NL-14-113, Steam Generator Examination Program Results 2014 Refueling Outage (2R21)
| ML14262A059 | |
| Person / Time | |
|---|---|
| Site: | Indian Point  |
| Issue date: | 09/08/2014 |
| From: | Ventosa J Entergy Nuclear Operations |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| NL-14-113 | |
| Download: ML14262A059 (20) | |
Text
%OEntergy Indian Point Energy Center 450 Broadway, GSB P.O. Box 249 Buchanan, N.Y. 10511-0249 Tel.(91) 254-6700 John A. Ventosa Site Vice President September 8, 2014 NL-14-113 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Mail Stop O-Pl-17 Washington, DC 20555-0001
Subject:
Steam Generator Examination Program Results 2014 Refueling Outage (2R21)
Indian Point Unit No. 2 Docket No. 50-247 License No. DPR-26
Dear Sir or Madam:
Enclosed as Attachment 1 is a report of the results of the Indian Point Unit 2 Steam Generator Examination Program conducted during the 2014 refueling outage, submitted pursuant to Technical Specification 5.6.7.
No new regulatory commitments are being made by Entergy in this correspondence.
Should you or your staff have any questions regarding this matter, please contact Mr. Robert.
Walpole, Manager, Regulatory Assurance at (914) 254-6710.
Sincerely, JAV/cbr hoe
NL-14-113 Docket No. 50-247 Page 2 of 2 Attachment 1: Steam Generator Examination Program Results, 2014 Refueling Outage Attachment 1-A: Service (2R21)
Induced Indication Tables by Steam Generator Attachment 1-B: Listing of Individual Tubes Plugged This Inspection Attachment 1-C: Steam Generator Tubesheet Map Attachment 1-D: Steam Generator Landmark Information cc: Mr. William M. Dean, Mr. Douglas Pickett, Regional Administrator, NRC Region Senior Project Manager, I NRC Resident Inspectors NRC NRR DORL Mrs. Bridget Frymire, Office, Indian Point New York State Public Energy Center Service Commission
ATTACHMENT 1 TO NL-14-113 Steam Generator Examination Program Results 2014 Refueling Outage (2R21)
Entergy Nuclear Operations, Inc.
Indian Point Unit No. 2 Docket No. 50-247
Docket No. 50-247 NL-14-113 Attachment 1 Page 1 of 5 Indian Point Unit 2 Steam Generator Examination Program Results 2014 Refueling Outaae (2R21) 1.0 Introduction Indian Point Unit 2 Technical Specification (TS) 5.6.7 Steam Generator Tube Inspection Report, requires Entergy Nuclear Northeast to submit a report to the NRC within 180 days after initial entry into Mode 4 following a steam generator inspection performed in accordance with Technical Specification 5.5.7, Steam Generator (SG) Program. The report 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 induced indications,
- 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-situ testing, and
- h. The effective plugging percentage for all plugginig in each SG.
Entergy performed a SG inspection in March 2014 during refueling outage 2R21. This inspection was the 4 th in-service inspection (ISI) following SG replacement in 2000 and the 1 st of 2 scheduled inspections in the 2 nd inspection period. IP2 initially entered MODE 4 following this inspection on March 15, 2014.
2.0 Steam Generator Background The original Westinghouse Model 44 SG's at Indian Point 2 were replaced in 2000 with Westinghouse Model 44F SG's. Each SG has 3214 tubes made from thermally treated Alloy 600. The nominal OD of each tube is .875 in. and the nominal tube wall is .050 in.
thick. At the time of the 2014 refueling outage (2R21) at Indian Point 2, the steam generators had accumulated approximately 126 effective full power months (EFPM) of operation since the first in-service inspection performed in 2002. Refueling outage 2R21 was the first of two refueling outages in the second inspection period of 90 EFPM as defined in Section 5.5.7.d.2 of Technical Specifications and the first scheduled inspection of the period. The steam generator inspections were performed in March 2014.
