NL-18-063, Submission of IP2 Steam Generator Examination Program Results for the 2018 (2R23) Refueling Outage in Accordance with Technical Specification 5.6.7

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Submission of IP2 Steam Generator Examination Program Results for the 2018 (2R23) Refueling Outage in Accordance with Technical Specification 5.6.7
ML18254A183
Person / Time
Site: Indian Point Entergy icon.png
Issue date: 08/13/2018
From: Vitale A
Entergy Nuclear Northeast
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NL-18-063
Download: ML18254A183 (22)
v • d • e


Text

    • --=- Entergx *,

Entergy Nuclear Northeast Indian Point Energy Center 450 Broadway, GSB P.O. Box249 Buchanan, NY 10511-0249 Tel 914 254 6700 Anthony J. Vitale Site Vice President August 13, 2018 NL-18-063 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk 11555 Rockville Pike, OWFN-2 F1 Rockville, MD 20852-2738

SUBJECT:

Submission of IP2 Steam Generator Examination Program Results for the 2018 (2R23) Refueling Outage in Accordance with Technical Specification 5.6. 7 Indian Point Unit No. 2 Docket No. 50-247 License No. DPR-26

Dear Sir or Madam:

Entergy Nuclear Operations, Inc. (Entergy) is providing in the Enclosure, the Indian Point Unit 2 Steam Generator Examination Program Results 2018 Refueling Outage (2R23), as required by Indian Point Unit No. 2 Technical Specification 5.6.7. Technical Specification 5.6.7 requires that a report be submitted within 180 days after the initial entry into MODE 4 following completion of an inspection performed in accordance with the Technical Specification 5.5. 7, Steam Generator (SG) Program. The subject inspection was performed in April 2018 during the Spring 2018 refueling outage (2R23). The unit initially entered MODE 4 following this inspection on April 16, 2018. This inspection was the 5th in-service inspection (ISi) following SG replacement in 2000 and the 2nd of three 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 600 tubes. At the time of the inspection, the steam generators had accumulated approximately 170 effective full power months {EFPM) of operation since the first in-service inspection performed in 2002. Based upon the inspection results, all four steam generators were found to be in compliance with Condition Monitoring requirements.

There are no commitments made or revised in this letter.

NL-18-063 Docket No. 50-247 Page 2 of 2 Should you have any questions concerning this letter or require additional information, please contact Mr. Robert Walpole, Manager, Regulatory Assurance at (914) 254-6710.

Sincerely, AJV/gd

Enclosure:

Indian Point Unit 2 Steam Generator Examination Program Results 2018 Refueling Outage (2R23) cc: Mr. David Lew, Regional Administrator, NRG Region 1 Mr. Richard Guzman, Senior Project Manager, NRG NRR DORL NRG Resident Inspector's Office Ms. Alicia Barton, President and CEO, NYSERDA Ms. Bridget Frymire, New York State Dept. of Public Service

ENCLOSURE to NL-18-063 Indian Point Unit 2 Steam Generator Examination Program Results 2018 Refueling Outage (2R23)

ENTERGY NUCLEAR OPERATIONS, INC.

INDIAN POINT NUCLEAR GENERATING UNIT NO. 2 DOCKET NO. 50-247

NL-18-063 Enclosure Page 1 of 19 Indian Point Unit 2 Steam Generator Examination Program Results 2018 Refueling Outage (2R23) 1.0 Introduction Indian Point Unit 2 (IP2) Technical Specification 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 (SG) inspection performed in accordance with Technical Specification 5.5.7, Steam Generator Program.

The report shall include:

a. The scope of inspections performed on each SG,
b. 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 degradation mechanism,
f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each SG, and
g. The results of condition monitoring, including the results of tube pulls and in-situ testing.
h. The primary to secondary leakage rate observed in each SG (if it is not practical to assign the leakage to an individual SG, the entire primary to secondary leakage should be conservatively assumed to be from one SG) during the cycle preceding the inspection which is the subject of the report
i. The calculated accident leakage rate from the portion of the tubes below 18.9 inches from the top of the tubesheet for the most limiting accident in the most limiting SG.

In addition, if the calculated accident leakage rate from the most limiting accident is less than 1. 75 times the maximum primary to secondary leakage rate, the report should describe how it was determined, and

j. The results of monitoring for tube displacement (slippage). If slippage is discovered, the implications of the discovery and corrective action shall be provided.

