BW080110, Thirteenth Refueling Outage Steam Generator Tube Inspection Report

Thirteenth Refueling Outage Steam Generator Tube Inspection Report

ML083220444
Person / Time
Site:	Braidwood
Issue date:	11/11/2008
From:	Bryan Hanson Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
BW080110
Download: ML083220444 (147)

Text

xeIwn Exelon Generation Company, LLC Braidwood Station 35100 South Route 53, Suite 84 Braceville, IL 60407-9619 www.exeloncorp.com Nuclear November 11, 2008 BW0801 10 U.S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555-0001 Braidwood Station, Unit 2 Facility Operating License No. NPF 77 NRC Docket No. STN 50-457

Subject:

Braidwood Station, Unit 2 Thirteenth Refueling Outage Steam Generator Tube Inspection Report In accordance with Technical Specification 5.6.9, "Steam Generator (SG) Tube Inspection Report,"

Exelon Generation Company, LLC is reporting the results of the SG inspections, completed during the Braidwood Station, Unit 2 Thirteenth Refueling Outage (A2R1 3).

If there are any questions regarding this submittal, please contact Mr. David Gullott, Regulatory Assurance Manager, at (815) 417-2800.

Respectfully, 1/2 "15an Hanson Site Vice President Braidwood Station

Attachment:

Exelon Braidwood Station Unit 2 Thirteenth Refueling Outage Steam Generator Tube Inspection Report

ecc:

Illinois Emergency Management Agency - Division of Nuclear Safety Director, Licensing and Regulatory Affairs, West Manager, Licensing - Braidwood, Byron and LaSalle Stations Braidwood Nuclear Licensing Administrator Regulatory Assurance Manager - Braidwood Station M. F. Sears - Engineering Programs - Braidwood Station Exelon Document Control Desk Licensing (Electronic Copy)

Exelon Nuclear BRAIDWOOD STATION, UNIT 2 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: October 17, 1988 STEAM GENERATOR TUBE INSPECTION REPORT THIRTEENTH REFUELING OUTAGE (A2R13)

April 2008 Exelon Generation Company, LLC 200 Exelon Way Kennett Square, PA 19348 Mailing Address 4300 Winfield Road Warrenville, IL 60555 Document Completion Date: October 30, 2008

TABLE OF CONTENTS

1.0 INTRODUCTION

2.0

SUMMARY

3.0 CERTIFICATIONS 3.1 Procedures/Examinations/Equipment 3.2 Personnel 4,0 EXAMINATION TECHNIQUES AND EXAMINATION SCOPE 4.1 Examination Techniques 4.2 Steam Generator Inspection Scope 4.3 Recording of Examination Data 4.4 Witness and Verification of Examination 5.0 EXAMINATION RESULTS 5.1 Indications Found 5.2 Other Inspection Results 6.0 RESULTS OF CONDITION MONITORING 6.1 AVB Wear 6.2 Pre-heater Baffle / TSP Wear 6.3 Foreign Object Wear 6.4 Tubesheet Region Indications 6.5 Primary to Secondary Leakage Assessment 7.0 REPAIR

SUMMARY

8.0 DOCUMENTATION 9.0 FIGURES/TABLES/ATTACHMENTS

1.0 INTRODUCTION

Braidwood Station, Unit 2, operates with four Westinghouse Model D-5 recirculating steam generators (SGs) in the four loop pressurized water reactor system. Each SG contains 4,570 thermally treated Alloy-600 U-tubes that have a nominal outside diameter of 0.750 inches and a nominal thickness of 0.043 inches. The tubes are hydraulically expanded into the full depth of the tubesheet. The tubes are supported by stainless steel quatrefoil support plates (TSP's) and chrome plated Alloy-600 anti-vibration bars (AVB's). See Figure A.1 for a diagram of the D-5 Steam Generator tube support plate configuration.

In accordance with Braidwood Station Technical Specification (TS) 3.4.19, "Steam Generator (SG) Tube Integrity," TS 5.5.9, "Steam Generator (SG) Program," and American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (B&PV)

Code Section XI 1989 Edition, IWB 2500-1, Examination Category B-Q, Item B16.20, SG eddy current examinations were performed during the Braidwood Station, Unit 2, thirteenth refueling outage (A2R1 3). In addition, the inspections were performed consistent with the Electric Power Research Institute (EPRI) "PWR Steam Generator Examination Guidelines," Revision 6 and Nuclear Energy Institute NEI 97-06, "Steam Generator Program Guidelines," Revision 2. The inspections were conducted from April 24, 2008 through May 5, 2008 by the Westinghouse Electric Company LLC. The following inspections were performed during this outage (TS 5.6.9.a).

100% bobbin coil eddy current examination of all SGs excluding the Row 1 and 2 U-Bend regions. In the Row 1 and 2 U-Bend regions a 25% +PointTM inspection was performed as described below.

Note: In the 2A SG, the cold leg straight sections of fifteen (15) tubes were not inspected with bobbin eddy current. This was due to the tubes being plugged prior to completion of cold leg eddy current inspection.

20% hot leg top of tubesheet (+ 3") +PointTM in all SGs.

20% hot leg bulges > 18 Volts and over expansions > 1.5 mils above 1 inch from the hot leg tubesheet tube end, +PointTM in all SGs.

20% of the hot leg tubing within the tubesheet for the full-length of tubesheet,

+PointTM in all SGs.

100% of the lower 1 inch of tubing within the hot leg tubesheet, +PointTM in all SGs.

100% hot leg top of tubesheet (+ 3") and full-length of the hot leg tubing within the tubesheet, +PointTM of inservice tubes identified as having increased residual stress.

100% of the hot leg dents/dings > 3.0 volts contained in inservice tubes identified as having increased residual stress, +PointTM.

100% of the wear indications contained in inservice tubes identified as having increased residual stress, +PointTM. (Note: None were identified during A2R13).

0

+PointTM inspection of all hot leg and cold leg tubesheet expansions transitions significantly outside the tubesheet. (Note: None were identified during A2R1 3).

0

+PointTM inspection of all pre-heater baffle plate expansions significantly above or below the baffle plate. (Note: None were identified during A2R1 3).

20% pre-heater baffle expansion +PointTM in the 2A SG.

1

25% hot leg dents/dings >3.0 volts +PointTM in all SGs.

25% row 1 and 2 U-bends +PointTM in all SGs.

Inspection of one deplugged tube hot leg Plug Expansion Zone (PEZ) +PointTM.

100% visual inspection of the previously installed and, newly installed tube plugs in all SGs.

2.0

SUMMARY

The requirements of Revision 6 of the EPRI PWR Steam Generator Examination Guidelines (i.e., EPRI Guidelines) along with Interim Guidance as provided by EPRI, were implemented during this inspection. A degradation assessment was performed prior to the inspection to ensure the proper EPRI Appendix H, "Performance Demonstration for Eddy Current Examination," qualified inspection techniques were used to detect any existing and potential modes of degradation. Each technique was evaluated to ensure that the detection and sizing capabilities are applicable to the Braidwood Station, Unit 2, site specific condition in accordance with the EPRI Guidelines. All data analysts were qualified to Appendix G, "Qualification of Nondestructive Examination Personnel for Analysis of NDE Data," of the EPRI Guidelines (i.e., Qualified Data Analyst (QDA)). All data analyst and acquisition personnel satisfactorily completed site specific training and testing prior to beginning examinations. An independent QDA process control review was employed to randomly sample the data to ensure that the analysis resolution process was properly performed and that the field calls were properly reported. An analysis feedback process was implemented that required the data analysts to review their missed calls and overcalls on a daily basis.

The modes of tube degradation found during A2R1 3 were Anti-Vibration Bar (AVB) wear, pre-heater tube support plate wear, secondary side foreign object wear, and Primary Water Stress Corrosion Cracking (PWSCC) that was limited to the bottom one inch of tubing in the hot leg tubesheet region. Prior to the start of A2R1 3 the NRC granted approval of an Interim Alternate Repair Criteria (IARC) for use during A2R13 and the subsequent operating cycle. Approval of the IARC was incorporated into the Braidwood Technical Speciation via Amendment Number 150. The IARO provided acceptance criteria for indications of PWSCC within the tubesheet region provided they are located below 17 inches from the top of the tubesheet.

As a result of the eddy current inspection of the SGs, a total of twenty-three (23) tubes were removed from service by mechanical tube plugging. Of the twenty-three (23) tubes removed from service, sixteen (16) were due to having PWSCC indications exceeding the IARO acceptance criteria, six (6) tubes were plugged due to having AVB wear greater than or equal to the 40% through wall (TW) Technical Specification 5.5.9.c.1 acceptance criteria, and one (1) tube was preventatively plugged due to having an 11%

TW wear from a secondary side foreign object. Pursuant to EPRI Guideline Section 3.5, "Inspection Results Categories", the results of the inspection were classified as inspection category C-1 for the 2B SG and C-2 for the 2A, 20 and 2D SGs. There were no scanning limitations during the examinations.

Table 2.1 provides the tube plugging levels for each SG. Table 2.2 provides the total number of tubes plugged during A2R1 3 by degradation mode.

2

Table 2.1 Equivalent Tube Plugging Level (TS 5.6.9.f & TS 5.6.9.h)

-SG IA.

S2 SGC G2D'i Total Tubes Previously Plugged 66 49 60 25 200 Tubes Plugged in A2R13 17 0

5 1

23 Total Tubes Plugged 83 49 65 26 223 Total Tubes Plugged (%)

1.82%

1.07%

1.42%

0.57%

1.22%

Table 2.2 Tubes Plugged During A2113 TS 5.6.9.e)

-SG 2A S, 2 SG '2C S 2-Total,.-

Foreign Object Wear.

0 0

1 0

1 Anti-Vibration Bar Wear 1

0 4

1 6

PWSCC in Lower Hot Leg 16 0

0 0

16 Tubesheet Region I

I A2R13 Plugging Totals 17 0

5 1

23 The Braidwood Unit 2 SGs are currently in their 90 Effective Full Power Month (EFPM) inspection period. The A2R13 outage was the second to last outage in the inspection period, with the next refueling outage (A2R14) being the last outage within the inspection period.

3.0 CERTIFICATIONS 3.1 Procedures/Examinations/Equipment 3.1.1 The examination and evaluation procedures used during the SG eddy current inspection were approved by personnel qualified to Level III in accordance with the 1984 Edition of SNT-TC-1A, "Personnel Qualification and Certification in Nondestructive Testing." Exelon Generation Company, LLC (i.e., Exelon) Procedure ER-AP-335-039, "Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing," Revision 4 and Exelon Procedure ER-AP-335-040, "Evaluation of Eddy Current Data for Steam Generator Tubing," Revision 3, were used for data acquisition and analysis.

3.1.2 The examinations, equipment and personnel were in compliance with the requirements of Exelon and Westinghouse Quality Assurance Programs for Inservice Inspection; Braidwood Station Technical Specification 5.5.9; 1989 Edition of ASME Boiler and Pressure Vessel Code Sections XI, "Rules for Inservice Inspection of Nuclear power Plant Components," and V, "Nondestructive Examination"; EPRI PWR SG Examination Guidelines Revision 6; and NEI 97-06, "Steam Generator Program Guidelines,"

Revision 2.

3

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

3.1.4 CoreStar International Corporation OMNI-200 TM Remote Data Acquisition Units (RDAUs) with Westinghouse ANSER 8.4.3 Revision 213 computer software was used to acquire the eddy current data. Analysis was performed with Westinghouse ANSER 8.4.3 Revision 299 computer software.

3.1.5 The bobbin coil examinations of the SGs were performed with 0.610 inch diameter bobbin coil eddy current probes. For low row U-Bend tubing, 0.590 inch diameter probes were utilized where there was difficulty using the 0.610 inch diameter probe.

3.1.6 The top of tubesheet, tubesheet region, baffle plate expansion, and special interest rotating coil examinations were performed with a 0.610 inch diameter three coil rotating plus-point probe that contained a plus-point coil, a 0.115 inch diameter pancake coil and a 0.080 inch diameter pancake coil.

3.1.7 The rotating coil examinations in the U-Bend region were performed With a 0.580 inch diameter rotating plus-point probe.

