BYRON 2002-5008, Steam Generator Inservice Inspection Summary Report

Steam Generator Inservice Inspection Summary Report

ML021720555
Person / Time
Site:	Byron
Issue date:	06/13/2002
From:	Lopriore R Exelon Generation Co, Exelon Nuclear
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
BYRON 2002-5008
Download: ML021720555 (17)

Text

Exelkn,.

Exelon Generation Company, LLC www.exeloncorp.com Nuclear Byron Station 4450 North German Church Road Byron, IL61010-9794 ASME Section Xl, IWA-6000 June 13, 2002 LTR: BYRON 2002-5008 File: 3.11.0320 United States Nuclear Regulatory Commission Attention: Document Control Desk Washington, D.C. 20555-0001 Byron Nuclear Power Station, Unit 1 Facility Operating License NPF-37 NRC Docket No. 50-454

Subject:

Byron Station Unit I Steam Generator Inservice Inspection Summary Report In accordance with Technical Specification 5.6.9, "Steam Generator (SG) Tube Inspection Reports," Item b, we are reporting the results of the steam generator inspections which were completed during the Byron Station Unit 1, Cycle 11 Refueling Outage (ie., B1R11). The attached report is also being submitted in accordance with the requirements of the American Society of Mechanical Engineers Boiler and Pressure Vessel Code, 1989 Edition,Section XI, "Rules for Inservice Inspection of Nuclear Power Plant Components," Article IWA-6000, "Records and Reports," and Article IV-7000, "Report of Examination," of Mandatory Appendix IV, "Eddy Current Examination of Non Ferromagnetic Steam Generator Heat Exchanger Tubing."

If there are any questions regarding this report, please contact W. Grundmann, Regulatory Assurance Manager, at (815) 406-2800.

Respectfully, Richard P. Lopriore Site Vice President Byron Nuclear Generating Station

Attachment:

Steam Generator Eddy Current Inspection Report (BIR11)

RL!JS/cab cc: Regional Administrator- NRC Region III NRC Senior Resident Inspector - Byron Station NRC Project Manager- NRR - Byron Station Office of Nuclear Facility Safety - Illinois Department of Nuclear Safety n,,

Exelon Nuclear BYRON STATION UNIT 1 4450 N. German Church Road Byron, IL 61010 COMMERCIAL OPERATION: 09/16/85 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT CYCLE 11 REFUELING OUTAGE (BIR11)

March 2002 Exelon Nuclear 4300 Winfield Road Warrenville, IL 60555 Documentation Completed Date: 05/06/02 Page 1 of 16

Table of Contents 1.0 Introduction ........................................................................................... 3 2.0 Sum mary ................................................................................................ 3 3.0 Certifications ......................................................................................... 4 3.1 Procedures/Exam inations/Equipm ent ......................................... 4 3.2 Personnel ................................................................................... 5 4.0 Examination Technique and Examination Scope .................................. 6 4.1 Exam ination Techniques ............................................................. 6 4.2 Steam G enerator Inspection Scope ........................................... 7 4.3 Recording of Exam ination Data .................................................. 8 4.4 W itness and Verification of Exam ination .................................... 8 5.0 Exam ination Results .............................................................................. 8 5.1 Eddy Current Inspection ............................................................. 8 5.2 Visual Inspection of Installed Tube Plugs .................................... 9 6.0 Repair Sum m ary ..................................................................................... 9 7.0 Docum entation ...................................................................................... 9 8.0 Tables/Figures/Attachm ents ................................................................... 10 Page 2 of 16

1.0 INTRODUCTION

Byron Station Unit 1 operates with four Babcock & Wilcox Replacement Steam Generators (SGs) in the four loop pressurized water reactor system. The SGs each contain 6633 thermally treated Inconel-690 U-tubes that have a nominal diameter of 0.6875 inches and a nominal thickness of 0.040 inches. The tubes are supported by stainless steel lattice grid structures and fan bars. The tubes are hydraulically expanded into the full depth of the tubesheet. Main Feedwater enters the SGs above the tube bundle through a feedring and J-tubes. The SG configuration is shown in Figures A.1 and A.2. The replacement SGs were installed at the end of Cycle 8.