Entergy performed a SG inspection in April 2018 during refueling outage 2R23. This inspection was the 5th in-service inspection (ISi) following SG replacement in 2000 and the 2nd of 3 scheduled inspections in the 2nd inspection period. The unit initially entered MODE 4 following this inspection on April 16, 2018.

IP2 is currently scheduled to permanently shut down in 2020.

NL-18-063 Enclosure Page 2 of 19 2.0 Steam Generator Background The original Westinghouse Model 44 SG's at IP2 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 0.875 inch and the nominal tube wall is 0.050 inch thick. At the time of the 2018 refueling outage (2R23) at IP2, the SG's had accumulated approximately 170 effective full power months (EFPM) of operation since the first in-service inspection performed in 2002. Refueling outage 2R23 was the third of five refueling outages in the second inspection period of 96 EFPM as defined in section 5.5.7.d.2 of Technical Specifications and the second of three scheduled SG inspections within the period. The SG inspections were performed in April 2018.

2R15 2002 20.6 20.6 N/A N/A First ISi 2R17 2006 16.6 59.2 38.6 First Ski f--------'----'""-------1 2R19 2010 22.2 103.2 82.6 Ski 2R21 2014 22.4 146.9 6.3 Second Ski f--------'----'""-------1 2R23 2018 20 190.2 49.6 Ski t--------'----'""------1 2R25 2022 22 est 234.2 est 93.6 est Ski 1 outa e Note: IP2 is scheduled to shutdown in 2020. The information included for 2R25 in 2022 is for information only.

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 Performed on each SG The inspection program, as required by the EPRI Pressurized Water Reactor (PWR)

SG Examination Guidelines, addressed the existing degradation mechanisms observed in Indian Point Unit 2 in prior inspections as well as those regarded as potential degradation mechanisms. The program also addressed inspection requirements related to the implementation of the H* alternate repair criteria (ARC) license amendment. The defined base scope implemented during 2R23 included the following:

  • 33% full length bobbin inspection in each SG including any previously identified degradation which may have been left in service from a previous examination (such as AVB or TSP wear).
  • 50% +POINT probe inspection of the Row 1 and 2 U-bends in tubes that were not inspected during 2R21.

NL-18-063 Enclosure Page 3 of 19

  • Three tube deep +POINT probe inspection of Hot and Cold Leg Top of Tubesheet periphery plus Row 1 and Row 2 tubes from +6 inches to -3 inches about TTS (foreign objects concern); this equated to approximately 22% of the tubes.
  • 100% +POINT probe inspection of bobbin special interest conditions:
  • Any freespan signal with a flaw-like response (DNI, NQI, FSI, etc.).
  • Any signal at a support structure with a flaw-like response (OSI, DNI, etc.).
  • +POINT probe "boxing" of previously and newly reported potential loose parts (PLPs).
  • +POINT probe "boxing" of tubes previously plugged for foreign objects.
  • 50% +POINT probe inspection of historical dents >5V at TSPs and AVBs.
  • 50% +POINT probe inspection of historical freespan dings >5V.
  • +POINT probe inspection of historic BLG reports within -3 inches of the hot leg TTS located on the 33% bobbin program tubes; this ensured that 67% of the BLGs within -3 inches of TTS have been inspected through the combined 2014 and 2018 inspections.
  • +POINT probe inspection of all BLGs greater than 18.0 Volts and OXPs greater than 0.790 inch between TSH-3/-18.9 inches which were included in the 33% base scope bobbin tubes. Inspections performed for this purpose encompassed the full TSH-3/-18.9 inches extent within the tubesheet.
  • 100% tube plug visual inspection from the primary side.
  • Remote visual inspection of the hot and cold leg divider plate-to-stub runner welds, cladding in the vicinity of drain tube welds, lowest points of the channel head bowl, tube-to-tubesheet welds, channel head-to-tubesheet Z-seam weld region and general bowl inspection:

The Indian Point 2R23 SG inspection plan met or exceeded the requirements of the EPRI SG Examination Guidelines, the EPRI SG Integrity Assessment Guidelines and was aligned with the Indian Point SG Program document.