3.2 Personnel 3.2.1 The personnel who performed the SG eddy current inspections were qualified to Level I and Level II certification in accordance with the 1984 Edition of SNT-TC-1A. The Level I personnel performed the inspections under the direct supervision of Level II or Level III personnel. A list of the certified eddy current personnel who performed data acquisition for the examination is contained in Table A. 1 of Attachment A.

3.2.2 The personnel who performed the SG eddy current data analysis were qualified to a minimum of Level II, with special analysis training (i.e., Level IIA) in accordance with the 1984 Edition of SNT-TC-1A and Article IV-2000 of ASME Section XI, 1989 Edition. A list of the certified eddy current personnel who performed data analysis for the examination is contained in Table A.2 of Attachment A.

3.2.3 All eddy current data analysts were qualified in accordance with EPRI Appendix G for Qualified Data Analysts (QDAs). In addition, all data analysts were trained and tested in accordance with a site specific performance demonstration program in both the bobbin coil and +PointTM inspection data analysis. Resolution analysts were also trained and tested specifically for the performance of data resolution. All analysts were required to achieve a minimum score of 80% Probability of Detection (POD) with a 90% confidence level on the practical 4

examination, and a minimum score of 80% on the written examination prior to analyzing data.

3.2.4 All SG eddy current data acquisition personnel were trained and tested in accordance with a site specific performance demonstration program. The data acquisition operators were required to achieve a written test score of 80% or greater prior to acquiring data.

3.2.5 The SG eddy current analysis was subject to two independent analyses.

Primary analysis of all data was performed by Westinghouse and sub-contractors. Secondary analysis was performed by various sub-contractor companies, different than those used on primary analysis.

Discrepancies between the two parties required Level Ill concurrence between both parties for the final resolution.

3.2.6 Two independent SG eddy current Level III QDA's were employed to serve as process control reviewers, in accordance with EPRI Guidelines, to randomly sample the data to ensure the resolution process was properly performed and that the field calls were properly reported. The Independent Level III QDA's also provided data acquisition oversight to ensure that the data collection process was in compliance with appropriate procedures, that all essential variables were set in accordance with the applicable Examination Technique Specification Sheet (ETSS) and to provide a data quality check of acquired data. The Independent Level III QDA's reported directly to the Exelon Level III inspector.

3.2.7 Personnel qualified as data analysts performed real time data quality verifications.

4.0 EXAMINATION TECHNIQUES AND EXAMINATION SCOPE All SG eddy current examination techniques used were qualified in accordance with Appendix H of the EPRI PWR SG Examination Guidelines. Each examination technique was evaluated to be applicable to the tubing and conditions of the Braidwood Station Unit 2 SGs.

4.1 Examination Techniques (TS 5.6.9.c) 4.1.1 The bobbin coil examinations were performed with a 0.610 inch diameter bobbin coil eddy current probe as described in Section 3.1.5. For low row U-Bend regions where there was difficulty using the 0.610 inch diameter probe, a 0.590 inch diameter probe was utilized where there was difficulty traversing the U-Bend region. The nominal probe inspection speed was 40 inches per second for rows 5 through 49 and 24 to 40 inches per second for rows 1 through 4 depending on tube conditions. Sufficient sampling rates were used to maintain a minimum of 30 samples per inch. The bobbin coil probes were operated at frequencies of 550 kHz, 300 kHz, 130 kHz, and 20 kHz operating in the differential and absolute test modes. In addition, suppression mixes were used to enhance the inspection. These 5

mixes were as follows: 550/130 kHz differential mix, a 550/300/130 kHz differential mix, and a 300/130 kHz absolute mix.

4.1.2 The +PointTM examinations at the top of tubesheet, within the tubesheet, pre-heater baffle plate expansion transition regions, dents/dings and special interest locations were performed with a 0.610 inch diameter three coil +PointTM eddy current probe as described in Section 3.1.6. Nominal probe speed was 0.8 inches per second and 0.10 inches per second for the examination of dent and dings. For the tube expansion regions and special interest regions a sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 25 samples per inch in the axial direction. For the dent/ding regions a sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 30 samples per inch in the axial direction. The rotating probes were operated at frequencies of 300 kHz, 200 kHz, 100 kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display circumferential indications in the positive trace.

4.1.3 The +PointTM examinations within the low row U-Bend regions were performed with a 0.580 inch diameter +PointTM eddy current probe as described in Section 3.1.7. Nominal probe speed was 0.4 inches per second. A sampling rate was used to maintain a minimum of 30 samples per inch in the circumferential direction and 30 samples per inch in the axial direction. The rotating probes were operated at frequencies of 400 kHz, 300 kHz, 150 kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display circumferential indications in the positive trace.

4.1.4 The eddy current calibration standards used for the bobbin coil and

+PointTM inspections met the requirements of the EPRI PWR Steam Generator Examination Guidelines, Revision 6 and Sections V and XI of the ASME Boiler and Pressure Vessel Code, 1989 Edition.

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

6

TABLE 4.1 EPRI APPENDIX H TECHNIQUES EPRITechnique Probe Description ETS u

-r e; esr o

96004.3 Rev. 11 Bobbin AVB I Pre-Heater / TSP I Foreign Object Wear, Freespan Flaws 96043.2 Rev. 1 Bobbin Single Land Tube Support Plate Wear 96007.1 Rev. 11 Bobbin ODSCC at Tube Support Plates 96910.1 Rev. 10

+PointTM Foreign Object Wear / Freespan Flaw Sizing / TSP Tapered Wear 96005,2 Rev. 9 Bobbin Freespan Pitting 21998.1 Rev. 4

+PointTM Foreign Object Wear / Freespan Flaw Sizing 20511.1 Rev. 8

+PointTM TTS Expansion / Tubesheet / Pre-Heater Expansion /

Dent / Ding / Deplugged Tube Location -

Axial PWSCC 20510.1 Rev. 7

+PointTM TTS Expansion / Tubesheet / Pre-Heater Expansion /

Dent

/

Ding

/

Deplugged Tube Location Circumferential PWSCC 21409.1 Rev. 5

+PointTM TTS Expansion / Pre-Heater Expansion / Sludge Pile

- Axial ODSCC 21410.1 Rev. 6

+PointTM TTS Expansion / Dent / Ding / Pre-Heater Expansion

- Circumferential ODSCC 22401.1 Rev. 4

+PointTM Dent/ Ding -Axial ODSCC 96511.1 Rev. 16

+PointTM Low Row U-Bend Axial and Circumferential PWSCC 96703.1 Rev. 17

+PointTM Dent / Ding / Axial PWSCC PWSCC - Primary Water Stress Corrosion Cracking ODSCC - Outer Diameter Stress Corrosion Cracking TSP - Tube Support Plate l-S - Top of Tubesheet AVB - Anti-Vibration Bar 4.2 Steam Generator Inspection Scope (TS 5.6.9.a) 4.2.1 100% of the tubes in all four SGs were inspected full length, with a bobbin coil probe as described in Section 4.1.1, with the exception of the Row 1 and 2 U-Bend region where a 25% sample was performed with a +PointTM probe as described in Section 4.1.3. Additionally, in the 2A SG, the cold leg straight section on fifteen (15) tubes was not inspected with bobbin eddy current. This was due to the tubes inadvertently being plugged prior to completion of cold leg eddy current inspection.

4.2.2 20% of the tubes in all four SGs were inspected full length in the hot leg tubesheet region from 3 inches above the top of tubesheet expansion transition region to the tube end with a +PointTM probe as described in Section 4.1.2. This population included 20% of the hot leg bulges > 18 volts and over expansions > 1.5 mils above 1 inch from the hot leg tubesheet tube end. These inspections were performed with a +PointTM as described in Section 4.1.2.

7

4.2.3 Based on the initial 20% full length hot leg tubesheet inspection as described in Section 4.2.2 identifying indications within the bottom 0.5 inches of tubing, scope was expanded to 100% of the bottom 1 inch of the hot leg tubing in all SGs. A +PointTM probe as described in Section 4.1.2 was used for this inspection.

4.2.4 100% of the tubes identified in all four SGs as having increased residual stress were inspected full length in the hot leg tubesheet region from 3 inches above the top of tubesheet expansion transition region to the tube end with a +PointTM probe as described in Section 4.1.2. Additionally, all hot leg dents/dings > 3.0 volts, and any wear indications identified in these tubes were inspected with a +PointTM probe as described in Section

4.1.2. (Note

No wear indications were identified in these tubes.)

4.2.5 20% of the pre-heater baffle plate expansion transitions (+/- 3 inches) in the 2A SG were inspected with a +PointTM probe at baffle plates 02C and 03C as described in Section 4.1.2. Additional pre-heater baffle plate expansion transitions (+/- 3 inches) were inspected in the 2B, 2C and 2D SGs with a +PointTM probe as described in Section 4.1.2, at baffle plate 02C in the outer peripheral tubes near the flow blocking region of the pre-heater. This location has historically been known as an area where secondary side foreign objects may collect due to the flow conditions in the region.

4.2.6 Inspection of the hot leg plug expansion zone of one tube in the 2B SG was performed. This is the only tube at Braidwood Station Unit 2 which had been previously deplugged and returned to service. This inspection was performed with a +PointTM probe as described in Section 4.1.2.

4.2.7 25% of the hot leg dents/dings greater than 3.0 volts based on bobbin inspection results, were inspected (+/- 3 inches) in all four SGs with a

+PointTM probe as described in Section 4.1.2.

4.2.8 25% of the Row 1 and Row 2 U-Bends in all four SGs were inspected from the top support plate on the hot leg side to the top support plate on the cold leg side with a +PointTM probe as described in Section 4.1.3.

4.2.9 100% +PointTM inspection of all hot leg and cold leg tubesheet expansions transitions significantly outside the tubesheet, and pre-heater baffle plate expansions significantly above or below the baffle plate, as determined by review of bobbin eddy current data.

4.2.10 Diagnostic examinations were conducted on non-quantifiable indications that were detected by the bobbin coil examination. Diagnostic examinations were also conducted on tubes in the vicinity of potential foreign objects in order to determine the extent of tubes potentially affected by the objects. These examinations were performed with a

+PointTM as discussed in Section 4.1.2.

4.2.11 See Attachment B for tubesheet maps detailing the inspection scopes for each SG.

8

4.3 Recording of Examination Data The eddy current data and analysis results were recorded on hard drives. The data was then loaded into the Westinghouse Eddy Current Data Management System, "ST Max" Version 1.21.02. This system was used to track the completion of the examinations and was used to generate the final SG eddy current report summaries.

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

5.0 EXAMINATION RESULTS 5.1 Indications Found (TS 5.6.9.b) 5.1.1 Anti-Vibration Bar (AVB) Wear - Tube degradation was found during bobbin coil examination in the U-Bend region due to fretting of Anti-Vibration Bars on the outer surface of the tube. A total of 868 indications were reported. The EPRI Appendix H bobbin coil technique 96004.3 was utilized for depth sizing of all AVB wear. The largest indication was 43%

through wall (TW). A total of six (6) tubes had indications of AVB wear greater than or equal to 40% TW and were removed from service by mechanical tube plugging. Table 5.1.1 provides a summary of AVB wear degradation. Refer to Attachment B for detailed locations and sizing for all AVB wear indications.

Table 5.1.1 A2R13 AVB Wear Summary

<20% TW 208 52 102 82 20-39% TW 151 45 143 79

> 40% TW 1

0 4

1 TOTAL 360 97 249 162 5.1.2 Foreign Object Wear-EPRI Appendix H +PointTM coil sizing technique 21998.1 was used to size indications of secondary side foreign object wear identified during A2R13. One (1) tube in the 2C SG tube Row 3 Column 85 had an 11% Through Wall (TW) indication at + 2.08 inches above the 5 th support plate on the cold leg side. Review of historical data showed that the indication had been present since the first inservice inspection in 1990 and had not changed. This tube was plugged and stabilized. +PointTM inspection of the surrounding tubes in this region 9

showed no signs of tube wear or presence of a foreign object. The area where the wear occurred was not accessible for secondary side visual inspection.