In compliance with Byron Station Technical Specification 5.5.9, "Steam Generator Tube Surveillance Program," and American Society of Mechanical Engineers (ASME) Boiler and Pressure Vessel (B&PV) Code, 1989 Edition,Section XI, "Rules for Inservice Inspection of Nuclear power Plant Components," IWB 2500-1, Examination Category B-Q, Item B16.20, SG eddy current examinations were performed during the Byron Station Unit 1 Cycle 11 Refueling Outage (i.e., B1 R1 1). In addition, the inspections were performed consistent with the Electric Power Research Institute (EPRI) "PWR Steam Generator Examination Guidelines," Revision 5, and Nuclear Energy Institute (NEI) 97 06, "Steam Generator Program Guidelines." The field inspection activities were conducted from March 16, 2002, through March 20, 2002, by Westinghouse Electric Company, Ltd. The following inspections were performed during this outage:

"* fifty-four percent (54%) full-length bobbin coil inspection in all four SGs (consisting of 100% of peripheral tubes with the exception of tubes under the manipulator base plate and 50% of interior tubes);

"* twenty-five percent (25%) plus-point probe inspection of hot leg top of tubesheet region;

"* visual inspection of all previously installed tube plugs; and

"* diagnostic plus-point inspections based on bobbin coil results.

2.0

SUMMARY

The guidance in Revision 5 of the EPRI PWR Steam Generator Examination Guidelines (i.e., EPRI Guidelines) was used during this inspection. A degradation assessment was performed prior to the inspection to ensure the proper EPRI Guideline Appendix H, "Performance Demonstration for Eddy Current Examination," qualified inspection techniques were used to detect any existing and potential modes of degradation. Each technique was evaluated to ensure that the detection and sizing capabilities are applicable to the Byron Station Unit 1 specific condition in accordance with Section 6.2.4 of 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. An independent QDA process control review was employed to randomly sample the data to ensure that the analysis resolution process was properly performed and that the field calls were properly reported. An analysis feedback process was implemented that required the data analysts to review their missed calls and overcalls on a daily basis.

Page 3 of 16

As a result of the eddy current inspection of the SGs, no tubes were found that contained flaws exceeding the repair limit. The results of this inspection were classified as inspection category C-1 pursuant to Technical Specification 5.5.9.c, "Inspection Results Classification." There were no scanning limitations during the eddy current examinations. No tubes were repaired. Table 2.1 provides the total tube plugging history and equivalent plugging levels to date for the Byron Station Unit 1 SGs.

Table 2.1 Equivalent Tube Plugging Level Tubes Previously Plugged*

Tubes Plugged in B Total Tubes Plugged Total Tubes Plugged(%)

{R11 0%

0 0

0

• Tube plugged at factory during vessel fabrication.

0 0

0 0%

1 0

1 0.015%

0 0

0 0% 0 1

0 1

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 American Society for Nondestructive Testing Recommended Practice No. SNT TC-1A (1984 Edition), "Personnel Qualification and Certification in Nondestructive Testing." Exelon Generation Company, LLC (i.e., Exelon)

Special Process Procedures Manual (SPPM) NDT-E-2, "Multifrequency Eddy Current Data Acquisition of Steam Generator Tubing at Braidwood and Byron Nuclear Stations," Revision 4 and Exelon procedure ER-AP-335-040, "Evaluation of Eddy Current Data for Steam Generator Tubing," Revision 0 were used for the data acquisition and analysis.

3.1.2 The examinations, equipment and personnel qualifications were in compliance with the requirements of Exelon and Westinghouse Quality Assurance Programs for Inservice Inspection, Byron Station Technical Specification 5.5.9, ASME B&PV Code, 1989 Edition,Section XI, "Rules for Inservice Inspection of Nuclear power Plant Components," and Section V, "Nondestructive Examination," EPRI PWR SG Examination Guidelines, Revision 5 and NEI 97-06, Steam Generator Program Guidelines, Revision 1.

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

3.1.4 R/D Tech Inc. TC6700 Remote Data Acquisition Units (RDAUs) with Westinghouse ANSER computer software were used to acquire the eddy current data. Analysis was performed with Westinghouse ANSER Version 01.2.3, including ANSER 8.3, Revision 81 computer software. Secondary analysis was performed with CoreStar EddyVISION 32 Release 4.6 computer software.