Docket No. 50-247 NL-14-113 Attachment 1 Page 2 of 5 Indian Point 2 Steam Generator Primary Inspection Plan Outage Year Cycle SG Inspection Sequential Notes EFPM Cumulative Period Inspection EFPM EFPM Period 2R15 2002 20.6 20.6 N/A N/A First ISI 2R16 2004 22 42.6 22 First No Inspection 2R17 2006 16.6 59.2 38.6 First 2R18 2008 21.8 81 60.4 First No Inspection 2R19 2010 22.2 103.2 82.6 First 2R20 2012 21.3 124.5 103.9 First No Inspection 2R21 2014 22.4 146.9 22.4 Second 2R22 2016 22 est. 169 (est) 44 (est) Second No Inspection 2R23 2018 22 est. 191 (est) 66 (est) Second 2R24 2020 22 est. 213 (est) 88 (est) Second No Inspection 3.0 Required Report Content - The following information is provided as required in Section 5.6.7 of IP2 Technical Specifications a) Scope of Inspections The eddy current examination scope consisted of the acquisition of 50% of all tubes in all four steam generators full length with a bobbin probe, 60% of the hot leg 1st span and 22% cold leg 1 st span with an X-probe array coil probe, 50% of rows 1 and 2 u-bends with the single coil +Pt rotating probe. In addition, tubes containing indications from previous examinations were examined. All new indications identified during the bobbin coil had a diagnostic examination performed with the +Pt coil. The data analysis scope included the bobbin coil data, the array coil data, all +Pt coil data, and Anti-Vibration Bar (AVB) position verification.
In addition to the eddy current inspections, visual inspections were performed on all tube plugs and on the primary bowl drain area (bowl cladding integrity inspection).
Sludge lancing and Foreign Object Search and Retrieval (FOSAR) was performed on the secondary side of all SG's. Secondary side Steam Drum and Top Tube Support Plate (TTSP) inspections were performed on 21 and 22 SG's.
b) Active Degradation Mechanisms AVB wear and Tube Support Plate (TSP) wear were the only active degradation mechanisms found during the SG inspection in 2R21. 5 tubes were preventatively plugged as a result of AVB wear. The largest AVB wear indication was measured at 38% through wall in Steam Generator 21 tube Row 33 Column 34. In 2R21, one TSP wear indication was identified with 8% TW depth which did not challenge any condition monitoring criteria.
Docket No. 50-247 NL-14-113 Attachment 1 Page 3 of 5 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 & FDB Bobbin 27091.2 (Rev 1) Loose part volumetric wear, part not present Bobbin 27091.3 (Rev 1) Loose part volumetric wear, part not present Bobbin 96005.2 (Rev 9) Freespan pitting Bobbin 96008.1 (Rev 14) Axial ODSCC at sludge pile region Bobbin 24013.1 (Rev 2) Axial ODSCC in freespan dings Bobbin 128411 (Rev 3) Axial ODSCC at drilled tube support structure Bobbin 128413 (Rev 3) Axial ODSCC in freespan
+Pt 10908.4 (Rev 1) Wear at AVB locations
+Pt 128424 (Rev 3) Axial ODSCC at drilled TSP's
+Pt 128425 (Rev 3) Axial ODSCC at broached TSP's
+Pt 21409.1 (Rev 7) Axial ODSCC at support structures
+Pt 111524 (Rev 0) Circ. PWSCC at expansion transitions
+Pt 20511.1 (Rev 8) Axial PWSCC at expansion transitions
+Pt 21410.1 (Rev 6) Circ. ODSCC at expansion transitions
+Pt 22842.3 (Rev 5) Circ. ODSCC at dented tube supports
+Pt 21998.1 (Rev 4) Freespan volumetric
+Pt 27901.3
+Pt.27907.3- -(RLoose 27907.3 (Rev 1) part wear Morphology dependent
+Pt 96511.2 (Rev 16) PWSCC, low row u-bend regions
+Pt 99997.1 (Rev 10) PWSCC, HF, low row u-bend regions
+Pt 96910.1 (Rev 10) Wear at supports and PLP wear Array 20400.1 (Rev 5)
.20402.1 (Rev 5) Circ & Axial ODSCC at US, support structure Array 20500.1 (Rev 4) Axial & Circ PWSCC indications at TTS 20501.1 (Rev 4) d) Service Induced Indications The only service induced indications detected during 2R21 were wear indications.