Additionally, four (4) tubes distributed in the 2A, 2B and 2D SGs had five (5) indications of foreign object wear that had not changed since the previous refueling outage (A2R12) inspection. These tubes have been allowed to remain in service based on being below the Technical Specification plugging limit and visual verification that the object(s) that had caused the wear were no longer present. Inspection of these locations during A2R1 3 confirmed that these wear indications had not grown since the last inspection, therefore the tubes remain in service.

Refer to Attachment B for detailed locations and sizing for foreign object wear indications.

5.1.3 Pre-heater Wear - Tube degradation was found in six (6) tubes that was attributable to pre-heater baffle / tube support plate wear. The depth of the pre-heater wear ranged from 3% TW to 30% TW. The depth was measured by either EPRI Appendix H qualified bobbin coil technique 96004.3 if the wear was at a drilled hole support, or bobbin coil technique 96043.2 if the wear was at a quatrefoil hole support location. Since no indications exceeded the Technical Specification plugging limit no tube plugging was required for this damage mechanism. Refer to Attachment B for detailed locations and sizing for all pre-heater wear indications.

5.1.4 Tubesheet Region Inspection Results (TS 5.6.9.i) - The initial 20% full length hot leg tubesheet inspection in all SGs with a +PointTM probe as described in Section 4.2.2, identified indications within the bottom 0.5 inches of tubing. Based on these indications scope expanded to 100% of the bottom 1 inch of the hot leg tubing in all SGs as described in Section 4.2.3. Table 5.1.4 provides a summary of the indications identified during the hot leg tubesheet inspection. All indications were indicative of Primary Water Stress Corrosion Cracking (PWSCC) originating from the primary side of the tube. Table 5.1.4 also identifies the number of tubes in each SG that exceeded the Interim Alternate Repair Criteria (IARC) that was approved for use at Braidwood by the Nuclear Regulatory Commission via License Amendment Number 150. The tubes that exceeded the IARC were removed from service by mechanical tube plugging. The IARC was approved for use during the Braidwood Unit 2 thirteenth refueling outage (A2R1 3) and subsequent operating cycle.

During A2R1 3, for tubes that contained more than one circumferential indication, the circumferential extents of the indications were conservatively added together without taking credit for overlap. The combined circumferential extent was then compared against the IARC plugging criteria. Refer to Attachment B for detailed locations and sizing for all indications identified within the hot leg tubesheet region.

10

Table 5.1.4 Summary of Indications in the Bottom 1 Inch of Hot Leg Tubin

'Steam...

-- "Axial..

Circumferential Tubes with ".'.Tubes--.

Generator-Indications-Indications Indications,'

Exceeding SG 2A 105 43 118 16 SG 2B 24 1

25 0

SG 2C 129 2

118 0

SG 2D 27 0

27 0

Total 285 46 288 16 5.2 Other SG Inspection Results 5.2.1 Inspection of Tubes that Potentially Contain Hiqher Residual Stress -

Prior to the start of A2R13 Braidwood had seventy one (71) tubes in service that were previously screened as potentially containing higher residual stress. This screening was performed in response to a fabrication anomaly that was found at another plant containing thermally treated Alloy-600 tubing, which was linked to the development of stress corrosion cracking of the tubes at the support plate intersections. The following inspections were performed during A2R1 3 on the 71 tubes that could potentially contain higher residual stress:

o Full Length bobbin coil inspection as described in Section 4.1.1.

o Full Length hot leg top of tubesheet inspection (+3 inches to tube end) with a +PointTM probe as described in Section 4.1.2.

o Inspection of all hot leg dents and dings greater than 3.0 volts with a

+PointTM probe as described in Section 4.1.2.

o Inspection of all wear indications with a +PointTM probe as described in Section 4.1.2. (Note: No wear indications were identified in these tubes.)

As a result of these inspections no indications of stress corrosion cracking were found above the hot leg tubesheet region. As part of the hot leg tubesheet inspection program two (2) tubes in the 2C SG had axial indications in the bottom 1 inch of hot leg tubing. These indications were allowed to remain in service since they did not exceed the IARC as discussed in Section 5.1.4. As part of the full-length bobbin inspection program for these tubes, two (2) hot leg dents/dings greater than 3.0 volts were identified. These two (2) dents/dings were inspected with a +PointTM probe as described in Section 4.1.2 and no degradation was identified.

Refer to Attachment B for detailed locations and sizing for all indications identified within the tubes identified as having potentially higher residual stress.

5.2.2 Visual Inspection of Installed Tube Pluqs - All previously installed tube plugs were visually inspected for signs of degradation and leakage. In addition, all plugs installed during this outage (A2R13) were also visually 11

inspected and the installation parameters were reviewed for acceptable installation. No anomalies were found.

5.2.3 Attachment B contains tube lists with location and orientation of all imperfections that contain measurable through wall depth that were found during the A2R1 3 eddy current inspection. All indications within the tubesheet were initiated from the primary side of the tube, while all indications above the tubesheet were outside diameter initiated (TS 5.6.9.d).

5.2.4 No tubes were identified with hot leg or cold leg tubesheet expansions transitions significantly outside the tubesheet, additionally no pre-heater baffle plate expansions were identified significantly above or below the baffle plate, as determined by review of bobbin eddy current data.

5.2.5 A visual inspection of the secondary side moisture separator regions of all fours SGs was performed during the A2R13 outage. The inspection was performed in accordance with Westinghouse procedure MRS-SSP-1 323-CBE/CDE, "Model D-5 SG Steam Drum and Auxiliary Feedwater Nozzle/Piping Inspection at Byron Station, Unit 2, and Braidwood Station, Unit 2," Revision 0. This was a follow-up inspection of the 2D SG based on erosion of the moisture separator tangential nozzles, downcomer barrels and swirl vanes being identified during the previous outage (A2R1 2), refer to the previous Braidwood Unit 2 Twelfth Refueling Outage Steam Generator Inservice Inspection Summary Report, dated January 29, 2007.

During A2R1 3 visual inspection and ultrasonic thickness measurements were taken of the eroded areas, with an emphasis on reinspection of the areas identified as eroded in the 2D SG during the previous A2R12 inspection, and initial inspection of all accessible areas in the 2A, 2B and 2C SGs. Continued erosion of the components was identified in the 2D SG, while no indications of through wall erosion were identified. Similar extent of corrosion was found in all four SGs with the most wear being identified in the 2C SG, which showed a maximum wall loss of 48% as compared to the original manufacturing nominal value. An analysis was performed that determined that in the eroded areas significant margin remained prior to the erosion penetrating through wall and affecting SG performance or possibly generating loose parts. The erosion in the affected areas was not projected to penetrate through wall over the next operating cycle. Monitoring of the condition is planned over subsequent operating cycles in order to develop a degradation growth rate and take corrective actions if they become necessary.

6.0 RESULTS OF CONDITION MONITORING (TS 5.6.9.g)

A condition monitoring assessment was performed for each inservice degradation mechanism found during the A2R13 SG inspection. The condition monitoring assessment was performed in accordance with TS 5.5.9.a and NEI 97-06 using the EPRI Steam Generator Integrity Assessment Guidelines, Revision 2. For each identified 12

degradation mechanism, the as-found condition was compared to the appropriate performance criteria for tube structural integrity, accident induced leakage and operational leakage as defined in TS 5.5.9.b. For each damage mechanism a tube structural limit was determined to ensure that SG tube integrity would be maintained over the full range of normal operating conditions and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary to secondary pressure differential and a safety factor of 1.4 against burst under the limiting design basis accident pressure differential. The structural limit was also based on using the draft Regulatory Guide 1.121 methodology for uniform wall thinning of unlimited length using ASME Code minimum material properties. Satisfying the structural limit ensures that the SG tube integrity performance criteria for structural integrity, accident induced leakage and operational leakage will be maintained.

The as-found condition of each degradation mechanism found during the A2R1 3 outage was shown to meet the appropriate limiting structural integrity performance parameter with a probability of 0.95 at 50% confidence, including consideration of relevant uncertainties.

No tube pulls or in-situ pressure testing was performed during A2R13.

Sections 6.1 through 6.4 provide a summary of the condition monitoring assessment for each degradation mechanism. Section 6.5 provides a primary to secondary leakage assessment as required by TS 5.6.9.k and TS 5.6.9.1.

6.1 AVB Wear The largest AVB wear indication found during the A2R1 3 inspection was 43%

TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision

11. Considering technique and analyst uncertainties, the largest AVB wear indication found is corrected to 50% TW with a 0.95 probability at 50%

confidence. This is below the AVB wear structural limit of 71.4% TW.

6.2 Pre-Heater Baffle/TSP Wear The largest pre-heater baffle plate drilled hole baffle wear indication found during the A2R13 inspection was 4% TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision 11. Since the Braidwood A2R1 3 EPRI Appendix H Qualification report determined that the signal to noise ratio may influence detection of indications less than 17% TW, it was conservatively assumed at a 17% TW indication could be present but not detected. Therefore it was conservatively assumed that a 17% TW indication was the largest indication remaining in service. Considering technique and analyst uncertainties, this indication is corrected to 25% TW with a 0.95 probability at 50% confidence.

This is below the 0.75-inch baffle plate wear structural limit of 65.6% TW.

The largest single land TSP quatrefoil wear indication found during the Refueling Outage 13 inspection was 30% TW as measured by the EPRI Appendix H qualified technique 96043.2, Revision 1. Considering technique and analyst uncertainties, the largest single land TSP wear indication found is corrected to 13

34% TW with a 0.95 probability at 50% confidence. This is below the 1.12 inch TSP wear structural limit of 60.7% TW.

6.3 Foreign Object Wear The largest foreign object wear indication found during the A2R13 inspection was 36% TW as measured by the EPRI Appendix H qualified technique 21998.1, Revision 4. This indication had not changed since the previous refueling outage (A2R12) inspection. This tube has been allowed to remain in service based on being below the Technical Specification plugging limit and visual verification that the object(s) that had caused the wear were no longer present, additional detail is provided in Section 5.1.2. Considering technique and analyst uncertainties, the foreign object wear is corrected to 54% TW with a 0.95 probability at 50%

confidence. This is below the 58.1% TW freespan uniform wall thinning of unlimited length structural limit.

6.4 Tubesheet Region Indications During A2R13 all indications identified within the tubesheet were contained within the bottom 1 inch of the hot leg tubesheet. As discussed in the IARC analysis, axial indications within this region are acceptable for continued operation since they are constrained within the tubesheet and have no safety significance. The largest circumstantial indication identified during A2R13 had an arc length of 211 degrees. While this indication exceeded the IARC for repair, it was below the 270 degree arc length structural limit for circumferential indications at the top of tubesheet. Therefore, the indications identified within the tubesheet during A2R13 met all condition monitoring requirements. In addition, from a condition monitoring perspective, for the previous cycle of operation (Cycle 13), Braidwood Unit 2 had been operating under criteria that did not require inspection below 17 inches from the top of the hot leg tubesheet. Braidwood Technical Specification Amendment 141, issued October 24, 2006 allowed that during Braidwood Station Unit 2 refueling outage twelve (A2R1 2), and the subsequent operating cycle (Cycle 13), the hot leg tubesheet inspection scope could be limited to the region 17 inches below the top of the hot leg tubesheet. This was based on analysis performed which concluded that the bottom four inches of the tube confined within the hot leg tubesheet is not safety significant, and any degradation within this region will not impact tube structural integrity or leakage limits during normal operating and accident conditions. Since this analysis was in place and approved for use during Cycle 13, and the inspections results obtained during A2R13 identify indications present during Cycle 13, all condition monitoring requirements are inherently met since all degradation identified during A2R13 was contained below 17 inches from the top of the hot leg tubesheet. All A2R1 3 indications were limited to the bottom 1 inch of tubing within the hot leg tubesheet. All indications that exceeded the IARC as defined in License Amendment 150 were repaired during A2R13.

6.5 Primary-to-Secondary Leakage Assessment (TS 5.6.9.k and TS 5.6.9.1)

Braidwood Unit 2 did not observe any operational primary to secondary leakage greater than three gallons per day over the cycle preceding the inspection.

Chemistry sampling of the Steam Jet Air Ejector and liquid SG blowdown sample 14

locations did not detect any SG operational leakage that was above the detection threshold. Therefore, it was determined that there was no quantifiable SG operational leakage.