Page 4 of 16

3.1.5 The bobbin coil examinations of SG A were performed with Westinghouse 0.560 inch diameter replaceable head probes.

3.1.6 The rotating coil examinations were performed with Zetec 0.560 inch diameter high frequency three coil plus-point probe for examinations in the straight portion of the tube. The coils within this probe were a 0.115 inch diameter pancake coil, a shielded 0.080 inch diameter pancake coil and a standard plus-point coil. For examinations in the U-bend region, a Zetec 0.520 inch diameter high frequency plus-point probe was used.

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 personnel. A list of the certified eddy current personnel who conducted the examinations is contained in Table A.1.

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 conducted the examinations is contained in Table A.1.

3.2.3 All eddy current data analysts were qualified in accordance with the EPRI Guidelines, 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 plus-point inspection data analysis techniques. Resolution analysts were also trained and tested specifically for the performance of data resolution. All analysts were required to achieve a score of 80% or greater on both the written and practical examinations 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, with NDE Technologies, Quantum, and Verner & James as sub-contractors. An independent company, CoreStar International, performed the secondary analysis. Primary and secondary analysis was performed by an automated data screening analysis system as described in Section 6.3 of the EPRI PWR Steam Generator Examination Guidelines, Revision 5. The analysis systems were operated in the manual interactive mode. Each system was required to successfully pass the site specific performance demonstration practical examination prior to analyzing field data.

Page 5 of 16

3.2.6 An independent SG eddy current Level III QDA was employed to serve as a process control reviewer, in accordance with EPRI Guidelines, Section 6.3.3.4, 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 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 was employed by a third inspection company, Anatec International, and reported directly to the Exelon Level III inspector.

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 Byron Station Unit 1 SGs.

4.1 Examination Techniques 4.1.1 Approximately 54% of the inservice tubes were inspected full length utilizing a bobbin coil probe described in Section 3.1.5 of this report. This consisted of 100% of the peripheral tubes and 50% of the interior tubes. Nominal probe inspection speed was 40 inches per second. Sufficient sampling rates were used to maintain a minimum digitizing rate of 30 samples per inch. The bobbin probes were operated in the differential and absolute modes at frequencies of 650 kHz, 320kHz, 160 kHz, and 35 kHz. The following suppression mixes were used to enhance the inspection: 650/160 kHz differential mix, 320/160 kHz absolute mix, and a 650/320 kHz differential mix.

4.1.2 Twenty-five percent (25%) of the tubes in each SG were inspected at the hot leg top of tubesheet expansion transition region (+/- 3 inches) with a three-coil plus point probe as described in Section 3.1.6. Axial probe inspection speed was 0.5 inches per second. Sample rates and rotation speeds were used to maintain a minimum digitizing rate of 30 samples per inch (i.e., 25 samples per inch for the axial direction and 30 samples per inch for the circumferential direction). The rotating probes were operated in the absolute test mode at frequencies of 300 kHz, 200kHz, 100 kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display axial indications in the positive trace.

4.1.3 Diagnostic examinations were planned for non-quantifiable indications and hot leg dents/dings greater than 5.0 volts that may be detected by the bobbin coil examination. The diagnostic examinations were to utilize a three-coil plus-point probe as described in Section 3.1.6. Axial probe inspection speed was 0.5 inches per second for straight tubing and 0.15 inches per second for U-bend region of the tubing and dents/dings. Sample rates and rotation speeds were used to maintain a minimum digitizing rate of 30 samples per inch (i.e., 25 samples per inch for the axial direction and 30 samples per inch for the Page 6 of 16

circumferential direction). The rotating probes were operated in the absolute test mode at frequencies of 300 kHz, 200kHz, 100 kHz and 20 kHz. High row U-bend examinations were performed at frequencies of 400 kHz, 300 kHz, 100kHz and 20 kHz. In addition to the four base frequencies, three process channels were used to display axial indications in the positive trace.

4.1.4 The eddy current calibration standards used for the bobbin coil and plus-point inspections met the requirements of Section 6.2.7 of the EPRI PWR Steam Generator Examination Guidelines, Revision 5 and Sections V and Xl of the ASME B&PV 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. Each technique was evaluated and determined to be applicable to the site conditions.