Tables A-1, A-2, A-3 and A-4 of Attachment 1-A list all service induced wear indications detected during 2R21, by Steam Generator, including which tubes were repaired and which tubes were left in service as a result of eddy current inspections.
e) Number of Tubes Plugged by Mechanism For this inspection two active degradation mechanisms were present, AVB wear and TSP wear. 5 tubes were preventatively plugged due to AVB wear. No tubes were plugged due to TSP wear. Additionally, 9 tubes were preventatively plugged and stabilized due to foreign objects which were left in the SG's. One foreign object in SG 21 was dispositioned by preemptively plugging and stabilizing 4 tubes. One
Docket No. 50-247 NL-14-113 Attachment 1 Page 4 of 5 foreign object in SG 23 was dispositioned by preemptively plugging and stabilizing 5 tubes. No associated tube wear was identified with either of these foreign objects.
Degradation Mechanism SG 21 SG 22 SG 23 SG 24 Total AVB Wear 2 0 3 0 5 TSP Wear 0 0 0 0 0 Totals 2 0 3 0 5 f) Tubes Plugged to Date SG 21 SG 22 SG 23 SG 24 Total Total Number of Tubes 3214 3214 3214 3214 12856 Tubes Plugged Pre-Service 0 0 0 2 2 Tubes Plugged in Prior Outages 14 5 5 8 32 Tubes Plugged in 2R21 6 0 8 0 14 Total Tubes Plugged to Date 20 5 13 10 48
% of Tubes Plugged to Date 0.6% 0.2% 0.4% 0.3% 0.4%
g) Condition Monitoring Results AVB wear and TSP wear were the only active degradation mechanisms identified during the 2R21 eddy current inspection. 2R21 was the first occurrence of TSP wear in the IP2 steam generators with one indication at 8% TW. None of the indications exceeded condition monitoring limits. There was no detectable SG primary-to-secondary leakage during the previous operating period. Therefore, all of the steam generator performance criteria were met for the two previous operating cycles.
Because the tube degradation found was sized less than the condition monitoring limit, in situ pressure testing was neither required nor performed. No tube pulls were performed.
The tube plug and primary bowl drain (bowl cladding integrity) 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. 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 45 lbs of deposit material removed from the 4 steam generators. The feed ring, J nozzles, primary separators and all associated welds and hardware were in satisfactory condition and were solid and intact. All J nozzles in both steam generators were visually inspected, both externally and internally 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, with a few areas showing minor signs
Docket No. 50-247 NL-14-113 Attachment 1 Page 5 of 5 of erosion/corrosion. The AVB position verification results were compared to the 2000 baseline examination data to compare the AVB insertion depths. The comparison confirmed that the insertion depths have not changed from the 2000 baseline examination.
A Condition Monitoring assessment was performed, on a defect-specific basis, to demonstrate compliance with integrity criteria by the comparison of 2R21 NDE measurements with calculated burst and leakage integrity limits. Calculated integrity limits, including consideration for appropriate uncertainties, burst and leak analytical correlations, material properties, NDE technique, and analyst uncertainties were provided in the degradation assessment report. All indications in this inspection were below the calculated integrity limits and, therefore, met integrity requirements without further testing. Based upon the inspection results, all four steam generators were found to be in compliance with Condition Monitoring requirements.
h) Effective Plugging Percentage Since there are no sleeves installed, the effective tube plugging is equivalent to the percentage of tubes plugged.
