ML13235A047

Indian Point, Unit 3, Technical Specification 5.6.8 - IP3 Steam Generator Tube Inspection Report - Spring 2013 Refueling Outage

ML13235A047
Person / Time
Site:	Indian Point
Issue date:	08/15/2013
From:	Robert Walpole Entergy Nuclear Northeast
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-13-032
Download: ML13235A047 (8)

Text

SEntergyEnteray Nuclear Northeast Indian Point Energy Center450 Broadway, GSBP.O. Box 249Buchanan, N.Y. 10511-0249 Tel (914) 254-6710Robert WalpoleLicensing ManagerNL-13-032 August 15, 2013U.S. Nuclear Regulatory Commission ATTN: Document Control Desk11555 Rockville PikeRockville, MD 20852

SUBJECT:

REFERENCE Technical Specification 5.6.8 -IP3 Steam Generator Tube Inspection Report -Spring 2013 Refueling OutageIndian Point Unit No. 3Docket No. 50-286License No. DPR-641. Entergy letter to the NRC, NL-07-083

'Steam Generator Tube Inspection Report for Spring 2007 Refueling Outage',

dated July 19, 2007

Dear Sir or Madam:

Entergy Nuclear Operations, Inc (Entergy) is providing in Enclosure 1 the Steam Generator (SG) Tube Inspection Report required by Indian Point 3 Technical Specification 5.6.8.Technical Specification 5.6.8 requires that a report be submitted to the NRC 180 days after theinitial entry into Mode 4 following completion of a steam generator program inspection.

Entergyperformed a SG inspection in March 2013 during unit 3 refueling outage 3R17. The unit initially entered MODE 4 following this inspection on March 25, 2013. This inspection was the 7th in-service inspection (ISI) following SG replacement in 1989 and the 1st of 2 scheduled inspections in the 2nd inspection period.The scope of the inspection included all four steam generators, which are Westinghouse Model 44F with thermally treated Alloy 690 tubes. At the time of the inspection, the steamgenerators had approximately 205 effective full power months of operation since the firstinservice inspection performed in 1990. All four steam generators were found to be incompliance with condition monitoring requirements.

The previous inspection was performed during the spring 2007, Refueling Outage 3R14 (reference 1).

NL-13-032 Docket No. 50-286Page 2 of 2There are no new commitments contained in this letter. If you have any questions or requireadditional information, please contact me at 914-254-6710.

Sincerely, RW/mb/rdcc: Mr. William Dean, Regional Administrator, NRC Region 1Mr. Douglas Pickett,,

Senior Project Manager, NRC NRR DORLMr. Peter Habighorst, Material Control and Accounting Branch, NRCIPEC NRC Resident Inspector's OfficeMr. Francis J. Murray, President and CEO, NYSERDAMs. Bridget Frymire, New York State Department of Public Service ENCLOSURE 1 TO NL-13-032 Steam Generator Examination Program Results2013 Refueling Outage (3R17)ENTERGY NUCLEAR OPERATIONS, INCINDIAN POINT NUCLEAR GENERATING UNIT 3DOCKET NO. 50-286 Indian Point Unit 3Steam Generator Examination Program Results2013 Refueling Outage Q3R17)1.0 Introduction Indian Point Unit 3 Technical Specification (TS) 5.6.8 Steam Generator Tube Inspection Report, requires Entergy Nuclear Northeast to submit a report to the NRC within 180days after initial entry into Mode 4 following a steam generator inspection performed inaccordance with Technical Specification 5.5.8, Steam Generator (SG) Program.

Thereport shall include:a. The scope of inspections performed on each SG,b. Active degradation mechanisms found,c. Nondestructive examination techniques utilized for each degradation mechanism,

d. Location, orientation (if linear),

and measured sizes (if available) of service inducedindications,

e. Number of tubes plugged during the inspection outage for each active degradation mechanism,

f. Total number and percentage of tubes plugged to date,g. The results of condition monitoring, including the results of tube pulls and in-situtesting, andh. The effective plugging percentage for all plugging in each SG.Entergy performed a SG inspection in March 2013 during refueling outage 3R17. Thisinspection was the 7th in-service inspection (ISI) following SG replacement in 1989 andthe 1st of 2 scheduled inspections in the 2nd inspection period. The unit initially enteredMODE 4 following this inspection on March 25, 2013.2.0 Steam Generator