Table 4.1 EPRI Appendix H Techniques Technque robe Description, 96004.3 Bobbin BFlaws Fan Bar/Lattice Grid/Foreign Object Wear and Free Span 96910.1 Plus-Point Foreign Object Wear/Free Span Flaws (Wear Like Flaws) 99998.1 Pancake Foreign Object Wear/Free Spam Flaws (Pit Like Flaws) 20409.1 Plus-Point ODSCC at Top of Tubesheet Transition Expansion 20511.1 Plus-Point PWSCC at Top of Tubesheet Transition Expansion 20510.1 Plus-Point PWSCC at Top of Tubesheet Transition Expansion 96703.1 Plus-Point PWSCC at Dents and Dings 96010.1 Bobbin Manufacturing Burnish Marks

- ODSCC - Outer Diameter Stress corrosion Cracking

- PWSCC - Primary Water Stress Corrosion Cracking 4.2 Steam Generator Inspection Scope 4.2.1 Approximately 54% of the inservice tubes were inspected full length utilizing a bobbin coil probe described in Sections 3.1.5 and 4.1.1of this report. This consisted of 100% of the peripheral tubes with the exception of tubes under the manipulator base plate and 50% of the interior tubes.

4.2.3 Twenty-five percent (25%) of the tubes in each SG were inspected at the hot leg top of tubesheet expansion transition region (+/- 3 inches) with a three-coil plus point probe as described in Sections 3.1.6 and 4.1.2.

4.2.4 Diagnostic examinations were planned for non-quantifiable indications and hot leg dents/dings greater than 5.0 volts that were detected by the bobbin coil examination. Diagnostic examinations were also performed to investigate potential foreign object signals and extent of condition for the potential foreign objects. These special examinations are performed with the three-coil plus-point probe described in Sections 3.1.6 and 4.1.3 above. A total of 90 tubes were Page 7 of 16

inspected as a result of these diagnostic examinations. No hot leg dents or dings greater than 5.0 volts by the bobbin coil technique were detected.

4.2.5 Diagnostic bobbin coil examinations were planned to bound locations of foreign object signals and fan bar wear indications. These examinations were performed with the bobbin coil probe described in Sections 3.1.5 and 4.1.1 above. A total of 85 tubes were inspected as a result of these diagnostic examinations.

4.3 Recording of Examination Data Results of the SG eddy current data analysis were recorded on optical disks. The data was then loaded into a Westinghouse SG eddy current data management system. The 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 Authorized Nuclear Inservice Inspectors, Mr. Jeff Hendricks and Mr. Robert Ward of the Hartford Steam Boiler Inspection & Insurance Company of Connecticut, Chicago Branch, 2443 Warrenville Road, Suite 500, Lisle, Illinois 60532-9871.

ASME Form NIS-1, "Owners Report for Inservice Inspections", is shown in Figure B.1.

5.0 EXAMINATION RESULTS 5.1 Eddy Current Inspection Full-length bobbin coil examination was performed on approximately 54% of the tubes in each SG. This inspection consisted of 100% of the periphery tubes and 50% of the interior tubes, excluding the tubes directly underneath the manipulator base plate. Twelve tubes were found that contained indication of fan bar wear.

The depth of the fan bar wear flaws ranged from 2% through-wall to 8% through wall. Table 5.1 provides the tube and flaw locations of each indication. No other tubes exhibited tube degradation.

Page 8 of 16

Table 5.1 Fan Bar Wear Indications - BI R1 I SG Ro Columrn Depth Location* "

A 46 11 4% F03+0.98" A 70 55 3% F03+0.75" A 72 63 3% F05-1.33" A 64 65 7% F06+0.47" A 60 93 3% F06-1.86" B 75 60 2% F02-2.25" B 67 62 6% F01-1.32" B 95 66 3% F05-0.85" B 101 74 8% F05+1.43" B 35 84 2% F05-0.74" B 87 90 5% F06+1.45" 1 52 79 2% F05-1.95" D None I I

• Fan Bar Support Number 5.2 Visual Inspection of Installed Tube Plugs All previously installed tube plugs (i.e., two shop welded plugs) were visually inspected for signs of degradation and leakage. No evidence of degradation or leakage was detected.

6.0 REPAIR

SUMMARY

No tubes were found during this inspection that required plugging or repair. The only degradation found was fan bar wear in 12 tubes with flaw depths of 2% to 8% through-wall and were all less than the 40% through-wall repair limit.