Docket No. 50-247 NL-14-113 Attachment 1-A Page 1 of 6 ATTACHMENT 1-A TO NL-14-113 Service Induced Indication Tables by Steam Generator
Docket No. 50-247 NL-14-113 Attachment 1-A Page 2 of 6 Table A-1 SG 21 Service Induced Indications - Wear - 2R21 Count SG Row Column Volts % TW Locn Inch Repair or Leave in service 1 21 20 30 0.23 11 AV2 -0.26 Leave in Service 2 21 20 30 0.2 10 AV1 -0.14 Leave in Service 3 21 26 64 0.71 20 AV3 0.16 Leave in Service 4 21 26 64 0.33 11 AV2 0.05 Leave in Service 5 21 27 38 0.29 12 AV2 -0.16 Leave in Service 6 21 27 63 0.28 10 AV4 -0.28 Leave in Service 7 21 27 63 0.37 12 AV2 -0.16 Leave in Service 8 21 29 19 0.2 10 AV3 -0.19 Leave in Service 9 21 29 64 0.3 10 AV2 0.00 Leave in Service 10 21 30 37 0.27 11 AV4 0.07 Leave in Service 11 21 30 37 0.32 13 AV3 -0.14 Leave in Service 12 21 30 38 0.22 10 AV3 -0.14 Leave in Service 13 21 30 47 1.43 30 AV3 -0.24 Leave in Service 14 21 30 47 0.92 24 AV2 0.21 Leave in Service 15 21 30 47 0.69 19 AVM -0.21 Leave in Service 16 21 30 47 0.38 12 AV4 0.14 Leave in Service 17 21 30 50 0.25 10 AV3 -0.21 Leave in Service 18 21 31 57 0.33 11 AV3 0.71 Leave in Service 19 21 31 57 0.49 15 AV2 0.12 Leave in Service 20 21 31 57 0.28 10 AVI -0.14 Leave in Service 21 21 32 39 0.32 11 AVM -0.12 Leave in Service 22 21 33 29 0.21 10 AV3 0.09 Leave in Service 23 21 33 29 0.24 11 AV4 -0.16 Leave in Service 24 21 33 33 0.82 27 AV3 0.16 Removed From Service 25 21 33 33 1.15 32 AV2 0.16 Removed From Service 26 21 33 34 0.26 12 AV4 -0.02 Removed From Service 27 21 33 34 1.43 36 AV3 0.26 Removed From Service 28 21 33 34 1.61 38 AV2 -0.02 Removed From Service 29 21 33 34 1.53 37 AVI 0.26 Removed From Service 30 21 33 37 0.23 11 AV2 -0.17 Leave in Service 31 21 33 38 0.31 12 AV3 -0.17 Leave in Service 32 21 33 38 0.33 13 AV2 -0.19 Leave in Service 33 21 33 46 0.28 12 AV2 0.07 Leave in Service 34 21 33 46 0.33 13 AVI -0.02 Leave in Service 35 21 34 47 0.32 11 AV3 -0.21 Leave in Service 36 21 34 47 0.47 15 AV2 0.21 Leave in Service 37 21 34 60 0.4 13 AV4 0.42 Leave in Service 38 21 34 60 0.61 18 AV2 -0.52 Leave in Service 39 21 34 60 0.91 23 AVi -0.26 Leave in Service 40 21 35 70 0.34 11 AV3 -0.21 Leave in Service 41 21 35 70 0.3 10 AV2 -0.21 Leave in Service
Docket No. 50-247 NL-14-113 Attachment 1-A Page 3 of 6 42 21 37 36 0.23 11 AV1 -0.07 Leave in Service 43 21 37 47 0.34 13 AV3 -0.19 / Leave in Service 44 21 37 47 0.32 13 AV1 -0.19 Leave in Service 45 21 37 54 0.36 14 AV3 -0.19 Leave in Service 46 21 38 68 0.23 10 AV2 0.05 Leave in Service 47 21 40 57 0.32 11 AV4 -0.23 Leave in Service 48 21 40 57 0.28 10 AV3 -0.28 Leave in Service 49 21 40 67 0.24 10 AV3 -0.16 Leave in Service 50 21 41 28 0.36 11 AVi -0.61 Leave in Service 51 21 41 39 0.28 12 AV3 -0.24 Leave in Service 52 21 42 40 0.25 10 AV2 0.07 Leave in Service 53 21 44 37 0.21 10 AV2 -0.16 Leave in Service 54 21 45 43 0.23 10 AV2 -0.16 Leave in Service 55 21 45 48 0.23 10 AV1 0.02 Leave in Service 56 21 45 52 0.25 10' AV4 -0.19 Leave in Service 57 21 45 52 0.26 11 AV3 -0.19 Leave in Service