The IARC contains additional requirements for Condition Monitoring (CM) assessment and Operational Assessment (OA) evaluation. The requirements and evaluations are summarized as:

For the CM assessment, the component of leakage from the lower 4 inches of the most limiting SG during the prior cycle of operation will be multiplied by a factor of 2.5 and added to the total leakage from any other source and compared to the allowable accident analysis leakage assumption.

0 For the OA evaluation, the difference in leakage between the allowable limit during the design basis accident and the leakage from other sources will be divided by 2.5 and compared to the observed leakage and, if required, an administrative limit will be established to not exceed the calculated value.

Regarding the CM requirement, since Braidwood Unit 2 did not observe any measurable SG primary to secondary operational leakage, the calculated accident leakage rate from flaws in the lowermost 4-inches of the hot leg tubesheet would also not be quantifiable.

Regarding the OA requirement, Braidwood Unit 2 did not observe any measurable SG primary to secondary operational leakage during Cycle 13.

Further, no degradation that may lead to leakage was detected above the bottom 4 inches of the tubesheet region during A2R13. This is evidenced by all degradation modes identified during A2R13 being below the tube structural limits as described in Sections 6.1, 6.2 and 6.3. Therefore, the entire allowable accident induced leakage (0.5 gallons per minute Room Temperature (gpmRT))

at Braidwood Unit 2 can be allocated to the tubesheet expansion region over the next cycle of operation. Using the calculation basis above, the allowable normal accident induced leakage from the tubesheet expansion region is 0.2 gpmRT (0.5 gpmRT divided by 2.5), which is greater than the 150 gpdRT (0.104 gpmRT)

Technical Specification (TS) 3.4.13 primary to secondary leakage limit for Braidwood Unit 2. Therefore, no adjustment of the TS 3.4.13 limit for normal operating leakage is required, and accident conditional leakage limits are maintained by adherence to TS 3.4.13.

7.0 REPAIR

SUMMARY

(TS 5.6.9.i)

Repairs were conducted in accordance with ASME Section X1, 1989 Edition. All repairs were performed using Alloy-690 mechanical tube plugs. All repairs were performed in accordance with Westinghouse approved procedures. Prior to plugging, one (1) tube in the 2C SG tube Row 3 Column 85 which had an 11% TW indication at + 2.08 inches above the 5 th support plate on the cold leg side was stabilized through the region of wear. Table 7.0 summarizes the repairs performed during A2R13. No tube sleeving was performed.

15

Table 7.0 Refer to Attachment B for detailed locations and sizing of indications in tubes that were plugged during A2R13.

8.0 DOCUMENTATION All original optical disks have been provided to Exelon and are maintained at Braidwood Station. The final data sheets and pertinent tube sheet plots are contained in the Westinghouse Outage Report for Braidwood Station Unit 2, Thirteenth Refueling Outage, and are also maintained at Braidwood Station.

NOTE: The ASME Section XI NIS-1 Form. "Owner's Report for Inservice Inspections," for steam generator inspections performed during the Braidwood Station Unit 2 Thirteenth Refueling Outage was submitted as part of "Braidwood Station, Unit 2 Inservice Inspection Summary Report", dated August 13, 2008.

16

9.0 FIG URES/TABLES/ATTACHMENTS Attachment A Contents Table A.1 Data Acquisition Personnel Certification List Table A.2 Data Analysis Personnel Certification List Figure A.1 Westinghouse Model D-5 Tube Support Plate Attachment B Contents Attachment B.1 As-tested Bobbin Inspection Maps Attachment B.2 As-tested +PointTM Inspection Maps Attachment B.3 As-tested +PointTM Special Interest Inspection Maps Attachment B.4 Tubes Containing Secondary Side Foreign Wear Attachment B.5 Tubes Containing Anti-Vibration Bar Wear Attachment B.6 Tubes Containing Pre-heater Wear Attachment B.7 Tubes that Potentially Contain Higher Residual Stress Attachment B.8 Tubes Containing Indications within the Tubesheet Attachment B.9 Tubes Repaired During A2R13 17

Attachment A Personnel Certifications

TABLE A.1 A2R13 Data Acquisition Personnel Certifications 2

Mantich, S.

Hudson I

No 3

Spires, A.

Hudson I

No 4

Bradley, G.

Westinghouse II No 5

Chiplaskey, G.

Westinghouse II No 6

Evering, D.

Westinghouse II No 7

Fore, S.

Westinghouse II No 8

Gault, W.

Westinghouse II No 9

Miller, G.

Westinghouse II No 10 Scott, A.

Westinghouse II No 11 Shipley, E.

Westinghouse II No 12 Smith, D.

Westinghouse II No 13 Vernon, D.

Westinghouse II No

• Qualified Data Analyst

TABLE A.2 A2R13 Data Anal sis Personnel Certifications Np.

Name Company,

.Lev.l Q.A* (Y.N) 1 Chapmon, G.

Young TS IIA Yes 2

Newsom, C.

Young TS IIA Yes 3

Brown, M.

NDE Technology III Yes 4

Siegel, R.

NDE Technology III Yes 5

Chambers, D.

More Tech III Yes 6

Newman, E.

More Tech IIA Yes 7

Richardson, H.

More Tech III Yes 8

Sordini, J.

More Tech IIA Yes 9

Anderson, D.

NDE Tech IIA Yes 10 Grant, B.

NDE Tech III Yes 11 Thompson, K.

NDE Tech IIA Yes 12 Stock, W.

Westinghouse III Yes 13 Calander, D.

Young TS IIA Yes 14 Chevalier, W.

Young TS IIA Yes 15 Circosta, S.

Young TS III Yes 16 Emley, L.

Young TS IIA Yes 17 Sails, Y.

Young TS III Yes 18 Neff, A.

Anatec III Yes 19 Dlabik. A.

Master-Lee III Yes 20 Lynn, V.

Master-Lee III Yes 21 Thulien, T.

More Tech III Yes 22 Black, C.

NDE Tech III Yes 23 Casuby, G.

NDE Tech III Yes 24 Drumm, R.

NDE Tech III Yes 25 Popovich, R.

Westinghouse III Yes 26 Welch, L.

Young Tech III Yes 27 Dykes, R.

Anatec IIA Yes 28 Maben, D.

Anatec III Yes 29 Raper, L.

Anatec III Yes 30 Wieber, J.

Anatec IIA Yes 31 Munk, R.

HRID IIA Yes 32 Zerovnik, V.

HRID IIA Yes 33 Zunac, D.

HRID IIA Yes 34 Galmoff, T.

Master-Lee IIA Yes 35 Kajari, I.

Master-Lee IIA Yes 36 Webb, M.

More Tech IIA Yes 37 Alspaugh NDE Tech III Yes 38 Agun Diez, F.

Tecnatom IIA Yes

.39 Garcia Lopez, F.

Tecnatom III Yes 40 Garcia Lopez, J.

Tecnatom IIA Yes 41 Manzanares, I Tecnatom IIA Yes 42 Garcia Munoz, A.

Tecnatom III Yes 43 Garcia-Caro, C.

Tecnatom IIA Yes 44 Rico Gonzalez. P Tecnatom IIA Yes 45 Martin, A.

Wiltec IIA Yes

• Qualified Data Analyst

FIGURE A.1 Westinghouse Model D-5 Tube Support Plate Configuration Anti-vibration

-bars Feedwater Inlet

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SG - B SPECIAL INTEREST +POINT RESULTS Braidwood 2 A2R13 CDE 20080401 05/07/2008 09:44:08

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B SPECIAL INTEREST +POINT RESULTS Braidwood 2 A2R13 CDE 20080401 05/07/2008 09:44:08

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5 Westinghouse Electdc Company LLC-ST Max 05/07/2008 09:31:58

SG - C SPECIAL INTEREST +POINT RESULTS Braidwood 2 A2R13 COE 20080401 05/07/2008 09:46:44

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C SPECIAL INTEREST +POINT RESULTS Braidwood 2 A2R13 CDE 20080401 05/07/2008 09:46:44

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C SPECIAL INTEREST +POINT RESULTS Braidwood 2 A2R13 CDE 20080401 05/07/2008 09:46:44

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170 3

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SG -

A FOREIGN OBJECT WEAR HISTORY Braedwood 2 A2R13 CDE 20080401

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SG - B FOREIGN OBJECT WEAR IN THE CURRENT AND/OR HISTORY Braidwood A2R13 CDE D5 X

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SG -

B FOREIGN OBJECT WEAR IN THE CURRENT AND/OR HISTORY Braldwood 2 A2R13 CDE 20080401 05/07/2008 14:36:12

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Tubes: 2 Records:

79

SG - C FOREIGN OBJECT WEAR IN THE CURRENT AND/OR HISTORY Braidwood A2R13 CDE D5 X

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85 NOD 11H TEH

.610 RBARH 49 HI 2003/11/01 3

85 NOD 11C 10H

.590 RBABJ 51 HI 2000/10/01 3

85 NOD TSH TSH

.610 ZPANM 21 HI 2000/10/01 3

85 NOD 11C TEC

.610 MBARH 64 CI 2000/10/01 3

85 NOD 110 TEH

.610 MBART 65 HI 1999/05/01 3

85 NOD TEC TEH

.610 MBALL 37 HI 1997/10/01 3

85 NOD 1

TSH TSH

.610 ZPSHF 66 HI 1997/10/01 3

85 NOD 1

TSH TSH

.610 ZPSHF 70 HI 1997/10/01 3

85 NOD I

TEC TEH

.610 EBALL 103 HI 1996/03/01 3

85 NOD 1

11H TEH

.610 EBALL 21 HI 1996/03/01 3

85 NOD 1

11C 09H

.590 EBAMB 31 HI 1996/03/01 3

85 NOD 1

11C TEC

.610 EBALL 38 Cl 1994/10/01 3

85 NOD 1

11H TEC

.610 EBAMB 22 CI 1994/10/01 3

85 NOD 1

11H TEH

.610 EBAMB 61 Hi 1993/03/01 3

85 NOD 1

11C TEH

.610 EBAMB 53 HI 1991/10/01 3

85 NOD 1

11H TSH

.610 ZBANM 53 HI 1991/10/01 3

85 NOD 1

11C TEH

.610 ZBANM 54 HI 1991/10/01 3

85 NOD 1

11H TEC

.610 EBAMB 75 CI 1990/04/01 3

85 NOD 1

11C TEH

.610 EBAMB 58 HI 1990/04/01 3

85 NOD 1

11C TEC

.610 EBAMB 62 CL

+-------------------------------------------+---+----+----+-----+--------+--------+

+

+

I INSPOATE ROW COL VOLTS DEG IND PER CHN LOCN INCHI INCH2 I

CRLEN CRWID CEG BEGT ENDT POIA PTYPE CAL Lf

+-----------------------------------------+---.4----+---+----+---+---------+

+-----+----------

+

Tubes: 1 Records: 28 1

SG - D FOREIGN OBJECT WEAR IN THE CURRENT AND/OR HISTORY Braidwood A2R13 CDE D5 X

I FOREIGN OBJECT WEAR a 25 PLUGGED TUBE 10 105 100 95 90 O(

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Westinghouse Electnc Company LLC - ST Max 05/07/2008 14:56:55

SG -

D Braldwood 2 A2R13 CDE 20080401 05/07/2008 14:55:19

+......+..+..+....+..