No inspections or cleaning were performed on the secondary side of the SG's during 2R23.

b) Degradation Mechanisms Found AVB wear and Tube Support Plate (TSP) wear were the only existing degradation mechanisms found during the SG inspection in 2R23. 3 tubes were plugged as a result of AVB wear. The largest AVB wear indication was measured at 41 % through wall in Steam Generator 23 tube Row 35 Column 59. In 2R23, two TSP wear indications were identified with 7% and 9% TW depth which did not challenge any condition monitoring criteria. No tubes were plugged for TSP wear indications.

NL-18-063 Enclosure Page 4 of 19 c) Nondestructive Examination Techniques Utilized for each Degradation Mechanism NOE T ec hrnques

. use dfor E"t" xis 1nq an dPt 1a eqra daf10n Mec harnsm s o en t"ID

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Degradation Mecl)anism' <* -**

Technique/ EPRIETSS. ,. .' ~ -,,.. *, ,-

Bobbin 128413 (1) Tube wear at non-dented AVB and TSP intersections, tube wear due to foreign objects, volumetric (not corrosion related).

Diagnostic technique for freespan differential siqnals.

Bobbin 10013.1 (2) Tube wear at <5V dented AVB and TSP intersections

+Pt 10908.1 Tube wear at non-dented AVB intersections, tube wear at <5V dented AVB

+Pt 96910.1 Tube wear at non-dented TSP intersections, tube wear at <5V dented TSP

+Pt 21998.1 Tube wear due to foreign objects, volumetric (not corrosion related). Diagnostic technique for potential manufacturing burnish marks and absolute drift indications.

Bobbin 96010.1 Diagnostic technique for potential manufacturing burnish marks and absolute drift indications.

+Pt 128425 Diagnostic technique for freespan differential signals.

(1) Bobbin coil Appendix I techniques include "hotter" span settings than non-Appendix I techniques that address wear mechanisms. Application of this technique produces improved detection capabilities.

(2) NOE technique is qualified for detection of axial ODSCC at dented supports and is extended for wear mechanisms. Wear of equal depth as ODSCC will produce significantly larger signal amplitudes thus resulting in wear detection at shallower depths compared to ODSCC.

d) Service Induced Indications The only service induced indications detected during 2R23 were wear indications.

Tables A-1, A-2, A-3 and A-4 of Attachment A list all service induced wear indications detected during 2R23, 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 Degradation Mechanism for 2R23 For this inspection two existing degradation mechanisms were present, AVB wear and TSP wear. Three tubes were plugged due to AVB wear (two tubes in SG 23 and one tube in SG 24). No tubes were plugged due to TSP wear. Additionally, three tubes were preventatively plugged and stabilized due to a possible loose part which was detected by eddy current in SG 24. The possible loose part in SG 24 was dispositioned by preemptively plugging and stabilizing 3 tubes. No associated tube wear was identified with this possible loose part indication.

NL-18-063 Enclosure Page 5 of 19 p~gradatiori Me"chanism *

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  • . SG2f;: SG22 )5~2.3 .8G21(. TotaL,::

AVB Wear 0 0 2 1 3 TSP Wear 0 0 0 0 0 Possible Loose Part 0 0 0 3 3 Totals 0 0 2 4 6 f) Tubes Plugged to Date and Effective Plugging Percentage

. **s.c:f24:

SG2J. :sp;~.2'./ :":sci'23*>'

" :'tot~f Total Number of Tubes 3214 3214 3214 3214 12856 Tubes Plugged Pre-Service 0 0 0 2 2 Tubes Plugged in Prior Outages 20 5 13 8 46 Tubes Plugged in 2R23 0 0 2 4 6 Total Tubes Plugged to Date 20 5 15 14 54

% of Tubes Plugged to Date 0.6% 0.2% 0.5% 0.4% 0.4%

Since there are no sleeves installed, the effective tube plugging is equivalent to the percentage of tubes plugged to date.

g) Condition Monitoring Results Mechanical wear at tube AVB and TSP supports are the only two existing degradation mechanisms with AVB wear indications observed in all four SGs and TSP wear in two SGs. None of the indications exceeded condition monitoring limits.

There were a total of six tubes plugged between the four SGs during 2R23. One of the tubes plugged was required in accordance with the plant technical specification while the other five were either precautionary to address a possible loose part or necessary in order to support the Operational Assessment projections. There was no detectable SG primary-to-secondary leakage during the previous operating period. Therefore, all of the SG 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 inspections had no findings. All tube plugs were present and in the correct positions with no evidence of leakage or degradation. All primary bowls were inspected to address Westinghouse NSAL 12-1, Nuclear Regulatory Commission (NRC) License Renewal Interim Staff Guidance LR-ISG-2016-01, and industry OE.