Docket No. 50-247 NL-14-113 Attachment 1-A Page 4 of 6 Table A-2 SG 22 Service Induced Indications - Wear - 2R21 Count SG Row Column Volts % TW Locn Inch Repair or Leave in service 1 22 23 54 0.81 27 AV4 0.23 Leave in Service 2 22 23 54 0.41 17 AV3 -0.09 Leave in Service 3 22 23 54 0.39 16 AV2 -0.18 Leave in Service 4 22 23 54 0.45 18 AVI -0.23 Leave in Service 5 22 30 35 0.24 10 AVI -0.19 Leave in Service 6 22 30 35 0.29 12 AV2 -0.28 Leave in Service 7 22 30 53 0.34 12 AV3 -0.22 Leave in Service 8 22 30 53 0.31 11 AV2 -0.09 Leave in Service 9 22 30 53 0.35 12 AVi -0.20 Leave in Service 10 22 30 67 0.28 10 AV2 0.09 Leave in Service 11 22 36 41 0.31 12 AVI 0.12 Leave in Service 12 22 36 41 0.29 11 AV2 0.14 Leave in Service 13 22 36 44 0.51 16 AV3 -0.23 Leave in Service 14 22 36 44 1.31 30 AV2 -0.31 Leave in Service 15 22 36 44 0.51 16 AV2 0.14 Leave in Service 16 22 36 44 0.60 18 AV1 -0.23 Leave in Service 17 22 36 62 0.52 17 AV2 -0.16 Leave in Service 18 22 36 64 0.28 13 AV2 -0.11 Leave in Service 19 22 36 64 0.34 15 AVi -0.20 Leave in Service 20 22 37 53 0.26 12 AVI -0.20 Leave in Service 21 22 37 54 0.37 14 AV2 -0.18 Leave in Service 22 22 37 54 0.33 14 AVI -0.18 Leave in Service 23 22 37 69 0.20 10 AV2 -0.16 Leave in Service 24 22 37 73 0.32 14 AV3 -0.18 Leave in Service 25 22 37 73 0.50 20 AVI 0.11 Leave in Service 26 22 38 49 0.53 20 AV2 -0.27 Leave in Service 27 22 38 49 0.44' 18 AVI -0.18 Leave in Service 28 22 38 55 0.57 21 AV2 -0.25 Leave in Service 29 22 38 55 0.31 14 AVi -0.20 Leave in Service 30 22 40 57 0.95 29 AV2 0.20 Leave in Service 31 22 40 57 0.30 13 AV3 -0.16 Leave in Service 32 22 41 52 0.41 17 AV2 0.11 Leave in Service 33 22 41 52 0.31 14 AVI -0.04 Leave in Service 34 22 42 62 0.36 15 AV4 -0.18 Leave in Service
Docket No. 50-247 NL-14-113 Attachment 1-A Page 5 of 6 Table A-3 SG 23 Service Induced Indications - Wear - 2R21 Count SG Row Column Volts % TW Locn Inch Repair or Leave in service 1 23 29 55 0.63 17 AV4 0.05 Leave in Service 2 23 29 55 0.32 10 AV2 -0.17 Leave in Service 3 23 30 22 0.41 11 AVi 0.12 Leave in Service 4 23 32 62 0.38 10 AVI 0.00 Leave in Service 5 23 32 63 0.35 10 AVI 0.14 Leave in Service 6 23 33 31 0.53 13 AV2 0.17 Leave in Service 7 23 34 44 0.46 12 AV2 0.26 Leave in Service 8 23 34 62 0.41 11 AV1 0.20 Leave in Service 9 23 34 62 0.68 16 AV2 -0.14 Leave in Service 10 23 34 64 0.55 14 AV4 -0.24 