View source for 2CAN040301, Annual Report of Steam Generator Tubing In-service Inspections

{{Adams
| number = ML031080421
| issue date = 04/11/2003
| title = Annual Report of Steam Generator Tubing In-service Inspections
| author name = Cotton S
| author affiliation = Entergy Operations, Inc
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000368
| license number = NPF-006
| contact person = 
| case reference number = 2CAN040301
| document type = Annual Report, Inservice/Preservice Inspection and Test Report, Letter type:
| page count = 6
}}

=Text=
{{#Wiki_filter:EnterI gy                                                                   Entergy Operations, Inc 1448 SR 333 Russeliville, AR 72802 Tel 501 858 5000 2CAN040301 April 11, 2003 U. S. Nuclear Regulatory Commission Document Control Desk Mail Station OP1-17 Washington, DC 20555

==Subject:==
Arkansas Nuclear One - Unit 2 Docket No. 50-368 License No. NPF-6 2003 Annual Report of Steam Generator Tubing In-service Inspections

==Dear Sir or Madam:==

Arkansas Nuclear One, Unit 2 (ANO-2) Technical Specifications 4.4.5.5.b and 6.9.1.5.b require that results of ANO-2 steam generator (SG) tubing in-service inspections performed during the report period be submitted to the NRC on an annual basis. Attached is the Steam Generator Tubing In-service Inspection Annual Report which presents the results from ANO-2's scheduled refueling outage (2R15) inspection. These inspections were completed on April 24, 2002.
This submittal completes the reporting requirements of ANO-2 Technical Specifications 4.4.5.5.b and 6.9.1.5.b for 2003. This submittal contains no commitments.
Should you have any questions regarding this issue, please contact Fred Van Buskirk of my staff at (479) 858-3155.
Sincerely, Sherrie R. Cotton Director, Nuclear Safety Assurance SRC/fpv Attachment 43(447

2CAN040301 Page 2 of 2 cc wI att:  Mr. Ellis W. Merschoff Regional Administrator U. S. Nuclear Regulatory Commission Region IV 611 Ryan Plaza Drive, Suite 400 Arlington, TX 76011-8064 NRC Senior Resident Inspector Arkansas Nuclear One P.O. Box 310 London, AR 72847 U. S. Nuclear Regulatory Commission Attn: Mr. Thomas W. Alexion MS O-7D1 Washington, DC 20555-0001

Attachment to 2CAN040301 Page 1 of 4 ARKANSAS NUCLEAR ONE, UNIT 2 STEAM GENERATOR TUBING IN-SERVICE INSPECTION ANNUAL REPORT 1       INTRODUCTION Arkansas Nuclear One, Unit 2 (ANO-2) Technical Specification (TS) 4.4.5.5.b requires Entergy Operations to submit an annual report to the NRC that outlines the details of the steam generator (SG) tubing in-service inspections that were performed during the reporting period. The report shall include:
: 1. Number and extent of tubes inspected
: 2. Location and percent of wall-thickness penetration for each indication of an imperfection.
3      Identification of tubes plugged The operating period for this report includes one outage, a refueling inspection (2R15) in April 2002.
2       DESIGN The replacement steam generators are Westinghouse (W) Model Delta 109s. They consist of Inconel 690 thermally treated tubing that is 11/16" in diameter with a 0.040" wall thickness The tubes are expanded full depth hydraulically in the tubesheet The tube supports are constructed of stainless steel and are a broached trefoil-hole design. The upper bundle supports consist of five sets of staggered stainless steel anti-vibration bars (AVBs) that are numbered AO1-A20.

Attachment to 2CAN040301 Page 2 of 4 3       2R15 OUTAGE RESULTS 3.1    2R15 Scope Table 3.1 lists the inspection scope of 2R15.
Table 3.1 2R15 Inspection Scope SG "A" Examination Type                 Inspections Conducted       % Scope   Extent Tested Bobbin                                     10637                100         TEC to TEH Row 1&2 U-Bend                              181                 100         08H to 08C Bobbin I-Codes                               15                 N/A            N/A SG "B" Examination Type                 Inspections Conducted       % Scope   Extent Tested Bobbin                                     10636          J     100  J      TEC to TEH Row 1&2 U-Bend                              181                 100         08H to 08C Bobbin I-Codes                               11                 N/A            N/A TEC - Tube End Cold TEH - Tube End Hot 3.2    Degradation Mechanisms Found Table 3.2 outlines the number of indications found during the outage.
Table 3.2 2R15 Inspection Results Location                                        SG "A"   SG "B" AVB Wear                                    l      0_l       1 Loose Part Wear                               _              2 Manufacturing Burnish Marks (MBM)                 139      216 Dents (Pre-service)                               1017      596

Attachment to 2CAN040301 Page 3 of 4 3.3    NDE Techniques Utilized Table 3.3 identifies the non-destructive examination (NDE) technique used for each location:
Table 3.3 2R15 NDE Techniques Location                               NDE Technique Bobbin                        0.560" Bobbin U-Bend                        0 520" Plus Point Coil Special Interest              0.520" or 0.560" Plus Point Coil 3.4    Number of Tubes Plugged or Repaired by Damage Mechanism There were no plugs or sleeves installed during 2RI 5.
3.5    Number and Percent Plugged and Sleeved Following 2R15 The number of tubes plugged or sleeved following 2R15 is shown in Table 3.5.
Table 3.5 Cumulative Plugs and Sleeves in Service SG "A"                 SG "B' Sleeves                                 0                  0 Pre-service I-690 Welded                0                   1 Post Installation Plugs                 0                  0 Percent Plugged                      0.000 %            0.009 %
3.6   Description of Tube Integrity Assessment The operational assessment was performed using deterministic methods for the identified damage mechanism and justified operation for the next two cycles. All performance criteria were met.
3.7   Description of Corrective Actions There were no corrective actions taken since all tests met the specified criteria

Attachment to 2CAN040301 Page 4 of 4 3.8     Evaluation of Exceeding Condition Monitoring Not applicable since all conditions were met.
3.9     Item #2 of the Technical Specification (location and percent of wall-thickness penetration for each indication of an imperfection)
This topic is addressed in Table 3.9 for SG "B" below. There were no indications identified in SG "A".
TABLE 3.9 SG "B" INDICATION LIST FOR 2R15 No.       Row      Column Indication        Location          Reason           % TW 1         100        25        VOL        TSC +12.8         Loose Part          18 2         102        25        VOL        TSC +12.3         Loose Part           4 3         109        92        WAR        All -0.17         AVB Wear            12 Legend:
VOL - Volumetric WAR - Anti-Vibration Bar Wear TSC - Tubesheet Cold Al l - I lh Anti-Vibration Bar TW - Through Wall}}