There were no anomalies or degradation detected on the divider plate or tube-to-tubesheet welds during the inspections. However, cladding anomalies were identified in 22 Hotleg, 23 Hotleg, 23 Coldleg, and 24 Coldleg in the primary bowl area. All other primary bowls had no anomalies. The cladding anomalies were characterized by discoloration. An inspection of all anomalies was performed,

NL-18-063 Enclosure Page 6 of 19 measurements were taken, a probing device (dental pick-like tool) was used to determine if any undercutting of the cladding was present and to determine if the cladding in the vicinity of the anomalies was tightly adhered to the channel head.

None of the anomalies exhibited undercutting and all cladding in the vicinity of the anomalies was tightly adhered to the channel head. Based on a detailed engineering assessment, which included similar operating experience at other plants, the SG cladding anomalies do not present a condition which could affect SG operation and therefore, the cladding anomalies were not required to be repaired prior to plant restart.

A Condition Monitoring assessment was performed, on a defect-specific basis, to demonstrate compliance with integrity criteria by the comparison of 2R23 NOE measurements with calculated burst and leakage integrity limits. Calculated integrity limits, including consideration for appropriate uncertainties, burst and leak analytical correlations, material properties, NOE 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 performance criteria requirements without further testing. Based upon the inspection results, all four SG's were found to be in compliance with Condition Monitoring requirements.

h) Primary to Secondary Leakage Rate Observed in Each SG No primary to secondary leakage was present during the steam generator inspection interval.

i) Calculated Accident Leakage Rate No primary to secondary leakage was present during the SG inspection interval, and no leakage is projected by the operational assessment calculations. Therefore, no leakage comparison is to be made and no administrative leakage limit to be set beyond the present SG program and plant Technical Specification requirements.

j) Results of Monitoring for Tube Displacement (Slippage)

All bobbin coil data collected was monitored for tube slippage. No tube slippage was detected.

4.0 Attachments A) Indian Point 2 Service Induced Indication Tables by Steam Generator B) Indian Point 2 Listing of Individual Tubes Plugged This Inspection C) Indian Point 2 Steam Generator Tubesheet Map

0) Indian Point 2 Steam Generator Landmark Information

NL-18-063 Enclosure Page 7 of 19 ATTACHMENT A Indian Point 2 Service Induced Indication Tables by Steam Generator

NL-18-063 Enclosure Page 8 of 19 Table A-1 SG 21 Service Induced Indications - Wear - 2R23 count* SG, *;R.ow.:** .Gcilu'mi:f Volts\ ,%.TVV>

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1 1 21 20 30 0.19 9 AV1 -0.14 Leave in Service 2 21 20 30 0.23 11 AV2 -0.26 Leave in Service 3 21 26 64 0.35 17 AV2 0.05 Leave in Service 4 21 26 64 0.7 24 AV3 0.2 Leave in Service 5 21 27 38 0.29 13 AV2 0.13 Leave in Service 6 21 27 38 0.23 11 AV3 -0.14 Leave in Service 7 21 27 63 0.2 10 AV1 -0.05 Leave in Service 8 21 27 63 0.29 13 AV2 -0.14 Leave in Service 9 21 27 63 0.25 12 AV4 -0.39 Leave in Service 10 21 29 19 0.18 9 AV3 -0.13 Leave in Service 11 21 29 64 0.28 15 AV2 0.05 Leave in Service 12 21 30 37 0.2 10 AV2 -0.16 Leave in Service 13 21 30 37 0.44 17 AV3 -0.15 Leave in Service 14 21 30 37 0.26 12 AV4 0.14 Leave in Service 15 21 30 38 0.22 9 AV3 -0.14 Leave in Service 16 21 30 47 0.8 24 AV1 -0.24 Leave in Service 17 21 30 47 1.05 27 AV2 0.16 Leave in Service 18 21 30 47 1.29 30 AV3 -0.21 Leave in Service 19 21 30 47 0.35 14 AV4 0.17 Leave in Service 20 21 30 so 0.24 14 AV3 -0.07 Leave in Service 21 21 31 26 0.17 11 AV1 -0.11 Leave in Service 22 21 31 57 0.25 11 AV1 -0.11 Leave in Service 23 21 31 57 0.34 14 AV2 0.12 Leave in Service 24 21 31 57 0.23 11 AV3 0.69 Leave in Service 25 21 32 39 0.32 11 AV1 -0.12 Leave in Service 26 21 32 39 0.19 10 AV2 0.07 Leave in Service 27 21 33 29 0.29 13 AV3 0.11 Leave in Service 28 21 33 29 0.22 11 AV4 -0.15 Leave in Service 29 21 33 37 0.21 10 AV2 0.07 Leave in Service 30 21 33 38 0.35 16 AV2 -0.15 Leave in Service 31 21 33 38 0.33 16 AV3 -0.14 Leave in Service 32 21 33 38 0.2 11 AV4 -0.21 Leave in Service 33 21 33 46 0.37 15 AV1 -0.19 Leave in Service 34 21 33 46 0.23 11 AV2 0.09 Leave in Service 35 21 34 47 0.24 11 AV1 -0.19 Leave in Service 36 21 34 47 0.41 16 AV2 0.16 Leave in Service 37 21 34 47 0.28 12 AV3 -0.14 Leave in Service 38 21 34 60 0.72 22 AV1 -0.25 Leave in Service 39 21 34 60 0.46 17 AV2 -0.46 Leave in Service 40 21 34 60 0.36 15 AV4 0.47 Leave in Service 41 21 35 70 0.25 12 AV2 -0.17 Leave in Service