Removed From Service 11 23 34 64 1.88 32 AV3 0.26 Removed From Service 12 23 34 64 1.13 23 AV2 -0.05 Removed From Service 13 23 34 64 0.58 14 AVI -0.17 Removed From Service 14 23 34 65 0.40 10 AV3 -0.19 Leave in Service 15 23 34 65 0.47 12 AV2 -0.19 Leave in Service 16 23 35 46 0.43 11 AV2 0.30 Leave in Service 17 23 35 46 0.56 14 AV3 0.22 Leave in Service 18 23 35 59 0.87 19 AV2 -0.22 Leave in Service 19 23 35 59 1.25 24 AV3 -0.26 Leave in Service 20 23 36 60 0.45 11 AVi -0.02 Leave in Service 21 23 38 62 0.60 14 AV2 -0.16 Leave in Service 22 23 39 56 1.56 28 AV3 -0.09 Leave in Service 23 23 39 56 0.91 20 AVI -0.24 Leave in Service 24 23 39 59 0.77 18 AV1 -0.14 Removed From Service 25 23 39 59 2.58 36 AV3 -0.24 Removed From Service 26 23 40 53 0.58 14 AV4 0.22 Leave in Service 27 23 40 58 0.82 19 AV3 -0.31 Leave in Service 28 23 40 58 0.66 16 AV2 -0.21 Leave in Service 29 23 41 40 0.52 14 AV4 -0.19 Removed From Service 30 23 41 40 0.62 16 AV3 -0.21 Removed From Service 31 23 41 40 1.70 31 AV2 -0.26 Removed From Service 32 23 41 40 0.40 11 AVi -0.19 Removed From Service 33 23 41 43 0.38 10 AVI 0.16 Leave in Service 34 23 41 64 0.50 14 AV2 -0.24 Leave in Service
Docket No. 50-247 NL-14-113 Attachment 1-A Page 6 of 6 Table A-4 SG 24 Service Induced Indications - Wear - 2R21 Count SG Row Column Volts % TW Locn Inch Repair or Leave in service 1 24 28 64 0.48 16 AV4 -0.25 Leave in Service 2 24 28 64 0.46 15 AV3 0.09 Leave in Service 3 24 28 73 0.40 14 AV4 -0.16 Leave in Service 4 24 32 45 0.41 11 AV2 -0.02 Leave in Service 5 24 32 45 0.44 11 AVI -0.18 Leave in Service 6 24 32 69 0.51 16 AV3 -0.18 Leave in Service 7 24 32 69 0.42 14 AV2 -0.18 Leave in Service 8 24 33 63 0.70 17 AV4 -0.18 Leave in Service 9 24 33 63 0.37 10 AV3 0.27 Leave in Service 10 24 33 63 0.55 14 AV2 -0.18 Leave in Service 11 24 33 64 0.77 18 AV4 0.13 Leave in Service 12 24 33 64 0.85 20 AV3 -0.25 Leave in Service 13 24 33 64 0.34 10 AV2 -0.18 Leave in Service 14 24 33 64 0.36 10 AVI -0.27 Leave in Service 15 24 33 69 0.60 15 AV3 -0.13 Leave in Service 16 24 33 69 0.40 11 AVI -0.18 Leave in Service 17 24 33 71 0.43 12 AV4 -0.22 Leave in Service 18 24 33 71 0.40 11 AV3 -0.18 Leave in Service 19 24 33 71 0.52 14 AV2 -0.20 Leave in Service 20 24 33 71 0.36 10 AVi 0.09 Leave in Service 21 24 34 59 0.34 10 AV3 0.00 Leave in Service 22 24 34 59 0.59 14 AV2 0.14 Leave in Service 23 24 34 59 0.73 17 AVI 0.56 Leave in Service 24 24 34 65 0.33 12 AV2 -0.13 Leave in Service 25 24 35 72 0.40 14 AV3 -0.18 Leave in Service 26 24 35 73 0.34 10 AV3 -0.22 Leave in Service 27 24 36 32 0.32 10 AV3 -0.16 Leave in Service 28 24 36 32 0.73 19 AV2 -0.29 Leave in Service 29 24 36 71 0.28 10 AV3 -0.16 Leave in Service 30 24 