7.0 DOCUMENTATION All original SG eddy current optical disks have been provided to Exelon and are maintained at Byron Station. The final data sheets and pertinent SG tube sheet plots are contained in the Westinghouse Final Outage Report for Byron Station Unit 1, B1 R1 1, and are also maintained at Byron Station.

Page 9 of 16

8.0 TABLES/FIGURES/ATTACHMENTS Table A.1 Eddy Current Personnel Certifications Figure A.1 Babcock & Wilcox Replacement Steam Generator Byron Unit 1 Configuration Figure A.2 Byron Station Unit 1 Steam Generator Tubesheet Configuration Figure B.1 ASME Form NIS-1, "Owners Report for Inservice Inspections Page 10 of 16

TABLE A.1 EDDY CURRENT PERSONNEL CERTIFICATIONS Page 1 of 2 4 Beiers, TS NDE Technology lilA Y 5 Bolt, W Westinghouse II N 6 Bowser, GC Corestar III Y 7 Burkholder, RS Westinghouse Ill N 8 Carlson, CD Verner & James IIA Y 9 Causby, GW Corestar IliA Y 10 Croyle, RJ Corestar III Y 11 Currier, DE Quantum III Y 12 Dvorak, DJ TMP/Spec I N 13 Estel, JW Westinghouse II N 14 Evering, DP Westinghouse II N 15 Gallik, MR Westinghouse I N 16 Glenn, WD Westinghouse II N 17 Gootz, TE Westinghouse III Y 18 Greenawalt, LS Westinghouse I N 19 Groh, TA Westinghouse II N 20 Haynes, WR NDE Technology lilA Y 21 Hazlett, WE Westinghouse II N 22 Hopper, JM Westinghouse II N 23 Humphrey, RA Corestar III Y 24 Johnson, JR Corestar IIA Y 25 Kirk, MB Corestar III Y 26 Koeser, SL Westinghouse II N 27 Lewis, CL NDE Technology IIA Y 28 Lewis, DA NDE Technology IliA Y 29 Lohner, ET NDE Technology IliA Y 30 Looper, VR NDE Technology lilA Y 31 Mains, PJ Westinghouse II N 32 Mardell, DM Westinghouse II N 33 Martin, AP Corestar IIA Y 34 McChesney, WD Corestar III Y 35 McElhinny, JW Westinghouse II N

• Independent Level III Qualified Data Analyst Page 11 of 16

TABLE A.1 DATA ANALYSIS PERSONNEL CERTIFICATIONS Page 2 of 2 38 Nelson, DL NDE Technology lilA Y 39 Overly, ES Corestar IIA Y 40 Parris, JR Westinghouse II N 41 Popovich, RA Westinghouse III Y 42 Richmond, MA NDE Technology lilA Y 43 Robertson, RR Corestar IIA Y 44 Rogers, GF Quantum III Y 45 Schaffner, KR TMP/Spec I N 46 Seutter, AE Corestar IIA Y 47 Shipley, EB Westinghouse II N 48 Siegel, RA NDE Technology lilA Y 49 Smith, JS Corestar IIA Y 50 Spake, CD Corestar III Y 51 Stach, GJ Corestar IIA Y 52 Stitt, .AL Westinghouse II N 53 Stokke, TF NDE Technology IliA Y 54 Taylor, SH Westinghouse III Y 55 Thompson, VA NDE Technology lilA Y 56 Thulien, TA Corestar III Y 57 Traves, DJ Corestar IIA Y 58 Turner, DG Corestar IMA Y 59 Vernon, DP Westinghouse II N 60 Visconte, CG Corestar IIA Y 61 Welch, LC Verner & James lilA Y 62 Whalen, DJ Westinghouse II N 63 Wrubleski, AF Quantum Ill Y 64 Young, JA Westinghouse II N

• Independent Level III Qualified Data Analyst Page 12 of 16

FIGURE A. 1 Babcock & Wilcox Replacement Steam Generator Byron Unit 1 Configuration SECONDARY.

HANWAY SECONDARY.