Cour:il .SG' *Row*. *c.o:rur:nn . Volts* JY~TW ""ocri '.:1 Inch *... *>.o
  • R.ebair or:L.:eave .in *service;':.

NL-18-063 Enclosure Page 9 of 19 Count.'* *S'G; :Row: Cqlurnri', *VOits: :.o/ci*tW< *Locn *,/. *Inch_' , <. :RepaiJ or*Leave: in *s-ervice '

42 21 35 70 0.23 11 AV3 -0.14 Leave in Service 43 21 37 36 0.29 15 AVl -0.22 Leave in Service 44 21 37 36 0.23 12 AV2 -0.12 Leave in Service 45 21 37 47 0.29 13 AVl -0.16 Leave in Service 46 21 37 47 0.31 13 AV3 -0.16 Leave in Service 47 21 37 47 0.21 10 AV4 0.11 Leave in Service 48 21 37 54 0.3 13 AV3 -0.23 Leave in Service 49 21 38 68 0.22 10 AV2 -0.1 Leave in Service so 21 40 57 0.25 11 AV3 -0.24 Leave in Service 51 21 40 57 0.27 12 AV4 -0.18 Leave in Service 52 21 40 67 0.27 15 AV3 -0.16 Leave in Service 53 21 41 28 0.15 8 AVl -0.15 Leave in Service 54 21 41 39 0.2 10 AV2 -0.17 Leave in Service 55 21 41 39 0.36 15 AV3 -0.2 Leave in Service 56 21 42 40 0.31 15 AV2 0.1 Leave in Service 57 21 44 37 0.17 9 AV2 -0.08 Leave in Service 58 21 45 43 0.24 11 AV2 -0.16 Leave in Service 59 21 45 52 0.26 12 AV3 -0.16 Leave in Service 60 21 45 52 0.29 13 AV4 -0.15 Leave in Service

NL-18-063 Enclosure Page 10 of 19 Table A-2 SG 22 Service Induced Indications - Wear - 2R23 Co.uni' ;$!3. Rowe:* :corur;np\ Vdlts: ,*%JV\(: :Lc5cii *incl,;; ;;,. :: )Repair. of;teaVe *ih!*service"***.