36 71 1.01 26 AV2 -0.25 Leave in Service 31 24 36 71 0,39 13 AVI -0.20 Leave in Service 32 24 37 25 0.42 12 AVI -0.20 Leave in Service 33 24 37 33 0.33 10 AVI -0.22 Leave in Service 34 24 37 70 0.43 12 AV2 0.11 Leave in Service 35 24 38 60 0.41 11 AV3 -0.22 Leave in Service 36 24 38 60 0.36 10 AV2 -0.16 Leave in Service 37 24 41 32 0.26 10 AVI -0.20 Leave in Service 38 24 41 65 0.28 8 05C 0.35 Leave in Service 39 24 43 39 0.50 17 AVI -0.16 Leave in Service 40 24 45 41 0.96 27 AV3 -0.25 Leave in Service 41 24 45 41 0.55 18 AV2 -0.18 Leave in Service
Docket No. 50-247 NL-14-113 Attachment 1-B Page 1 of 2 ATTACHMENT 1-B TO NL-14-113 Listing of Individual Tubes Plugged This Inspection
Docket No. 50-247 NL-14-113 Attachment 1-B Page 2 of 2 Count SG Row Col Reason for Plugging Stabilized 1 21 33 33 Preventative due to AVB Wear No 2 21 33 34 Preventative due to AVB Wear No 3 21 14 71 Preventative to bound a secondary side foreign object Yes which could not be removed 4 21 1 72 Preventative to bound a secondary side foreign object Yes 21 5 14 72 which could not be removed to bound Preventative which a secondary side foreign object Yes 5 21 15 72 could not be removed 73 to bound Preventative which a secondary side foreign object Yes 6 21 15 could not be removed Preventative to bound a secondary side foreign object 7 23 32 24 which could not be removed Yes Preventative which to bound a secondary side foreign object Yes 8 23 33 24 could not be removed Preventative to bound a secondary side foreign object 9 23 33 25 which could not be removed Yes 10 23 34 25 Preventative which to bound a secondary could side foreign object not be removed Yes 11 6 Preventative to bound 2 11 33423 26which a secondary could side foreign object not be removed Yes 12 23 34 64 Preventative due to AVB Wear No 13 23 39 59 Preventative due to AVB Wear No 14 23 41 40 Preventative due to AVB Wear No
Docket No. 50-247 NL-14-113 Attachment 1-C Page 1 of 2 ATTACHMENT 1-C TO NL-14-113 Steam Generator Tubesheet Map
Docket No. 50-247 NL-14-113 Attachment 1 -C Page 2 of 2 Indian Point 2 Steam Generator Tubesheet Map 6
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Docket No. 50-247 NL-14-113 Attachment 1-D Page 1 of 2 ATTACHMENT 1-D TO NL-14-113 Steam Generator Landmark Information
Docket No. 50-247 NL-14-113 Attachment 1-D Page 2 of 2 Indian Point 2 Steam Generator Location Landmarks AV2 AV3 AVi AV4 6H -4 - 6C 5H m - 5C 4H -+- - 4C 3H 4- 3C 2H 4- 2C 1H - B -0 -1C BPH - - BPC TSH a TSC TEH .1 /-*.*/,////////.. TEC 5(-,-rr//.///////<
Westinghouse Model 44F Steam Generator Legend AV = Anti-Vibration Bar (AVB)
C = cold leg H = hot leg
- = support plate (TSP)
BP = baffle plate (FDB)
TS = tubesheet TE = tube end