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I INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

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+-----------------------------------------+----+-------+----+-----+---+---+---+-----+

+------

31 48 NDD TEH TEH

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.26 94 DSS P1 01H

.41 TEC TEH

.610 ZBAZC 77 HI 31 48

.04 83 VOL P4 01H

.39 01H 01H

.610 ZPSNN 133 HI 31 48

.15 273 PCT 19 2

01H

.48

.19

.41 63 01H 01H

.610 ZPSNN 133 HI 2006/10/01 31 48

.20 95 DSS P1 01H

.47 TEC TEH

.610 ZBAZC 31 HI 2006/10/01 31 48 NDD TSH TSH

.610 ZPSNM 67 HI 2006/10/01 31 48

.15 99 VOL 2

01H

.42 01H 01H

.610 ZPSNM 83 HI 2006/10/01 31 48

.13 101 VOL 2

01H

.41 01H 01H

.610 ZPSNM 91 HI 2006/10/01 31 48

.14 244 PCT 19 2

01H

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.44 68 01H 01H

.610 ZPSNM 91 HI 2005/04/01 31 48

.18 103

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.41 TEC TEH

.610 ZBARH 37 HI 2005/04/01 31 48

.12 64 VOL 2

01H

.42 01H 01H

.610 ZPSNM 105 HI 2005/04/01 31 48

.19 100 PCT 19

.2 01H

.34

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.610 ZPSNM 111 HI 2005/04/01 31 48

.14 108 VOL 2

01H

.41 01H 01H

.610 ZPSNM 111 HI 2003/11/01 31 48

.22 90 DSS P1 01H

.44 TEH TEC

.610 RBARH 14 C0 2003/11/01 31 48

.13 118 VOL P1 01H

.44 01H 01H

.610 ZPSNM 55 HI 2003/11/01 31 48 PRC 01H 01H

.610 ZPSNH 57 HI 2003/11/01 31 48 PRC 01H 01H

.610 ZPSNH 63 HI 2003/11/01 31 48

.87 288 PCT 18 2

01H

.36 01H 01H

.610 ZPSNM 63 HI 2000/10/01 31 48 NOD TSH TSH

.610 ZPANM 11 Hi 2000/10/01 31 48

.40 47 0SS P1 01H

.47 TEH TEC

.610 MBARH 24 C1 I 1999/05/01 31 48

.23 108 DSS P1 01H

.46 TEH TEC

.610 MBALL.

26 C0 1997/10/01 31 48 NDD 1

TSH TSH

.610 ZPSHF 32 HI 1997/10/01 31 48 NDD 1

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.610 EBALL 72 C1 1996/03/01 31 48 NOD 1

TSH TSH

.610 Z3S3C 29 HI 1996/03/01 31 48 NOD 1

TEH TEC

.610 EBALL 42 HI 1993/03/01 31 48 NDD 1

TEC TEH

.610 EBAMB 23 HI 1991/10/01 31 48 NDD 1

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.610 EBAFH 26 HI 1990/04/01 31 48 NDD 1

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Tubes: 1 Records:

28

Attachment B.5 Tubes Containing Anti-Vibration Bar Wear

SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Largest Percent Indication Per Tube Braidwood A2R13 CDE D5 2 65 20% to 29%

3 35 30% to 39%

4 1 40% to 49%

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60 55 50 45 40 35 30 Westinghouse Electric Company LLC - ST Max 05/07/2008 07:42:04

SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R13 CODE 20080401 05/07/2008 07:20:57

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.610 ZBAZC 93 HI I.I 30 11

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.610 ZBAZC 73 HI 42 26

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.610 ZBAZC 79 HI I

31 38

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.610 ZBAZC 81 HI I

24 40

.85 0

PCT 11 P2 AVI

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.610 ZBAZC 81 HI I

39 18

.91 0

PCT 11 P2 AVi

.24 TEC TEH

.610 ZBAZC 91 HI I

47 72

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PCT 11 P2 AV3

.00 TEC TEH

.610 ZBAZC 89 HI I

I 39 78

.62 0

PCT 11 P2 AV2

-. 07 TEC TEH

.610 ZBAZC 93 HII 29 103

.93 0

PCT 11 P2 AV1

.05 TEC TEH

.610 ZBAZC 101 HI I

28 93

.78 0

PCT 12 P2 AV2

-. 13 TEC TEH

.610 ZBAZC 73 HII 43 72

.69 0

PCT 12 P2 AV3

.00 TEC TEH

.610 ZBAZC 91 HII 37 78

.71 0

PCT 12 P2 AV1

.00 TEC TEH

.610 ZBAZC 93 HII 37 82

.78 0

PCT 12 P2 AV3

-. 12 TEC TEH

.610 ZBAZC 93 HII 38 84

.83 0

PCT 12 P2 AV2

-. 25 TEC TEH

.610 ZBAZC 99 HII 38 90

.82 0

PCT 12 P2 AV2

-. 08 TEC TEH

.610 ZBAZC 99 HII 38 93

.83 0

PCT 12 P2 AV2

.00 TEC TEH

.610 ZBAZC 99 HII 24 97 1.02 0

PCT 12 P2 AV3

-. 02 TEC TEH

.610 ZBAZC 101 HII 28 105

.75 0

PCT 12 P2 AV2

.02 TEC TEH

.610 ZBACC 107 HII 33 13

.85 0

PCT 13 P2 AV3

-. 18 TEC TEH

.610 ZBAZC 73 HI I345

52.

.79 0

PCT 13 P2 AV2

-. 05 TEC TEH

.610 ZBAZC 85 HIi I

340 7

.77 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 79 HI I40 70

.77 0 PCT 13 P2 AV3

.00 TEC TEH

..610 ZBAZC 93 HI I

38 27

.76 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 77 HI I

41 30

.81 0

PCT 13 P2 AV2.

.00 TEC TEH

.610 ZBAZC 79 HI 30 39

.. 80 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC

.83 HI

~I 41 39 1.02 0

PCT 13 P2 AV3

.00 TEC TEH

.610 ZBAZC 81 HI 41 39

.98 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC

81.

HII 40 40

.79 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 83 HI

~I 49 41

.98 0

PCT 13 P2 AV1

.00 TEC TEH

.610 "ZBAZC 81 HI 41 52

.82 0

PCT 13 P2 AV2

-. 12 TEC TEH

.610 zBAzc 85 HIm I

45 52

.79 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 85 HI I

39 67

.73 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 89 Hl I

40 78

.77 0

PCT 13 P2 AV2

.00 TEC TEH

.610 ZBAZC 93 HI 40 78

.77 0

PCT 13 P2 AV3

.00 TEC TEH

.610 ZBAZC 93 HI I

41 82

.78 0

P ET 13 P2 AV N.00 TEC TEH N

10 ZBAZC 93 HLI 38 87

.66 0

PCT 13 P2

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.26 TEC TEH

.10 zBAzc 99 HI I

42 89 10

.06 0

PCT 13 P2 AV2

.07 TEC TEH

.610 ZBAZO 101 HI I

42 28

.81 0

PCT 14 P2 AV4

.00 TEC TEH

.616 ZBAZC 79 HI I

36.

30

.83 0

PCT 14 P2 AV2

.00 TEC TEH

.610 ZBAZC 79 HI IROW COL VOLTS DEG IND PER CHN LOON INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL Ll

...... *.... +.

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SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Braldwood 2 A2R13 CDE 20080401 05/07/2008 07:20:57

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.610 ZBAZC 81 HI I

45 61

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PCT 14 P2 AV4

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.610 ZBAZC 89 HI 45 61

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PCT 14 P2 AV1

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.610 ZBAZC 89 HI I

45 62

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PCT 14 P2 AV3

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.610 ZBAZC 89 HI I

32 73

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PCT 14 P2 AV4

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.610 ZBAZC 89 HI I

37 73

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PCT 14 P2 AV3

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.610 ZBAZC 89 HI 37 73

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PCT 14 P2 AV4

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.610 ZBAZC 89 HI 37 73

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PCT 14 P2 AV1

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.610 ZBAZC 89 HII 40 74

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PCT 14 P2 AV3

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.610 ZBAZC 91 HII I29 77

.82 0

PCT 14 P2 AV3

.00 TEC TEH

.610 ZBAZC 93 HI I

33 77

.84 0

PCT 14 P2 AV3

.00 TEC TEH

.610 ZBAZC 93 HI I

I 33 81

.87 0

PCT 14 P2 AV2

.00 TEC TEH

.610 ZBAZC 95 HI 0I 40 83

.86 0

PCT 14 P2 AV4

.00 TEC TEH

.610 ZBAZC 95 HII 35 90

.75 0

PCT 14 P2 AV2

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.610 ZBAZC 97 HI 1 35 90

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PCT 14 P2 AV2

.00 TEC TEH

.610 ZBAZC 97 HI 37 92

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POT 14 P2 AV3

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.610 ZBAZC 97 HII 41 93

.87 0

PCT 14 P2 AV2

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.610 ZBAZC 93 HII I

43 93

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PCT 14 P2 AV4

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.610 ZBAZC 93 HI I42 56

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POT 16 P2 AV4

.05 TEC TEN

.610 ZBAZO 85 HI 42 71

.85 0

PCT 14 P2 AV3

.00 TEC TEH

.610 ZBAZC 89 HI I

29 107

.88 0

PCT 14 P2 AV2

.00 TEC TEH

.610 ZBAZC 109 HII 28 3047

.93 0 PCT 15

• P2 AV2

-.21 TEC TEN

.610 ZBAZC 191 NI 27 106 1.00 0

PCT 14 P2 AV4

.00 TEC TEH

.610 ZBAZC 109 HI

~I 30 24 7

.92 0

PCT 15 P2 AV4

.10 TEC TEH

.610 ZBAZC 79 HII 38 24

.95 0

PCT 15 P2 AV2

.00 TEC TEH

.610 ZBAZC 79 HII 30 28

.92 0

PCT 15 P2 AV3

.00 TEO TEH

.610 ZBAZC 79 HI

~I 140, 38

.90 0

PCT 15 P2 AV2

.00 TEC TEH

.610 ZBAZC 83 Hl I45 82

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POT 15 P2 AV2

.00 TEC TEN

.610 ZBAZC 89 NI 43 84

.95 0

PCT 15 P2 AV2

-.05 TEC TEH

.610 ZBAZC 83 HI 43 86

.26 0

PCT 15 P2 AV2

.01 TEC TEH

.610 ZBAZC 89 HI 42 671

.94 0

PCT 15 P2 AVI

.18 TEC TEH

.610 ZBAZC 891 Hl 40 89

.89 0

POT 15 P2 AV3

.00 TEC TEH

.610 ZBAZC 89 HI 42 71

.85 0

PCT 15 P2 AV4

.00 TEC TEH

.610 ZBAZC 895 HI 340 73

.88 0

PCT 15 P2 AV4

-. 10 TEC.

TEH

.610 ZBAZC 893H 30 76

.93 0

PCT 15 P2 AV2

-.21 TEC TEH

.610 ZBAZC 91 HI 37 76

.97 0

PCT 15 P2 AV2

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.610 ZBAZC 95 Hl 39' 76

.94 0

PCT 15 P2 AV1

-. 105 TEC TEH

.610 ZBAZC 93 HI 29 77 1.94 0

PCT 15 P2 AV21

.08 TEC TEH

.610 ZBAZC 93 HI 29 70 8

.91 0

PCT 15 P2 AV3

.00 TEC TEH

.610 ZBAZC 95 HI I

40 89

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PCT 15 P2 AV2

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.610 ZBAZC 95 HI 39 95

+-

PCT--15-P2+----+

+--+

+

+-.610---+----9-+

+

I ROW COL VOLTS DEG IND PER CHN LOCN INCHI INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL Ll

+.

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2

SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R13 CDE 20080401 05/07/2008 07:20:57

.+---...

