View source for NL-13-143, Response to Request for Additional Information Regarding Steam Generator Tube Inservice Inspection Performed During-the Spring 2013 Refueling Outage

{{Adams
| number = ML13310A309
| issue date = 10/29/2013
| title = Response to Request for Additional Information Regarding Steam Generator Tube Inservice Inspection Performed During-the Spring 2013 Refueling Outage
| author name = Walpole R
| author affiliation = Entergy Nuclear Northeast
| addressee name = 
| addressee affiliation = NRC/Document Control Desk, NRC/NRR
| docket = 05000286
| license number = DPR-064
| contact person = 
| case reference number = NL-13-143
| document type = Letter type:NL
| page count = 6
| project = 
| stage = Response to RAI
}}

=Text=
{{#Wiki_filter:Enteray Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box 249
~Ent&W~                                                                         Buchanan, N.Y. 10511-0249 Tel (914) 254-6710 Robert Walpole Licensing Manager NL-13-143 October 29, 2013 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk 11555 Rockville Pike Rockville, MD 20852

==SUBJECT:==
Response to Request for Additional Information Regarding Steam Generator Tube Inservice Inspection Performed During-the Spring 2013 Refueling Outage Indian Point Unit No. 3 Docket No. 50-286 License No. DPR-64 REFERENCE          1. Entergy letter to the NRC, NL-1 3-032 dated August 15, 2013 regarding Technical Specification 5.6.8 - IP3 Steam Generator Tube Inspection Report - Spring 2013 Refueling Outage
: 2. NRC letter dated October 24, 2013 Request for Additional Information Regarding Steam Generator Tube Inservice Inspection Performed During the Spring 2013 Refueling Outage (TAC NO. MF2614)

==Dear Sir or Madam:==

Entergy Nuclear Operations, Inc (Entergy) submitted a report on the 3R17 Steam Generator Tube Inspection in accordance with Technical Specification 5.6.8 (Reference 1). The NRC indicated that additional information was needed to complete the NRC review (Reference 2). The purpose of this letter is to provide that information. Attachment 1 contains the Entergy response to the request for information.
There are no new commitments contained in this letter. Ifyou have any questions or require additional information, please contact me.
Sincerely, cc next page

NL-13-143 Docket No. 50-286 Page 2 of 2 cc: Mr. William Dean, Regional Administrator, NRC Region 1 Mr. Douglas Pickett,, Senior Project Manager, NRC NRR DORL Mr. Peter Habighorst, Material Control and Accounting Branch, NRC IPEC NRC Resident Inspector's Office Mr. Francis J. Murray, President and CEO, NYSERDA Ms. Bridget Frymire, New York State Department of Public Service

ATTACHMENT 1 TO NL-13-143 Response to Request for Additional Information Regarding the Steam Generator Examination Program Results 2013 Refueling Outage. (3R17)
ENTERGY NUCLEAR OPERATIONS, INC INDIAN POINT NUCLEAR GENERATING UNIT 3 DOCKET NO. 50-286

NL-13-143 Docket 50-286 Attachment 1 Page 1 of 3 Indian Point Unit 3 Response to Request for Additional Information Regarding Steam Generator Examination Program Results 2013 Refueling Outage (3R17)
In a letter dated August 15, 2013, Entergy Nuclear Operations, Inc. (Entergy), submitted information pertaining to the 2013 steam generator tube inspections at Indian Point Nuclear Generating Unit No. 3 (Agencywide Documents Access and Management Systems Accession Number [ADAMS] ML13235A047). These inspections were performed during the Unit No. 3 refueling outage seventeen. The Nuclear Regulatory Commission staff reviewed the information Entergy provided and requested, in a letter dated October 24, 2013, that additional information be provided in order to complete the NRC evaluation. Requests and responses with additional information are as follows:

===RAI 1===
The SG tube inspection report states that "no tubes were found with newly-formed degradation." It further states that there are eight small volumetric indications in the steam generator. Ifthese eight tubes were inspected during the 3R 17 outage, please provide the size, location, orientation, and measured sizes of any service induced indications (regardless of whether they are new) including the eight small volumetric indications created in 2001 as a result of sludge lance rail wear.
RAI I Response: The eight small volumetric indications noted are not service induced indications and were created in 2001 as a result of sludge lance rail wear.
The eight indications were examined during the 3R17 outage, the size, location, orientation, and measured sizes are shown in Table 1. These small volumetric wear indications were caused by the sludge lance rail system and are traceable to the 2001 inspection.
Table 1 SIG     Tube       Test       Voltage    Orientation    Location      Arc     Length    Depth Type 31      1-8      Bobbin        0.82         ADS        TSC
                                                             +16.38 XP          1.75         VOL        TSC
                                                             +16.41
                         +Pt         0.26         VOL        BPC -7.18    0.30      0.71      26%
1-27      Bobbin        0.67         ADS        TSC
                                                             +16.44 XP          1.03         VOL        TSC
                                                             +16.38
                         +Pt         0.25         VOL        BPC -7.45    0.27      0.66      26%

NL-13-143 Docket 50-286 Attachment 1 Page 2 of 3 SIG Tube  Test  Voltage Orientation Location   Arc Length    Depth Type 1-65 Bobbin  0.42      ADS      TSC
                                    +17.98 XP    0.60      VOL      TSC
                                    +18.02
           +Pt   0.11      VOL      BPC -5.68 0.23  0.55      16%
1-65 Bobbin  0.55      ADS      TSC
                                    +16.38 XP    1.06,,    VOL      TSC
                                    +16.14
           +Pt   0.12      VOL      BPC -7.73 0.20  0.92      17%
1-66 Bobbin  0.57      ADS      TSC
                                    +18.08 XP    0.42      VOL      TSC ;
                                    +17.85
           +Pt   0.17      VOL      BPC -5.63 0.24  0.66      21%
34  1-27 Bobbin  0.55      ADS      TSC
                                    +18.57 XP    1.55      VOL      TSC
                                    +18.36
           +Pt   0.19      VOL      BPC -5.27 0.30  1.21      24%
34  1-66 Bobbin  0.26      ADS      TSC
                                    +18.42 XP    0.46      VOL      TSC
_ +18.49
          +Pt    0.10      VOL      BPC -5.03 0.30  1.00      16%
34  1-85 Bobbin  0.33      ADS      TSC
                                    +17.01 XP     0.43      VOL      TSC
                                    +17.09
          +Pt    0.13      VOL      BPC -6.62 0.24  0.84      18%

NL-13-143 Docket 50-286 Attachment 1 Page 3 of 3

===RAI 2===
Please clarify the results of the tube plug and primary bowl drain area inspections. For example, were all plugs present and in the correct position? Did any plugs show any evidence of leakage or degradation? For the primary bowl drain area inspections, were any anomalies or degradation detected?
RAI 2 Response: The tube plug and primary bowl drain inspections had no findings. All plugs were present and in the correct positions with no evidence of leakage or degradation. There were no anomalies or degradation detected during the primary bowl drain area inspections.
RAI 3:'.
Please clarify the results of the secondary side steam drum and top tube support plate inspections: For example, discuss deposit loading in the secondary side and discuss whether any anomalies or degradation were observed. The staff notes.that in a prior inspection possible erosion/corrosion in two J-tube welds was identified. Please discuss whether these indications still exist or whether any other evidence exists that erosion/corrosion is occurring. Ifit is occurring, discuss the results of the condition monitoring and any planned corrective action.
RAI 3 Response: The secondary side steam drum and top tube support plate inspections had no anomalies or degradation observed and revealed extremely good to excellent conditions in all areas and components viewed. The deposit loading in the secondary side of the steam generators was minimal, with a total of 157 lbs of deposit material removed from the 4 steam generators. The feed ring, J nozzles, associated welds and hardware showed no signs of erosion or corrosion'. Five J nozzles in each steam generator were internally inspected looking for signs of erosion at the J nozzle to feed ring interface. The internal surfaces of the J nozzles inspected were intact and of sound condition, showing no evidence that erosion/corrosion is occurring. Two J-tube welds, 34 steam generator J-tubes 1 and 36, had inconclusive inspection results in 1997. J-tube 1 was one of the 5 J-tubes inspected in 34 steam generator during 3R17 and there was no indication of erosion corrosion at this location.

===RAI 4===
Please discuss the results of the anti-vibration bar position verification.
RAI 4 Response: The anti-vibration bar position verification results verified that the depth of insertion of the AVB's is in compliance with the design specifications.}}