L-08-072, Transmittal of Technical Specification 5.6.6.1 - Steam Generator Inspection Report

Transmittal of Technical Specification 5.6.6.1 - Steam Generator Inspection Report

ML080800448
Person / Time
Site:	Beaver Valley
Issue date:	03/18/2008
From:	Sena P FirstEnergy Nuclear Operating Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
L-08-072
Download: ML080800448 (8)

Text

FENOC FirstEnergyNuclear OperatingCompany Peter P. Sena III 724-682-5234 Site Vice President Fax: 724-643-8069 March 18, 2008 L-08-072 ATTN: Document Control Desk U. S. Nuclear Regulatory Commission Washington, DC 20555-0001

SUBJECT:

Beaver Valley Power Station, Unit No. 1 Docket No. 50-334, License No. DPR-66 Technical Specification 5.6.6.1 - Steam Generator Inspection Report In accordance with Beaver Valley Power Station Unit No. 1 Technical Specification (TS) 5.6.6.1, information related to steam generator inspections is provided in Attachment 1.

There are no regulatory commitments contained in this letter. If there are any questions or if additional information is required, please contact Mr. Thomas A. Lentz, Manager -

FENOC Fleet Licensing, at 330-761-6071.

Sincerely, Peter P. Sena III Attachments:

1. Technical Specification 5.6.6.1 - Unit 1 SG Tube Inspection Report cc: Mr. S. J. Collins, NRC Region I Administrator Mr. D. L. Werkheiser, NRC Senior Resident Inspector Ms. N. S. Morgan, NRR Project Manager Mr. D. J. Allard, Director BRP/DEP Mr. L. E. Ryan (BRP/DEP)

ATTACHMENT 1 L-08-072 Beaver Valley Power Station Unit No. 1 Technical Specification 5.6.6.1 - Unit 1 SG Tube Inspection Report Page 1 of 7 The following information satisfies the reporting requirement of Beaver Valley Power Station Technical Specification (TS) 5.6.6.1. Refer to the tables on Page 7 of this attachment which define abbreviations, codes and other terms used throughout this report.

Information required by Technical Specification 5.6.6.1 Technical Specification 5.6.6.1 requires reporting within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with Specification 5.5.5.1, Unit 1 Steam Generator (SG) Program. Information required by TS 5.6.6.1, Items a through h is provided below for the maintenance and refueling outage in the fall of 2007 (1R1 8).

a. The scope of inspections performed on each SG Primary side inspection scope involved the following:

• 100% full length bobbin coil probe examination (Row*3 through Row 47)

• 100% bobbin coil probe examination of the hot and cold leg straight sections in Row 1 and 2 up to and including the top support plate

• 100% Plus Point probe inspection of the Row 1 and 2 U-bends from the top support plate on the hot leg to the top support plate on the cold leg

• 100% Plus Point probe inspection of over-expansions and bulges contained within or just above the hot leg tubesheet (These were previously reported during the preservice examination and are located 10.0" or higher from the hot leg tube end)

• 100% Plus Point probe inspection of bobbin coil indications that could possibly represent degradation (I-codes)

• Plus Point probe inspection of the top-of-tubesheet periphery (3 tubes deep in any row or column) and the blowdown pipe region (2 tubes deep on either side of the blowdown pipe)

• Plus Point probe inspection of any ambiguous bobbin coil signals P "As- left" video inspection of the hot and cold leg channel heads Secondary side inspection scope involved the following:

• Secondary side visual inspections of the top-of-tubesheet annulus, blowdown pipe region and random in-bundle locations

" In-bundle visual inspections of possible loose part locations identified from the analysis of the eddy current data L-08-072 Page 2 of 7

b. Active degradation mechanisms found No active degradation mechanisms were reported during the 1R1 8 SG tube examinations.

c. Nondestructive examination techniques utilized for each degradation mechanism For 1R1 8, bobbin coil probes were used as the primary method of degradation detection except in those areas of the tube (e.g. at or below TTS, low row U-bends) where bobbin probes are not qualified. In those areas of the tube, Plus Point probes were employed. Plus Point probes were also used to re-examine any ambiguous bobbin coil signals.