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+-----+-----+-

+

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42 89

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.610 ZBAZC 95 HI 39 90

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.610 ZBAZC 93 HII 33 94

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.610 ZBAZC 97 HII 34

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PCT 15 P2 AV3

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.610 ZBAZC 99 HII 29 104 1.08 0

PCT 15 P2 AVi

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.610 ZBAZC 109 HI I

26 8

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PCT 16 P2 AV2

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.610 ZBAZC 75 HII 29 12 1.05 0

PCT 16 P2 AV3

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.610 ZBAZC 75 HI I

39 21 1.01 0

PCT 16 P2 AV4

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.610 ZBAZC 77 HII 40 24

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PCT 16 P2 AV3

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.610 ZBAZC 79 HII 38 23 1.02 0

PCT 16 P2 AV2

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.610 ZBAZC 79 HI I34 39 1.301 0 PCT 16 P2 AV4

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.610 ZBAZC 81 HI I

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PCT 16 P2 AV4

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.610 ZBAZC 91 HI I

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.610 ZBAZC 91 HI I40 68 1.97 0 PCT 16 P2 AV3

-.07 TEC TEH

.610 ZBAZC 91 HI I

1 3297 1.930 0

PCT 16 P2 AV3

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.610 ZBAZC*

89 Hi I

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PCT 16 P2 AV3

.07 TEC TEH

.610 ZBAZC 91 HI I

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.610 ZBAZC 93 HI I

I 2 738

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PCT 16 P2 AV3

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.610 ZBAZC 95 HI I34 79

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.610 Z8AZC 895 HI I

I3 73

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PCT 16 P2 AV2

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.610 ZBAZC 89 HI 3I 78 1.09 0

PCT 16 P2 AV3

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.610 ZBAZC 93 HI I

I4 78 1.02 0

PCT 16 P2 AV3

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.610 ZBAZC 93 HI I

41 79

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PCT 16 P2 AV3

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.610 ZBAZC 95 HI I

I 37 81 1.03 0

PCT 16 P2 AV3

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.610 ZBAZC 95 HI 37 82 1.09 0

PCT 16 P2 AVi

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.610 ZBAZC 93 HI 40 84 1.02 0 PCT 16 P2 AV3

-. 15 TEC TEH

.610 ZBAZC 93 Hi 36 87

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PCT 16 P2 AV3

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42 1.24 1.41 1.41 1.43 1.21 1.47 1.49 1.43 1.54 1.50 1.35 1.55 1.31 1.58 1.32 1.36 1.60 1.32 PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT PCT POT PCT PCT PCT PCT PCT POT PCT PCT PCT PCT PCT PCT PCT 18 18 18 18 18 18 18 18 18 19 19 19 19 19 19 19 19 19 19 19 19 19 19 19 20 20 20 20 20 20 20 20 20 20 20 20 20 20 21 21 P2 AV4 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV4 P2 AV4 P2 AV3 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AVi P2 AV3 P2 *AV3 P2 AV2 P2 AVi P2 AV3 P2 AV3 P2 AV2 P2 AV4 P2 AV3 P2 AV2 P2 AV3 P2 AV4 P2 AV1 P2 AV4 P2 AV3 P2 AVi P2 AVi P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2ý AV2 P2 AV2 P2.

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0 Rcod Tubes: 100 Records: 163 5

Attachment B.6 Tubes Containing Pre-heater Wear

SG - B PREHEATER WEAR INDICATIONS Braidwood A2R13 CDE D5 X

3 TUBE WITH WEAR INDICATION o 49 PLUGGED TUBE 110 105 100 95 90 85 80 75 I

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SG - C PREHEATER WEAR INDICATIONS Braidwood A2R13 CDE D5 X

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5 1

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SG - D Preheater Wear Indications Braidwood 2 A2R13 CDE 20080401 05/07/2008 10:10:03

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Attachment B.7 Tubes that Potentially Contain Higher Residual Stress

SG - A,-,UBES POTENTIALLY MORE SUSCEPTIýLF TO ODSCC Braidwood A.-13 CDE D5 X 12 POTENTIALLY MORE SUSCEPTIBLE TO ODS.CC a 66 PLUGGED TUBE 45 35 25, 110 105 100 95 90 85 80 75 O

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32 1

SG - B >TIUBES POTENTIALLY MORE SUSCEPTIB)--E TO ODSCC BraidwoodAe-,,12 CDE D5 X 16 TUBE POTENTIALLY MORE SUSCEPTI-BLE TO ODSCC a 48 PLUGGED TUBE 45 40 35 25 20 15 10 5

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Tubes: 16 Records:

38 1

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SG-D j1JBES POTENTIALLY MORE SUSCEPTIBLFTO ODSCC Braidwood A2,-13 CDE D5

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Tubes: 28 Records: 61 2

Attachment B.8 Tubes Containing Indications within the Tubesheet

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TEH 2

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TEH P1 TEH 2

TEH P1 TEH 2

TEH 2

TEH P1 TEH 2

TEH P1 TEH P1 TEH 2

TEH 2

TEH P1 TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH PI TEH P1 TEH 2

TEH P1 TEH 2

TEH 2

TEH

.03

.06

.14

.04

.08

.00

.06

.07

.06

.06

.11

.02

.04

.05

.01

.09

.07

.15

.00

.00

.02

.05

.00

.10

.07

.02

.03

.05

.00

.00

.00

.00

.00

.00

.00

.00

.14

.00

.00

.20

.00

.00

.07

.08

.00

.09

.15

.15

.09

.09

.15

.11

.10

.16

<16

.17

.11

.18

.11

.06

.18

.11

.14

.13

.11

.14

.16

.11

.12

.11

.17

.21

.14

.11

.20

.20

.14

.14

.14

.11

.23

.16

.16

.14

.18

.11

.11

.09

.14

.11

.14

.09

.15

.15

.18

.18

.16

.16

.20

.20

.15

.15

.12

.12

.15

.15

.18

.18

.29

.15

.21

.21

.21

.21

.32

.12

.12

.21

.21

.21

.19

.12

.19

.11

.16

.16

.50 77 TEH TEH

.27 42 TEH TEH

.22 34 TEH TEH

.33 50 TEH TEH

.25 39 TEH TEH

.18 27 TEH TSH

.43 66 TEH TEH

.34 51 TEH TEH

.98 149 TEH TEH

.39 59 TEH TEH

.84 129 TEH TEH

.21 32 TEH TEH

.49 76 TEH TEH

.25 39 TEH TEH

.32 48 TEH TEH

.84 129 TEH TEH

.37 56 TEH TEH

.34 51 TEH TEH 1.38 211 TEH TSH

.35 53 TEH TEH

.36 55 TEH TEH

.54 82 TEH TEH

.17 26 TEH TSH

.55 84 TEH TEH

.45 69 TEH TEH

.49 76 TEH TEH

.44 67 TEH TEH

.33 50 TEH TEH

.40 61 TEH TEH

.44 67 TEH TEH

.19 29 TEH TSH

.28 43 TEH TSH

.43 66 TEH TEH

.43 66 TEH TEH

.28 43 TEH TEH 1.24 190 TEH TEH

.44 68 TEH TEH

.53 80 TEH TEH

.35 53 TEH TEH

.45 69 TEH TEH

.49 76 TEH TEH

.34 51 TEH TEH

.20 31 TEH TEH

.33 50 TEH TEH

.16 24 TEH TSH

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN 35 35 35 31 25 29 7

25 25 25 25 25 25 25 25 25 25 25 25 7

25 25 25 7

25 25 25 25 27 21 21 7

7 21 21 21 21 21 21 21 21 21 21 21 25 7

HI I

HI I

HI NI NI NI NI NI NI NI NI NI NI NI NI NI NI NI NI NI NI NI HI NI NI NI NI NI I

HI NI NI HI I

HI NI HI NI HI I

HI I

HI I

HI HI HI HI I

HI HI HI HI HI-HI HI HI I

HI HI HI HI HI HI HI HI I

HI HI HI HI

+.... -

+.

+.

+....

+....

+....

+....

+

+.

+

-+

+.

+

+..

+.

+.

+.

-+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

+.........+....+....+....+....+....--+......+...+....+....+--+..+..+.

1

SG - A PWSCC Indications Braidwood 2 A2R13 COE 20080401 07/17/2008 15:07:43

+...

+

. +

+

+

+---.

+--+-.......+

+.--+----+----+-

-+

+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

.... +..

+....

+....

+....

+....

+....

+.

+-

+

+.--

+....

+

+...

.+...----+

+

_ +

+

1 40 6.16 25 SAS 2

TEH 00

.18

.18

.41 63 TEH TEH

.610 ZPSNM 21 HI 1

40 3.60 39 SAS 2

TEH 00

.18

.18

.38 58 TEH TEH

.610 ZPSNM 21 HN 1

40 4.51 40 SCS Pl TEH

.03

.18

.15

.34 51 TEH TEH

.610 ZPSNM 21 HII 1

41 7.51 42 SAS 2

TEH

.00

.24

.24

.41 63 TEH TEH

.610 ZPSNM 21 HI 1

41 9.76 34 SAS 2

TEH

.00

.21

.21

.28 43 TEH TEH

.610 ZPSNM 21 HI 1

41 10.20 39 SCS P1 TEH

.07

.34

.27

.50 77 TEH TEH

.610 ZPSNM 21 HII 1

42 4.55 36 SCS P1 TEH

.04

.13

.09

.50 77 TEH TSH

.610 ZPSNM 1

HII 1

43 1.48 22 SAS 2

TEH

.00

.16

.16

.17 26 TEH TSH

.610 ZPSNM 1

HII 4

43 2.17 24 SAS 2

TEH

.00

.15

.15

.15 22 TEH TSH

.610 ZPSNN 3

HNI 6

43 1.30 40 SCS P1 TEH

.04

.16

.12

.26 40 TEH TSH

.610 ZPSNN 3

HI 6

43

.94 43 SCS P1 TEH

.05

.17

.12

.23 35 TEH TSH

.610 ZPSNN 3

HII 1

44 10.06 38 SCI P1 TEH

.00

.12

.12

.67 103 TEH TEH

.610 ZPSNM 21 HI 1

44 5.12 32 SAS 2

TEH

.00

.15

.15

.60 92 TEH TEH

.610 ZPSNM 21 HII 10 44 4.68 37 SAS 2

TEH

.00

.18

.18

.34 51 TEH TEH

.610 ZPSNM 21 HII 19 44 1.92 28 SAS 2

TEH

.20

.35

.15

.58 88 TEH TEH

.610 ZPSNM 21 HII 1

45 3.91 52 MCI P1 TEH

.00

.12

.12

.80 122 TEH TEH

.610 ZPSNM 21 HII 1

46 2.52 211 MCI P1 TEH

.00

.12

.12

.72 109 TEH TEH

.610 ZPSNM 21 HII 5

46 2.54 30 SAS 2

TEH

.00

.12

.12

.23 35 TEH TEH

.610 ZPSNM 21 HII 14 46 1.92 29 SAS 2

TEH

.00

.18

.18

.28 43 TEH TEH

.610 ZPSNM 21 HI 14 46 1.21 27 SAS 2

TEH

.21

.36

.15

.33 50 TEH TEH

.610 ZPSNM 21 HI I

I1 47 7.84 27 SAS 2

TEH

.00

.21

.21

.24 37 TEH TEH

.610 ZPSNM 21 HI 1

47 5.99 44 SCI P1 TEH

.15

.36

.21

.54 82 TEH TEH

.610 ZPSNM 21 HI 1

47

.59 38 SCI P1 TEH

.20

.32

.12

.28 43 TEH TEH

.610 ZPSNM 21 HII 2

47 8.30 35 SAS 2

TEH

.05

.20

.15

.35 53 TEH TEH

.610 ZPSNN 23 HII 1

48 3.05 28 SAS 2

TEH

.07

.19

.12

,47 72 TEH TEH

.610 ZPSNM 21 HI 1

48

.91 46 MCS P1 TEH

.18

.27

.09

.47 72 TEH TEH

.610 ZPSNM 21 HII 1

49.

2.99 35 SAS 2

TEH

.00

.18

.18

.27 42 TEH TEH

.610 ZPSNM 21 HI 1

49 6.37 29 SAS 2

TEH

.00

.18

.18

.40 61 TEH TEH

.610 ZPSNM 21 HI 1

49 1.32 40 SCS P1 TEH

.06

.15

.09

.18 27 TEH TEH

.610 ZPSNM 21 HI 1

50 5.44 25 SAS 2

TEH

.00

.16

.16

.22 34 TEH TSH

.610 ZPSNM 1

HI 5

51 1.81 23 SAS 2

TEH

.00

.12

.12

.18 27 TEH TSH

.610 ZPSNN 3

HI 28 51 3.34 31 SAS 2

TEH

.00

.16

.16

.18 27 TEH TSH

.610 ZPSNM 9

HI 37 51 1.62 30 SCS P1 TEH

.00

.19

.19

.32 48 TEH TSH

.610 ZPSNM 9

HN 3

52 1.42 17 SAS 2

TEH

.00

.12

.12

.24 37 TEH TEH

.610 ZPSNN 23 HI 29 53

.66 32 SAS 2

TEH

.04

.13

.09

.40 61 TEH TEH

.610 ZPSNN 27 HI

21.