Background

The original Westinghouse Model 44 SG's at Indian Point 3 were replaced in 1989 withWestinghouse Model 44F SG's. Each SG has 3214 tubes made from thermally treatedAlloy 690. The nominal OD of each tube is .875 in. and the nominal tube wall is .050 in.thick. At the time of the 2013 refueling outage (3R1 7) at Indian Point 3, the steamgenerators had accumulated approximately 205 effective full power months (EFPM) ofoperation since the first in-service inspection performed in 1990. Refueling outage 3R17was the first of two refueling outages in the second inspection period of 108 EFPM asdefined in section 5.5.8.d.2 of Technical Specifications and the first scheduled inspection of the period. The steam generator inspections were performed in March 2013.Indian Point 3 Steam Generator Primary Inspection PlanOutage Year Cycle SG Inspection Sequential NotesEFPM Cumulative Period Inspection EFPM EFPM Period3R07 1990 13 13 N/A n/a First ISI 3R08 1992 13.6 26.6 13.6 First3R09 1997 18.6 45.2 32.23R10 1999 21.5 66.7 53.73R12 2003 39.7 106.4 93.4 Skip I outage3R14 2007 44.7 151.1 138.1 Skip 1 outage3R17 2013 67 218.1 67 Second Skip 2 outages3R19 2017 45 est. 263 est. 112 est. Skip 1 outage3R21 2021 45 est. 308 est. 45 est. Third Skip 1 outage3R22 2023 22.5 est. 330 est. 67.5 est. Skip 1 outage3.0 Required Report Content -The following information is provided as required in Section5.6.8 of IP3 Technical Specifications a) Scope of Inspections The eddy current examination scope consisted of the acquisition of 50% of all tubesin all four steam generators full length with a bobbin probe, 60% of the hot leg 1stspan and 22% cold leg 1St span with an X-probe array coil probe, 50% of rows 1 and2 u-bends with the single coil +Pt rotating probe. In addition, tubes containing indications from previous examinations were examined.

All indications identified during the bobbin coil had a diagnostic examination performed with the +Pt coil. Thedata analysis scope included the bobbin coil data, the array coil data, all +Pt coildata, and AVB position verification.

In addition to the eddy current inspections, visual inspections were performed on alltube plugs and on the primary bowl drain area.Sludge lancing and Foreign Object Search and Retrieval (FOSAR) was performed onthe secondary side of all SG's. Secondary side Steam Drum and Top Tube SupportPlate (TTSP) inspections were performed on 2 SG's.b) Active Degradation Mechanisms No active degradation mechanisms were found during the SG inspection in 3R17.c) Nondestructive Examination Techniques NDE Techniques used for Potential Degradation Mechanisms Technique EPRI ETSS Degradation Mechanism Bobbin 96004.1 (Rev 13) Wear at AVB supports, support plates & FDBBobbin 27091.2 (Rev 0) Loose part volumetric wear, part not presentBobbin 27091.3 (Rev 1) Loose part volumetric wear, part not present+Pt 10908.4 (Rev 1) Wear at AVB locations

+Pt 21998.1 (Rev 4) Freespan Volumetric

+Pt 27901.1 -27907.1 (Rev 1) Freespan Volumetric

+Pt 96910.1 (Rev 10) Wear at supports and PLP wear part presentArray 20200.1 (Rev 5) OD Circ indications (ODSCC) at TTS andExpansion Transitions d) Service Induced Indications There were no service induced indications detected during 3R17e) Number of Tubes Plugged by Mechanism for 3R17No tubes were plugged during 3R17f) Tubes Plugged to DateSG 31 SG 32 SG 33 SG 34 TotalTotal Number of Tubes 3214 3214 3214 3214 12856Tubes Plugged Pre-Service 0 0 0 2 2Tubes Plugged in Prior Outages 3 6 3 2 14Tubes Plugged in 3R17 0 0 0 0 0Total Tubes Plugged to Date 3 6 3 4 16% of Tubes Plugged to Date 0.09% 0.19% 0.09% 0.12% 0.12%g) Condition Monitoring ResultsNo tubes were found with newly-formed degradation.

There are eight smallvolumetric indications, created in 2001 as a result of sludge lance rail wear, that arestill present, unchanged.

The eight indications did not exceed condition monitoring limits. There was no detectable SG primary-to-secondary leakage during theprevious operating period. Therefore, all of the steam generator performance criteriawere met for the three previous operating cycles. Because the tube degradation found was sized less than the condition monitoring limit, in situ pressure testing wasneither required nor performed.

No tube pulls were performed.

Tube plug andprimary bowl drain inspections had no findings.

Secondary side inspections wereperformed with all results nominal.h) Effective Plugging Percentage Since there are no sleeves installed, the effective tube plugging is equivalent to thepercentage of tubes plugged.4.0 Attachments a) SG Tubesheet Mapb) SG Landmark Information Indian Point 3 Steam Generator Tubesheet Map6ZILn M r 0) rN LO M 0) -0) V) 0l N U -t~t c'IT'-NMCO

'J MNCNCN CNN- ----Col24.(DI-NN0zcucuH Indian Point _..._.Steam Generator Location Landmarks AV2 AV3AV1 AV46H 6C5H 5C4H 4C3H 3C2H 2C1H 1CBPH BPCTSHTEH TECWestinghouse Model 44FSteam Generator LigandAV = Anti-Vibration Bar (AVB)C = cold legH = hot leg# = support plate (TSP)BP = baffle plate (FDB)TS = tubesheet TE = tube end