All examination techniques utilized during the 1R1 8 SG tube inspections were qualified for detection of the relevant and potential degradation mechanisms listed in the 1R1 8 degradation assessment. This qualification is in accordance with Appendix H of the EPRI SG Examination Guidelines, Revision 6. Examination techniques used for detection of degradation are tabulated below.

Examination Techniques Used for Detection of Degradation Degradation Mode I Tube Location Probe EPRI ETSS*

Bobbin 96008.1 Free Span Area of Tubing 3 oiuin 2109.1 General Degradation 3 Coil Plus Point 21409.1 PWSCC Tubesheet Region 3 Coil Plus Point 20511.1 Tube Wear AVB Locations Bbi Bobbin, 60.

96004.1 1 Coil Plus Point 21409.1 Bobbin 96001.1 Tube Wear TSP Intersections 3 Coil Plus Point 21998.1 Bobbin 96008.1 Periphery/Blowdown lane 3 Coiuin 998.1 Tube Wear 3 Coil Plus Point 21998.1 Bobbin 96010.1 MBM's Free Span Area of Tubing 3 Coil Plus Point 21409.1 Bobbin 96008.1 Volumetric Full Length 3 Coil Plus Point 21998.1

-The applicable EPRI Examination Technique Specification Sheets (ETSS) are listed for reference only. Site-specific examination technique sheets are developed prior to each SG inspection in accordance with Appendix H of the EPRI SG Examination Guidelines (Revision 6).

L-08-072 Page 3 of 7

d. Location, orientation (if linear), and measured sizes (if available) of service-induced indications The following tables provide examination results for tubes with service-induced indications in each SG. All indications listed with I-codes (e.g., distorted support plate signals with indications (DSIs), non-quantifiable indications (NQIs), dents with indications (DNIs), etc,) were re-inspected with the Plus Point Probe. Ifthe Plus Point probe indicated that no degradation/flaws were present, the tube remained in service. Ifdegradation/flaws were reported from the Plus Point examination the tube was removed from service via plugging.

SG 1RC-E-1A Row Col Ind Volts Phase %TW Chan Loc Inch Length Angle From To 2 61 NQI 2.11 70 6 06C 47.43 07C TEC 2 61 NDF 6 06C 47.43 06C 07C 8 30 NQI 1.56 39 6 06H 47.00 TEC TEH 8 30 NDF 6 06H 47.00 06H 07H 8 31 NQI 1.71 40 6 07H -1.66 TEC TEH 8 31 NDF 6 07H -1.66 06H 07H 8 32 NQI 1.5 58 6 07H 1.90 TEC TEH 8 32 NDF 2 07H 1.90 07H 07H 12 47 DNI 0.38 150 5 TSC 25.03 TEC TEH 12 47 NDF 6 TSC 25.03 TSC 01C 26 29 DNI 0.61 165 P1 06H -0.02 TEC TEH 26 29 NDF 6 06H -0.02 06H 06H 32 26 DNI 0.28 146 5 02H 28.80 TEC TEH 32 26 NDF 6 02H 28.80 02H 03H 33 25 FSI 0.42 48 3 06C 8.08 TEC TEH 33 25 NDF 6 06C 8.08 05C 07C 33 25 FSI 0.27 29 3 06C 14.92 TEC TEH 33 25 NDF 6 06C 14.92 05C 07C 33 25 FSI 0.11 44 3 06C 22.82 TEC TEH 33 25 NDF 6 06C 22.82 05C 07C 33 25 FSI 0.44 37 3 05C 47.14 TEC TEH 33 25 NDF 6 05C 47.14 05C 07C SG 1RC-E-1B Row Col Ind Volts Phase %TW Chan Loc Inch Length Angle From To 39 52 DNI 0.28 156 P1 AV3 0 TEC TEH 39 52 NDF 2 AV3 0 AV3 AV3 L-08-072 Page 4 of 7 SG 1RC-E-1C Row Col Ind Volts Phase %TW Chan Loc Inch Length Angle From To 11* 2 DSI 0.23 114 P1 04H 0.34 TEC TEH 11* 2 PCT .0.22 114 29 P4 04H 0.39 0.21 26 04H 04H 43 44 NQI 2.11 65 6 02H 14.99 TEC TEH

.43 44 NDF 6 02H 14.99 02H 03H 44 36 DNI 0.31 169 P1 TSC 18.62 TEC TEH 44 36 NDF 6 TSC 18.62 TSH FBC

• Row 11, Column 2 was administratively removed from service.