55 1.61 33 SCS P1 TEH

.05

.17

.12

.20 31 TEH TSH

.610 ZPSNN

.3 HI 29 55 1.88 27 SAS 2

TEH

.12

.24

.12

.42 64 TEH TSH

.610 ZPSNN 11 HII 19 56 3.04 28 SAS 2

TEH

.00

.18

.18

.17 26 TEH TSH

.610 ZPSNN 3

HII 31 56 5.58 36 SAS 2

TEH

.00

.19

.19

.21 32 TEH TSH

.610 ZPSNM 9

HI 19 59 3.53 33 SAS 2

TEH

.06

.16

.09

.36 55 TEH TEH

.610 ZPSNM 55 HI 6

60 1.71 24 SAS 2

TEH

.17

.27

.12

.29 45 TEH TSH

.610 ZPSNN 43 HI 27 61 4.14 33 SAS 2

TEH

.02

.17

.15

.32 48 TEH TEH

.610 ZPSNM 37 HI 2

62 5.63 31 SAS 2

TEH

.08

.24

.16

.48 74 TEH TSH

.610 ZPSNN 43 HI 25 62 3.36 35 SAS 2

TEH

.09

.30

.20

.33 50 TEH TEH

.610 ZPSNM 37 HI 32 62 4.32 38 SAS 2

TEH

.02

.14

.12

.32 48 TEH TEH

.610 ZPSNM 37 HI 2

63 3.77 30 SAS 2

TEH

.09

.22

.12

.32 48 TEH TEH

.610 ZPSNM 55 HI

+....

..+......-.

+_._-

+

.---.----+....+

+....

+..

-+.....

... +.......

+....+....

+......

+......-

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL Ll

+....+....+....+....+....

.+..-

+

+....-+....+.+

.+.

SG - A PWSCC Indications Braidwood 2 A2R13 COE 20080401 07/17/2008 15:07:43

+.

+.

+..

+

+

+

+--------+....-+-....-+

+-----

+

+..-

.+.----

+---- -+

+-..

+.-....

+-

+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

.÷

-÷

÷

÷-

-÷ 4

19 24 6

18 20 19 1

5 16 1

6 1

35 4

5 1

1 1

5 10 15 5

2 23 23 32 1

1 2

2 8

38 1

1 15 1

64 66 68 69 71 71 72 73 73 73 74 74 75 75 76 76 77 77 79 79 79 79 80 81 81 81 81 82 82 82 82 82 82 83 84 85 87 5.26 29 SAS 2

TEH

.07 3.62

.94 2.33 1.85 3.30 3.22 3.53 5.61 2.23 3.34 4.12 8.20 1.32 3.36 2.15.

2.81 5.74 5.93 4.53 3.31 6.88 1.79 5.96 2.15 1.47 1.73 2.55 3.28 5.35 3.07 1.69 2.70 2.67 6.89

.87 6.97 30 SAS 30 SAS 32 SAS 26 SAS 28 SAS 30 SAS 21 SAS 34 SAS 31 SAS 35 MCI 30 SAS 36 SCI 26 SAS 37 SAS 26 SAS 21 SAS 32 SCS 215 SCI 28 SAS 31 SCI 37 SAS 24 SAS 32 SAS 26 SAS 25 SAS 23 SAS 23 SAS 29 SCS 39 SAS 32 SAS 27 SAS 27 SAS 21 MCS 38 MCI 24 SAS 36 MCI 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH P1 TEH 2

TEH PI. TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH P1 TEH 2

TEH P1 TEH

.29

.06

.11

.21

.28

.08

.03

.06

.27

.07

.00

.03

.30

.24

.00

.00

.07

.06

.01

.02

.13

.00

.01

.28

.29

.26

.00

.10

.20

.25

.28

.23

.09

.10

.23

.09

.26

.19

.27 42 TEH TSH

.610 ZPSNN 43 HI

.41

.12

.34 51 TEH TEH

.610 ZPSNN 57 HI

.15

.09

.35 53 TEH TEH

.610 ZPSNN 39 Hi

.24

.13

.39 59 TEH TEH

.610 ZPSNM 59 HI

.31

.10

.34 51 TEH TSH

.610 ZPSNM 13 HI

.42

.14

.35 53 TEH TEH

.610 ZPSNN 53 HI

.21

.12

.40 61 TEH TSH

.610 ZPSNN 15 HI

.19

.16

.44 67 TEH TEH

.610 ZPSNN 61 HI

.32

.26

.32 48 TEH TSH

.610 ZPSNM 13 HI

.39

.14

.31 47 TEH TEH

.610 ZPSNN 53 Hi

.19

.81 124 TEH TEH

.610 ZPSNN 61 HI

.16

.16

.35 53 TEH TEH

.610 ZPSNN 61 HI

.16

.65 100 TEH TEH

.610 ZPSNN 61 HI

.41

.17

.29 45 TEH TEH

.610 ZPSNN 53 HI

.44

.19

.29 45 TEH TEH

.610 ZPSNN 61 HI

.16

.16

.23 35 TEH TEH

.610 ZPSNN 61 HI

.16

.16

.21 32 TEH TEH

.610 ZPSNN 61 HI

.13

.36 55 TEH TEH

.610 ZPSNN 61 HI

.16

.76 116 TEH TEH

.610 ZPSNN 61 HI

.17

.16

.26 40 TEH TSH

.610 ZPSNM 13 HII

.10

.65 100 TEH TEH

.610 ZPSNM 59 HI

.39

.26

.60 92 TEH TSH

.610

-ZPSNM 13 HI

.16

.16

.19 29 TEH TEH

.610 ZPSNN 61 HI

.14

.13

.56 85 TEH TSH

.610 ZPSNM 13 HI

.44

.16

.31 47 TEH TSH

.610 ZPSNM 9

HI

.45

.16

.26 40 TEH TSH

.610 ZPSNM 9

HI

.38

.12

.60 92 TEH TSH

.610 ZPSNN 11 HI

.12

.16

.27 42 TEH TEH

.610 ZPSNN 61 HI

.13

.35 53 TEH TEH

.610 ZPSNN 61 HI

.48

.28

.66 101 TEH TEH

.610 ZPSNN 61 HI

.48

.22

.25 39 TEH TEH

.610 ZPSNN 61 HI

.50

.22

.58 88 TEH TEH

.610 ZPSNN 61 HI

.41

.18

.41 63 TEH TEH

.610 ZPSNM 51 HI

.13

.44 67 TEH TEH

.610 ZPSNN 61 HI

• .19

.64 98 *TEH TEH

.610 ZPSNN 61 HI

.34

.12

.47 72 TEH TSH

.610 ZPSNN 11 HI

.16 1.02 156 TEH TEH

.610 ZPSNN 61 HI I

.39

.16

.33 50 TEH TSH

.610 ZPSNM 9

HI

.33

.16

.32 48 TEH TSH

. 610 ZPSNM 9

HI I

.13

.98 149 TEH TEH

.610 ZPSNN 61 HII

.13

.32 48 TEH TEH

.610 ZPSNN 61 HI

.13

.86 132 TEH TEH

.610 ZPSNN 61 Hl I

+..+.-

+.....

+.-..+

+....+

-++....÷....

+

INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI 3

+

+

....+

+....+

.+.+.

29 87 3.46 28 SAS 2

TEH

.23 33 87 2.50 25 SAS 2

TEH

.17 1

88 12.01 38 SCI.

P1 TEH

.11 3

88 4.46 37 SCS P1 TEH

.10 1

89 8.33 44 MCI P1 TEH

.16

+----.----- -----

+.

.+..

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1

+-....

+

+-....

+....+.

SG -

A PWSCC Indications Braidwood 2 A2R13 CDE 20080401 07/17/2008 15:07:43

+ - - -------------

-+

+

+

I ROW COL VOLTS DEG IND PER CHN LOCN INCH1

-+

+

+

+-..

-+

+-...

+

+

+-

-+- --

INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

+--+-......+......-.+.----

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27 33 33 3

17 3

25 1

1 5

6 7

3 89 89 89 90 90 92 93 94 94 95 95 95 97 1.93 31 SAS 2

TEH

.02

.17

.15

.28 43 TEH TEH

.610 ZPSNN 1.10

.57 5.05 1.60 5.87 3.49 6.64 4.28 2.79 3.31 2.73 1.92 20 SAS 21 SAS 29 SAS 26 SAS 25 SAS 29 SAS 32 SAS 32 SCS 29 SAS 32 SAS 27 SAS 24 SAS 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH

_+ _ --.

.+

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.25

.40

.18

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.40

.15

.00

.16

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.25

.37

.12

.00

.19

.19

.00

.12

.12

.00

.19

.19

.06

.16

.00

.16

.16

.00

.13

.13

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.13

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+. -. +-...

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.610 ZPSNN 58 TEH TEH

.610 ZPSNN 56 TEH TEH

.610 ZPSNN 29 TEH TEH

.610 ZPSNN 55 TEH TSH

.610 ZPSNN 71 TEH TEH

.610 ZPSNN 50 TEH TEH

.610 ZPSNN 56 TEH TEH

.610 ZPSNN 40 TEH TEH

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.610 ZPSNN 29 TEH TEH

.610 ZPSNN 93 TEH TEH

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+

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+.

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VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE

+.

.+

+----.

+

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-÷ Tubes: 118 Records: 148 4

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Westinghouse Electrc Company LLC - ST Max 07/1712008 15:19:12

SG -

B PWSCC Indications Braidwood 2 A2R13 CDE 20080401 07/17/2008 15:07:40

+

+-..--.----+ +

+

+

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+.

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I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

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11 22 1.70 59 SCS P1 TEH

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.610 ZPSNM 57 HII 2

28 4.42 26 SAS 2

TEH.

.03

.21

.18

.46 71 TEH TSH

.610 ZPSNN 11 HII 2

30 2.04 32 SAS 2

TEH

'.00

.15

.18

.25 39 TEH TEH

.610 ZPSNN 55 HI I

1 36 2.03 19 SAS 2

TEH

.00

.12

.12

.16 24 TEH TEH

.610 ZPSNN 57 HII 2 1 39 1.98 31 SAS 2

TEH

.00

.12

.12

.14 21 TEH TEH

.610 ZPSNN 55 HI I

I 1

40 2.13 26 SAS 2

TEH

.00

.12

.12

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.610 ZPSNM 57 HI I

1 42 2.18 29 SAS 2

TEH

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.12

.12

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HII 1

48 2.51 23 SAS 2

TEH

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.12

.12

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.610 ZPSNM 53 HII 10 59 3.78 29 SAS 2

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65 4.31 25 SAS 2

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.17

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74 2.74 27 SAS 2

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Tubes: 25 Records: 25

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SG -

C PWSCC Indications Braidwood 2 A2R13 CDE 20080401 07/17/2008 15:07:41 I ROW COL

+ -- --

+ --. -+

+

+

+-

+-

+

-+--------------

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VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI 4--

.+-

1 18 3.42 24 SAS 19 23 24 25 28 28 32 32 33 35 38 39 42 43 43 45 45 45 46 46 46 46 46 46 47 47 47 47 48 49 49 49 49 50 50 50 50 51 51 52 53 2.25 2.90 4.24 3.37 2.28 1.84 2.40 1.35 1.14 1.16 2.78 1.40 2.89 3.02 1.68 1.88 3.05 2.26 2.95 3.10 3.58 1.67 2.06 2.56 2.30 2.42 2.84 1.81

.70 4.52 3.12 4.01 2.27 1.03 1.64

.78 2.24 2.42 2.71 3.38 2.67 18 SAS 19 SAS 25 SAS 19 SAS 18 SAS 22 SAS 19 SAS 21 SAS 18 SAS 19 SAS 25 SAS 20 SAS 21 SAS 19 SAS 21 SAS 20 SAS 21 SAS 24 SAS 28 SAS 26 SAS 28 SAS 19 SAS 17 SAS 24 SAS 22 SAS 18 SAS 17 SAS 18 SAS 19 SAS 22 SAS 25 SAS 24 SAS 25 SAS 16 SAS 20 SAS 20 SAS 20 SAS 22 SAS 20 SAS 25 SAS 18 SAS 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

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2 TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

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TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2 TEH 2