DECK PRIM-ARY DrECK FEEC WATER NOZZLE REC I RCUL.AT 1 ON NOZZLE FEEDWATER HEADER (TYP)

LATTICE GRIO INSPECTION PORTS (TYP)

PR -IMRY -EAOD REACTOR COCO(A?-T NOZZLE Page 13 of 16

FIGURE A.2 Byron Unit 1 Steam Generator Tubesheet Configuration (Typical)

Byron Station UNIT: 1 SG: 1 A 5 10 Is 20 21 30 35 40

/ 5 50 55 Gs 7 0so As so 5 100 11 120 125 [30 135 140 1155 110 0000000. 105 110 .. .000 00o - ~O ------ 09-000 0o~ 0 Qnc 00 0~- 2 o 00 o

4

ý9 Q Q~0 g0 100 Los

.,o ...

1s i0

"-u 35 (0 0 00 '

0000 o 00o0 00do od 0co S... --

• 70 70

,-h 15 10 55 62..s-so - -

000 00 0o 45 40 35 40 0

30 0 15 0,00 0 4 o 0 0 0 0 o 25 S .... 00 00000 00050 20 i5 o o0 10 115 120 125 130 135 140 55 90 55 100 105 110 50 55 *o s5 70 75 0 Model: 7720 INLET NOZZLE 20 25 30 35 40 45 5 10 15 MANWAY Database: BYRONi X or Total Character Extent Total 673 100.00 0 DFault Tube Default Stay 6

FIGURE B.1 FORM NIS-1 OWNER'S REPORT FOR INSERVICE INSPECTIONS As Required by the Provisions of the ASME Code Rules

1. Owner: Exelon Nuclear 4300 Winfield Road, Warrenville, IL 60555 (Name and Address of Owner)

2. Plant: Byron Station 4450 N. German Church Rd. Byron, Illinois 61010 (Name and Address of Plant)

3. Plant Unit: One (1) 4. Owner Certificate of Authorization (if required): N/A

5. Commercial Service Date: 09/16/85 6. National Board Number for Unit: N-198

7. Components Inspected: Steam Generator Eddy Current Inspection Component or Manufacturer or Manufacturer or State or Province National Board No.

Appurtenance Installer Installer Serial No. No.

IRCOIBA Babcock & Wilcox 7720-02 ILU-242904 165 1RCOIBB Babcock & Wilcox 7720-03 ILU-292903 166 IRCO1BC Babcock & Wilcox 7720-01 ILU-242902 164 IRCO1BD Babcock & Wilcox 7720-04 ILU-242901 167 L 4 4 4 I I I I I I I I 4 4 I 4 4 I 4 i 1

.1 1 4 1 I.

I 4- 4. 1*

I 4- 4. 1-I .1. + __________ j __________ .1 __________ .1.__________ __________

Page 15 of 16

FORM NIS-1 (Back)

8. Examination Dates 03/16/02 to 03/20/02 9. Inspection Interval from 6/30/96 to 6/30/05

10. Abstract of Examinations. Include a list of examinations and a statement concerning status of work required for current interval.

Refer to the Attached Steam Generator Eddy Current Report

11. Abstract of Conditions Noted Refer to the Attached Steam Generator Eddy Current Report

12. Abstract of Corrective Measures Recommended and Taken Refer to the Attached Steam Generator Eddy Current Report We certify that the statements made in this report are correct and the examinations and corrective measures taken conform to the rules of the ASME Code,Section XI.

Certificate of Authorization No. (if applicable) Not Applicable ExpirationyPa ot A icable Date I1&I (0y 20", Signed For Exelon Nuclear By -I Owner I I CERTIFICATE OF INSERVICE INSPECTION I, the undersigned, holding a valid commission issued by the National Board of Boiler and Pressure Vessel Inspectors and the State or Province of z2,hpl and employed by #ý, e e Of I ,-ý / have inspected the components described in this Owner's Report during the period to __St/w , and state that to the best of my knowledge and belief, the Owner has performed examinations and ta en orrective rneastfres described in this Owner's Report in accordance with the requirements of the ASME Code,Section XI.

By signing this certificate neither the Inspector nor his employer makes any warranty, expressed or implied, concerning the examinations and corrective measures described in this Owner's Report. Furthermore, neither the Inspector nor his employer shall be liable in any manner for any personal injury or property damage or loss of any kind arising from or connected with this inspection. I

_m__d__**_l_* Commissions ///- 12.Y

?s'pector's Signature National Board, State, Province, and Endorsements Date 20 e2 Page 16 of 16