L-08-072 Page 5 of 7 Description of Column Headings and Data Abbreviations Used in Tables in Item d Report Header Definitions Term Definition Row/Col Row & Column of tube location Ind Type of indication (See data analysis acronyms below)

Volts Voltage amplitude of an indication Phase Angular rotation of indication

%TW Percent through wall of indication Chan Frequency channel from which indication was recorded Loc Location of nearest support structure Inch Indication distance from nearest support structure Length Field measured crack length Angle Field measured crack phase angle From Starting point of examination To End point of examination Examination Extent Definitions (From - To)

Term Definition FBC Flow Distribution Baffle - Cold Leg Side TEH Tube End - Hot Leg TSH Hot Leg Tubesheet TEC Tube End Cold Leg TSC Cold Leg Tubesheet 01H 1st Tube Support Plate on Hot Leg Side 01C Ist Tube Support Plate on Cold Leg Side AV1 1st Anti-Vibration Bar (Numbered hot leg to cold leg)

L'08-072 Page 6 of 7

e. Number of tubes plugged during the inspection outage for each active degradation mechanism As stated above, no active degradation mechanisms were reported during 1R1 8.

However, one tube (R1 1 C2 in SG "C") was administratively removed from service-due to a wear indication. The indication was located at the upper edge of the 4 th hot leg support plate and is believed to be caused by a burr remaining from the broaching process used during fabrication of the support plate.

f. Total number and percentage of tubes plugged to date The total number of tubes plugged post 1 R1 8 is 1 tube (0.01%). To date, no tubes have been repaired (sleeved).

g. The results of condition monitoring, including the results of tube pulls and in-situ testing During the 1R18 SG tube inspections, no indications were observed that exceeded the structural integrity limits for either axial or circumferential degradation (i.e., burst integrity > 3 times normal operating primary to secondary pressure differential). No tubes were found to contain indications that could potentially challenge the tube integrity requirements of NEI 97-06, Revision 2, "Steam Generator Program Guidelines."

Based on the 1 R18 inspection results, the SG tubing is expected to meet all operational, structural and leakage integrity requirements at the end of Cycle 19. No, indications were reported during 1R1 8 that could possibly represent a leakage potential at postulated main steam line break conditions. As such, in-situ proof or leakage testing was not required during 1R18 and no tubes or tube sections were removed (pulled).

h. The effective plugging percentage for all plugging in each SG Listed below are the plugging percentages for each SG post 1R1 8. Since no sleeves have been installed to date, the effective plugging percentage is not applicable.

SG Tubes Plugged  % Plugged 1RC-E-1A 0 0.00 1RC-E- B 0 0.00 1RC-E-1C 1 0.01 L-08-072 Page 7 of 7 Definitions of Abbreviations, Codes and Reporting Terminology 3 Letter Code Definitions Term Bobbin Coil Definitions DNI Dent/Ding with a Possible Indication DSI Distorted Support Signal with Possible Indication FSI Free Span Indication MBM Manufacture's Burnish Mark NQI Non-Quantifiable Indication Term Plus Point Definitions NDF No Degradation Found Additional Definitions Term Definition AVB Anti-Vibration Bar DENT Indentation Observed within Tube Support Plate DING Indentation Observed in Free-Span Region EPRI Electric Power Research Institute NEI Nuclear Energy Institute PCT Percent Through Wall PWSCC. Primary Water Stress Corrosion Cracking TSP Tube Support Plate TTS Top of Tubesheet