TEH

.00

.00

.06

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.00

.00

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.00

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.05

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.06

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.05

.06

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.00

.00

.00

.01

.06

.00

.00

.03

.10

.04

.09

.00

.00

.29

.02

.05

.03

.01

.04

.00

.15

.15

.32 48 TEC TEH

.05

.18

.19

.23

.15

.18

.23

.05

.12

.18

.10

.21

.19

.15

.15

.12

.17

.21

.21

.22

.12

.12

.19

.12

.16

.21

.16

.19

.23

.19

.19

.18

.22

.16

.38

.14

.16

.15

.13

.16

.12

.18

.13

.21

.15

.18

.21

.12

.12

.09

.15

.09

.14

.14

.15

.15

.12

.11

.15

.15

.15

.12

.12

.19

.12

.14

.15

.16

.19

.20

.09

.14

.09

.22

.16

.12

.12

.09

.12

.12

.12

.22

.32

.32

.33

.23

.24

.40

.16

.16

.32

.43

.29

.44

.44

.19

.18

.14

.35

.35

.48

.26

.18

.17

.17

.39

.34

.31

.46

.23

.28"

.42

.33

.33

.18

.15

.61

.29

.35

.38

.32

.41 34 TEH TEH 48 TEH TEH 48 TEH TEH 50 TEH TEH 35 TEH TEH 37 TEH TSH 61 TEH TSH 24 TEH TSH 24 TEH TSH 48 TEC TEH 66 TEH TSH 45 TEH TEH 67 TEH TEH 67 TEH TEH 29 TEH TEH 27 TEH TSH 21 TEH TSH 53 TEH TEH 53 TEH TSH 74 TEH TSH 40 TEH TSH 27 TEH TSH 26 TEH TSH 26 TEH TSH 59 TEH TEH 51 TEH TEH 47 TEH TEH 71 TEH TEH 35 TEH TSH 43 TEH TEH 64 TEH TSH 50 TEH TEH 50 TEH TEH 27 TEH TSH 22 TEH TSH 93 TEH TSH 45 TEH TEH 53 TEH TEH 58 TEH TEH 48 TEH TEH 63 TEH TEH

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

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.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

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.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM 83 HI 83 HI 83 HI 81 HI 83 HI 87 HI 7

HI S I 5

HI 7

HI 7

H NI 87 HI S I 5

HI 53 HI 45 HI 43 HI 35 HI 3

HI 3

HI 39 HI 3

HI 3

HI 3

HI 21 HI 21 HI 3

HI 43 HI 43 HI 43 HI 21 HI 3

HI 43 Hi 15 HI 43 HI.

45 HI 3

HI 3

HI 3

HI 53 I

43 HI 43 HI 45 HI 43 HI CAL LI I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE

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SG - C PWSCC Indications Braidwood 2 A2R13 CDE 20080401 07/17/2008 15:07:41

+.... -

+-

+- -+

+

+-....

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I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL Ll

4.

4.

4...

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.+

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18 53 2.61 21 SAS 16 8

24 2

13 18 1

2 1

1 6

8 2

3 30 2

6 18 17 2

41 42 13 20 1

20 2

9 21 14 18 21 22 1

4 19 21 20 1

4 54 55 55 56 56 56 57 57 59 59 59 60 61 62 62 63 63 63 64 65 65 65 66 66 67 68 69 69 69 70 70 70 70 71 71 71 71 72 73 73 3.09 2.16 2.78 2.67 2.33 2.79 2.41 3.21 2.92 5.21 2.15 2.38 1.33 1.81 1.61 1.50 3.10 3.00 2.97 2.23 2.71 1.42 4.46 2.47 1.61 3.45 2.19 2.64 2.87 2.36 1.35 4.93 2.56 5.48 2.24 2.37 3.07 2.20 3.52 22 SAS 18 SAS 18 SAS 32 SAS 23 SAS 20 SAS 35 SAS 33 SAS 29 SAS 39 SAS 26 SAS 18 SAS 30 SAS 27 SAS 24 SAS 25 SAS 19 SAS 23 SAS 26 SAS 26 MCS 23 SAS 22 SAS 22 SAS 30 SAS 27 SAS 27 SAS 19 SAS 22 SAS 23 SAS 23 SAS 19 SAS 26 SAS 22 SAS 29 SAS 24 SAS 23 SAS 25 SAS 25 SAS 24 SAS 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH

2. TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH

.03

.15

.12

.32 48 TEH TEH

.06

.02

.00

.06

.04

.07

.08

.10

.00

.00

.00

.00

.11

.00

.07

.10

.00

.08

.02

.08

.05

.05

.00

.04

.01

.06

.10

.00

.06

.01

.03

.08

.13

.03

.02

.07

.01

.01

.06

.18

.14 15

.18

.24

.19

.19

.21

.23

.32

.15

.12

.23

.15

.14

.25

.20

.16

.14

.20

.17

.18

.16

.11

.21

.22

.15

.18

.16

.15

.24

.25

.24

.15

.15

.10

.07

.25

.12

.12

.15

.12

.20

.12

.11

.11

.23

.32

.15

.12

.12

.15

.06

.15

.20

.08

.11

.12

.15

.12

.18

.12

.09

.15

.12

.15

.12

.15

.12

.18

.12

.21

.12

.08

.08

.06

.22

.74

.34

.20

.45

.37

.35

.36

.40

.27

.29

.22

.18

.48

.24

.35

.42

.23

.40

.35

.48 46

.25

.27

.33

.28

.36

.33

.27

.33

.43

.34

.45

.29 1.06

.31

.34

.39

.32

.37 112 TEH TEH 51 TEH TEH 31 TEH TSH 69 TEH TEH 56 TEH TEH 53 TEH TEH 55 TEH TEH 61 TEH TEH 42 TEH TSH 45 TEH TSH 34 TEH TSH 27 TEH TSH 74 TEH TSH 37 TEH TSH 53 TEH TSH 64 TEH TSH 35 TEH TSH 61 TEH TSH 53 TEH.

TSH 74 TEH TSH 71 TEH TEH 39 TEH TEH 42 TEH TSH 50 TEH TEH 43 TEH TSH 55 TEH TEH 50 TEH TEH 42 TEH TSH 50 TEH TEH 66 TEH TEH 51 TEH TEH 69 TEH TEH 45 TEH TSH 162 TEH TEH 47 TEH TSH 51 TEH.

TSH 59 TEH TSH 48 TEH TSH 56 TEH TSH

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN.

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN

.610 ZPSNM

.610 ZPSNM

.610 ZPSNM

.610 ZPSNN

.610 ZPSNN 43 HI 45 H

43 NI 3

H 45 H

45 H

45 H

47 HI 49 HI 59 HI 59 HI 57 HI 59 HI 63 HI NI 61 HI 9

HI 63 HI 59 HI 19 HI

.19 HI 63 HI 65 HI 65 HI 57 HI 67 HI 63 HI 67 HI 65 HI 57 HI 65 HI 67 HI 67 HI 67 HI 17 HI 67 HI 63 HI 19 HI 19 HI 17 HI 63 I

63 HI 2.31 28 SAS

.03

.15 1.12

.66 101 TEH TSH

+.... -

-+ - ---

+

+

+ ---

+

+-

-+

+

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I ROW COL VOLTS DEG IND PER CHN LOCN INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

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+

2

SG - C PWSCC Indications Braidwood 2 A2R13 I ROW COL VOLTS DEG IND PER CHN LOCN CDE 20080401 07/17/2008 15:07:41

--+-

+. -

+

+

+

+

+

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INCH1 INCH2 I

CRLEN CRWID CEG BEGT ENDT PDIA PTYPE CAL LI

-÷

+....-

-+-

.+

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17 2

4 40 20 20 6

6 1

2 6

1 5

6 14 1

2 1

14 14 25 1

6 15 15 15 3

3 4

11 1

3 2

4 3

1 5

3 1

3 9

9 73 74 74 74 75 75 76 76 77 77 77 81 81 82 82 84 85 86 87 87 87 88 89 89 89 89 90 90 90 90 91 93 94 96 98 99 100 103 106 106 106 107 3.56 3.16 2.86 1.62 2.34 4.17 4.48 2.07 2.94 3.31 2.04 4.52 1.80 1.99 3.31 1.30 2.72 2.02 1.09 1.41 2.88 3.39 1.22

.69

.89 2.39 1.95 1.04 2.60 1.61 2.44

.2.24 1.64 1.92 1.16 3.01 1.97 3.02 4.35 3.23 4.33 3.22 22 SAS 22 SAS 28 SAS 15 SAS 23 SAS 25 SAS 26 SAS 22 SAS 23 SCS 24 SAS 30 SAS 27 SAS 21 SAS 24 SAS 22 SAS 14 SAS 23 SAS 22 SAS 22 SAS 9

SAS 18 SAS 21 SAS 19 SAS 18 SAS 18 SAS 30 SAS 24 SAS 20 SAS 25 SAS 17 SAS 20 SAS 19 SAS 17 SAS 22 SAS 21 SAS 18 SAS 22 SAS 21 SAS 23 SAS 24 SAS 28 SAS 29 SAS 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH P1 TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

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TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH 2

TEH

.02

.00

.06

.08

.04

.04

.05

.07

.07

.02

.10

.05

.04

.12

.11

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.06

.02

.00

.00

.11

.01

.00

.15

.17

.18

.06

.15

.00

.00

.00

.07

.01

.02

.05

.03

.08

.02

.00

.05

.04

.02

.11

.16

.18

.20

.15

.15

.17

.13

.18

.25

.24

.16

.24

.26

.12

.18

.14

.12

.12

.20

.16

.12

.24

.26

.40

.28

.31

.14

.12

.12

.31

.14

.14

.17

.23

.21

.15

.19

.20

.11

.15

.08

.16

.12

.12

.11

.11

.12

.06

.12

.12

.15

.21

.12

.12

.15

.12

.12

.12

.12

.12

.09

.15

.12

.09

.09

.22

.22

.16

.14

.12

.12

.24

.12

.12

.12

.19

.12

.13

.19

.15

.16

.13

.49

.20

.43

.35

.33

.33

.60

.36

.39

.36

.38

.45

.29

.34

.42

.13

.35 34

.21

.16

.35

.61

.17

.15

.15

.21

.43

.52

.17

.16

.26

.27

.27

.31

.27

.32

.41

.38

.21

.38

.38

.22 76 TEH TSH 31 TEH TSH 66 TEH TEH 53 TEH TEH 50 TEH TSH 50 TEH TSH 92 TEH TEH 55 TEH TEH 59 TEH TEH 55 TEH TEH 58 TEH TEH 69 TEH TEH 45 TEH TEH 51 TEH TEH 64 TEH TEH 19 TEH TSH 53 TEH TEH 51 TEH TEH 32 TEH TSH 24 TEH TSH 53 TEH TSH 93 TEH TEH 26 TEH TSH 22 TEH TSH 22 TEH TSH 32 TEH TSH 66 TEH TSH 79 TEH TSH 26 TEH TSH 24 TEH TSH 40 TEH TSH 42 TEH TEH 42 TEH TEH 47 TEH TEH 42 TEH TEH 48 TEH TEH 63 TEH TEH 58 TEH TEH 32 TEH TSH 58 TEH TEH 58 TEH TEH 34 TEH TEH 610 ZPSNM 19 HI 610 ZPSNM 21 HI 610 ZPSNN 67 HN 610 ZPSNN 71 HI 610 ZPSNM 19 HI 610 ZPSNM 19 HI I

610 ZPSNN 65 HI 610 ZPSNN 65 HI 610

ZPSNN, 67 HI 610 ZPSNN 67 HI 610 ZPSNN 67 HI 610 ZPSNN 67 HI 610 ZPSNN 67 NI 610 ZPSNN 67 HI 610 ZPSNN 67 HI 610 ZPSNM 21 NI 610 ZPSNN 65 NI 610 ZPSNN 67 HI 610 ZPSNM 21 HI 610 ZPSNM 21 NI 610 ZP SNM

.17 HI 610 ZPSNN 67 HI 610 ZPSNM 21 HI 610 ZPSNM 21 NI 610 ZPSNM 21 HI 610 ZPSNM 21 NI 1

I 610 ZPSNM 21 HI 610 ZPSNM 23 HI 610 ZPSNM 23 HI 610 ZPSNM 21 HI 610 ZPSNN 65 HI 67 I

.610 ZPSNN 67 HI

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SG - C PWSCC Indications Braidwood 2 A2R13 CDE 20080401 07/17/2008 15:07:41

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Tubes:

1 Records: 5 1