1 22 9 42 0.21 7 OSH -0.63 Leave in Service 2 22 23 54 0.38 15 AVl -0.24 Leave in Service 3 22 23 54 0.34 14 AV2 0.09 Leave in Service 4 22 23 54 0.37 15 AV3 -0.19 Leave in Service 5 22 23 54 0.68 22 AV4 0.25 Leave in Service 6 22 30 35 0.22 10 AVl -0.18 Leave in Service 7 22 30 35 0.22 10 AV2 -0.25 Leave in Service 8 22 30 53 0.33 15 AVl -0.27 Leave in Service 9 22 30 53 0.39 16 AV2 -0.15 Leave in Service 10 22 30 53 0.39 17 AV3 -0.22 Leave in Service 11 22 30 67 0.24 11 AV2 0.05 Leave in Service 12 22 31 26 0.36 16 AV3 -0.14 Leave in Service 13 22 36 41 0.28 12 AVl 0.17 Leave in Service 14 22 36 41 0.22 10 AV2 0.17 Leave in Service 15 22 36 44 0.59 20 AVl -0.24 Leave in Service 16 22 36 44 0.48 18 AV2 0.19 Leave in Service 17 22 36 44 1.52 33 AV2 -0.28 Leave in Service 18 22 36 44 0.5 18 AV3 -0.33 Leave in Service 19 22 36 62 0.31 13 AVl -0.19 Leave in Service 20 22 36 62 0.64 21 AV2 -0.17 Leave in Service 21 22 36 64 0.25 11 AVl -0.2 Leave in Service 22 22 36 64 0.22 10 AV2 -0.1 Leave in Service 23 22 37 53 0.19 9 AV1 -0.2 Leave in Service 24 22 37 54 0.26 11 AVl 0.1 Leave in Service 25 22 37 54 0.27 12 AV2 -0.21 Leave in Service 26 22 37 73 0.37 14 AVl 0.15 Leave in Service 27 22 37 73 0.29 12 AV3 -0.15 Leave in Service 28 22 38 49 0.42 16 AVl -0.16 Leave in Service 29 22 38 49 0.46 17 AV2 -0.24 Leave in Service 30 22 38 55 0.34 14 AVl -0.27 Leave in Service 31 22 38 55 0.54 19 AV2 -0.19 Leave in Service 32 22 40 57 0.27 12 AVl 0.07 Leave in Service 33 22 40 57 0.84 24 AV2 0.16 Leave in Service 34 22 40 57 0.28 12 AV3 -0.28 Leave in Service 35 22 41 52 0.27 12 AVl -0.03 Leave in Service 36 22 41 52 0.36 15 AV2 0.1 Leave in Service 37 22 42 62 0.34 14 AV4 -0.13 Leave in Service Tube R9 C42 in BOLD is TSP wear, all other tubes are AVB wear

NL-18-063 Enclosure Page 11 of 19 Table A-3 SG 23 Service Induced Indications - Wear - 2R23

  • ,Count* *sG Row' 'Colurhn* ,VOlts:c: . %T'N Locn . .lncft * .:.* RepairqrLeave in servrce'. '

1 23 29 41 0.23 10 AV2 -0.27 Leave in Service 2 23 29 55 0.25 12 AVl -0.24 Leave in Service 3 23 29 55 0.3 14 AV2 -0.17 Leave in Service 4 23 29 55 0.51 19 AV4 0.05 Leave in Service 5 23 30 22 0.27 13 AVl 0.16 Leave in Service 6 23 32 62 0.39 16 AVl 0 Leave in Service 7 23 32 62 0.3 13 AV2 0 Leave in Service 8 23 32 63 0.26 12 AVl 0.14 Leave in Service 9 23 33 31 0.49 18 AV2 0.21 Leave in Service 10 23 33 31 0.39 15 AV3 -0.21 Leave in Service 11 23 33 31 0.21 10 AV4 -0.21 Leave in Service 12 23 34 44 0.35 15 AV2 0.17 Leave in Service 13 23 34 62 0.37 15 AVl 0.2 Leave in Service 14 23 34 62 0.54 19 AV2 -0.14 Leave in Service 15 23 34 62 0.37 15 AV3 -0.29 Leave in Service 16 23 34 65 0.32 14 AVl 0.1 Leave in Service 17 23 34 65 0.42 17 AV2 -0.19 Leave in Service 18 23 34 65 0.38 16 AV3 -0.19 Leave in Service 19 23 34 65 0.29 13 AV4 -0.13 Leave in Service 20 23 34 70 0.28 13 AV2 -0.2 Leave in Service 21 23 35 38 0.31 14 AV2 0.12 Leave in Service 22 23 35 38 0.22 11 AV3 0 Leave in Service 23 23 35 41 0.28 12 AV2 0.07 Leave in Service 24 23 35 46 0.39 16 AV2 0.3 Leave in Service 25 23 35 46 0.44 17 AV3 0.22 Leave in Service 26 23 35 59 1.38 32 AV2 -0.22 Removed From Service 27 23 35 59 2.33 41 AV3 -0.26 Removed From Service 28 23 35 59 0.27 13 AV4 -0.2 Leave in Service 29 23 35 61 0.19 10 AV3 -0.14 Leave in Service 30 23 36 60 0.4 16 AVl -0.11 Leave in Service 31 23 38 51 0.21 11 AV3 -0.14 Leave in Service 32 23 38 62 0.52 18 AV2 -0.25 Leave in Service 33 23 38 62 0.28 12 AV3 -0.19 Leave in Service 34 23 39 56 0.76 23 AVl -0.22 Removed From Service 35 23 39 56 1.98 36 AV3 -0.21 Removed From Service 36 23 40 53 0.57 21 AV4 -0.18 Leave in Service 37 23 40 54 0.21 10 AVl -0.22 Leave in Service 38 23 40 58 0.57 21 AV2 -0.21 Leave in Service 39 23 40 58 0.78 25 AV3 -0.31 Leave in Service 40 23 41 43 0.36 15 AVl -0.22 Leave in Service 41 23 41 64 0.35 15 AVl -0.19 Leave in Service 42 23 41 64 0.43 17 AV2 -0.02 Leave in Service

