ 3I 21 AV3 -0.077 F241 26 [ 3I [ 3AV2 -0.09 F2-4112 II 8 4[0C OII +0.1]3 AV1

[2412 4 1 +0.39 F2-4]1 26 4 I 6[Ag2 -0.3 AV3 24 26 34 [7 +0.00 AV4 24 26 3 19 +0.55 AV4 24 27 58 1 +1.28 AV3

[24]2 8 2 +0.33 AV2 F24]2 8 2 +0.50 F2-4]12 I5 I AV

[A1 -0.474 AV4

[2412 2 1 +0.85 12411 2 I 6 I I [AV2 -0.091 24[ ]D627 ][ 2 [AV2 -0.63 33

[SGRow [CLU]%TW ILOCATION 2] AVI 62L27E929 +0.00 241 27JII 68 II 18 AV4 -0.13 24[ 27 II6II 21 JAV3 -0.52 24] 28I O1C -0.13 AV2 P24 +0.24 24 29 O51C +0.02 F24 IOI1C -0.02 31 III 2Ioic -0.029 1241 30I F24] 31 I 6 IA 3 -. 2ý AV3 24 31 F24][3 I 7 48O1 I4 ll C+0.0202 F24]1 1 I 8 I2 lolc +0.11 F24] 32I 6 II AV2 -0.17 AV1

[2413 1 2 +0.07 AV4 F24]3 7 3 +0.00 F241 33 47ZII AV3 -o.64 AV2 F24]3 7 2 +0.C4 AV2 F24] 3+0.00 F2]4 33 4 3 +0.00 A4 AV4

[2413 0 1 +0.00 AV3

[2413 1 1 +0.00 AV2

[241 33IT M33L +0.00 34

SGROW ILOCATION F245 33 5 iIiil AVI -0.25 F24] 33 JAWII AV4 -0.22 AV3

[24i 3 57 2 +0.42 F24] 33 57 12 AV2 -0.24 241 33 16 AVI -0.02

[24 33 IýI58II21 [AV3 -0.43 F24 33 6 ]Z AV3 -0.91 24 33 6 AV3 -0.04

[24 33 24 AV2 -0.15 AV1 F24]3 7 2 +0.04 24 33 E78] 13 02C +0.15 24] 33 32I oc +0.06 241 34 I673II 18 AV3 -0.11 F24 34 6 19 AV2 -0.13 II AV4 24 63 +0.20 AV4 P24 34 6 6 +0.30 24[ 34 24]7834 II6 II 21 45

[AV3 -0.37 01C +0.09 241 35 45 oc +0.00 T8 24] 36 6 10 AV3 -0.07 24] 36 7Ij 7 1c -0.09 24] 37 III75LII o1c -0.06 24 38 3 20 AV3 -0.33 24 38 j39j 24 JAV4 -0.28 AV4 F24]3 2 2 +0.00 AV3

[2413 2 1 +0.00 24] 38 6 LI2 AV3 -0.30 24] 38 18 AV2 -0.07 A5 24 3868 24 +0.00 35

SSG ROW IjOLUMIj TW LOCATION 24 3 68 25 +.0 AV2 F24]3 8 3 +0.00 F24]4 AV3 F24]3 2 1 +0.19 Q4V JAV3-0.1 0 3 F2-4ý 6 W24] II F241 39V 1 -9 0.0 241 39 I65 213 AV2 -0.13 241 39 65 217 iol Al -0.24 244 39 7 21 +0.00 AV2 24 40[24V1 56 18 AV2 -0.18 F2-4] 40V -720.0

[244Z2 +0.00 24- 41 EII35] 24 [AVi -0.09 24 41 22 I35]

AV2AV1-0.05 AV4

[2414 7 1 +0.00 AV4 36

4 sG]ROW COLUMN %T4ljLOCATION I

I LZEIIZ]II +0.22 AV2 24 42 53I 11 +0.09 124114 I 55 II 38AViAV2-0.02 24 LI1 II~ LIi~iAVi-.2 24 42 [ 5 11 +0.00

[21E 2I 5 2 10o2C +0.021 F24 43 [134 II 03C +0.00 F241 43 III34 II 7j1o02C +0.11 F24ý 43 II135II 17]02C +0.16 1241 43 I1 35 I 04C +0.12 1241 43 L I1 h 1o02C +0.28 F241 43 19 02C +0.28 124 43 II II37 02C -0.06 124 43 6 10C +0.28 F24] I 35II 10 JAV2 -0.02 F241 4I 35II23E AVI -0.07 F24] II 58LiII1 102C -0.19 241 [] Z]59 3 102C +0.29 124 45 II]51 II 102C +0.15 AV1

[241 4 4 1 +0.00 F24] 45 II5 III 201lo1c -0.11 241 45 59 I 02C -0.22 37

.d I

NDE Techniques Utilized for 2R12 Depth Site-Specific Review Salem Industry Damage Demonstrated Extended Sizing Deemed Acceptable Technique Qualification Mechanism Applicability Applicability Technique Applied Detection Sizing r Differential Bobbin 96001.1 Above Mix For Revision 7 Thining TP Tubesheet Phase Yes Service Analysis PLP Wear (Sizing is Differential 2 Bobbin 96004.1 Wear TSP and AVB performed Mix Yes For Revision 7 with Phase Service techniques 11 Analysis and 12)

Differential 3 96005.2 Presence of mix CM/OA Bobbin Revision 6 Pitting Copper None Phase Purposes Analysis Differential 4 Bobbin 96007.1 IGA/ODSCC TSP Freespan, Mix Yes CM/OA Revision 8 Sludge Pile Phase Purposes Analysis

+Point ODSCC Single 2 PWSCC U-bend (Techniques Frequency CM/OA S96511.1/.

(MR Revision 10 Phase Purposes Probe) 9 and 10) Analysis

+Point ODSCC Single 6 (HF 99997.1 PWSCC U-bend (Techniques Frequency Yes CM/OA Revision 4 9Wand 10) Phase Purposes Probe)

_ _ _ _ _ __ d10Analysis Single 20510.1 Circ PWSCC Expansion Dent, Frequency Yes CPpOA 7

Revision 2 Transition Tubesheet Phase Purposes Analysis Single Circ PWSCC Expansion Dent, Frequency Yes CM/OA 2

96701.1 Revision 7 Transition Tubesheet Amplitude Purposes Analysis Single 20511.1 Axial Expansion Tubesheet Frequency Yes CM/OA

+Point Revision 2 PWSCC Transition Phase Purposes Analysis Single 8 +Point 96703.1 Axial Dent Tubesheet Frequency Yes CM/OA Revision 10 PWSCC Phase Purposes Analysis J~ 409.1 0 Axial TSP, Single Yes PupOA oubeseheet 1Revision ODSCC Freespan, L Expansion IFrequency 38

t 39