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

{{Adams
| number = ML080800448
| issue date = 03/18/2008
| title = Transmittal of Technical Specification 5.6.6.1 - Steam Generator Inspection Report
| author name = Sena P
| author affiliation = FirstEnergy Nuclear Operating Co
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000334
| license number = DPR-066
| contact person = 
| case reference number = L-08-072
| document type = Letter type:L, Report, Miscellaneous
| page count = 8
}}

=Text=
{{#Wiki_filter: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}}