NL-18-063 Enclosure Page 12 of 19 Table A-4 SG 24 Service Induced Indications - Wear - 2R23

. :count-* ':SG'. <Row.* Cc5,lumn :Volts? '.%JW,* .Lot:n Jncn}*.*.* ,,: .. :Repair,orteavefJo*se.r:vicij":

1 24 28 64 0.42 16 AV3 0.08 Leave in Service 2 24 28 64 0.36 15 AV4 -0.28 Leave in Service 3 24 32 45 0.43 17 AV1 -0.16 Leave in Service 4 24 32 45 0.35 15 AV2 0.02 Leave in Service 5 24 32 45 0.33 15 AV3 -0.21 Leave in Service 6 24 32 69 0.27 10 AV2 -0.47 Leave in Service 7 24 32 69 0.32 12 AV3 -0.14 Leave in Service 8 24 33 63 0.43 15 AV2 -0.15 Leave in Service 9 24 33 63 0.42 14 AV3 0.28 Leave in Service 10 24 33 63 0.7 20 AV4 -0.18 Leave in Service 11 24 33 64 0.26 12 AV1 -0.24 Leave in Service 12 24 33 64 0.41 16 AV2 0.19 Leave in Service 13 24 33 64 0.73 23 AV3 -0.14 Leave in Service 14 24 33 64 0.67 22 AV4 0.16 Leave in Service 15 24 33 69 0.22 9 AV1 0.13 Leave in Service 16 24 33 69 0.66 19 AV3 0.18 Leave in Service 17 24 33 71 0.32 12 AVl 0.15 Leave in Service 18 24 33 71 0.32 12 AV2 0.12 Leave in Service 19 24 33 71 0.35 12 AV3 0.13 Leave in Service 20 24 33 71 0.46 15 AV4 -0.2 Leave in Service 21 24 34 59 0.74 24 AV1 0.55 Leave in Service 22 24 34 59 0.61 21 AV2 0.12 Leave in Service 23 24 34 59 0.35 15 AV3 -0.14 Leave in Service 24 24 34 60 0.36 12 AV3 -0.16 Leave in Service 25 24 34 65 0.31 12 AV2 -0.1 Leave in Service 26 24 35 72 0.22 11 AV3 -0.34 Leave in Service 27 24 35 73 0.21 10 AV3 -0.24 Leave in Service 28 24 36 32 0.9 26 AV2 -0.24 Leave in Service 29 24 36 32 0.25 12 AV3 -0.19 Leave in Service 30 24 36 47 0.23 11 AV1 -0.11 Leave in Service 31 24 36 71 0.37 13 AV1 0.1 Leave in Service 32 24 36 71 0.92 24 AV2 -0.22 Leave in Service 33 24 36 71 0.22 9 AV3 -0.17 Leave in Service 34 24 37 25 0.43 15 AV1 -0.16 Leave in Service 35 24 37 33 0.29 11 AV1 -0.24 Leave in Service 36 24 37 70 0.55 19 AV2 0.14 Leave in Service 37 24 38 60 0.45 15 AV2 -0.17 Leave in Service 38 24 38 60 0.46 15 AV3 -0.21 Leave in Service 39 24 41 32 0.22 11 AV1 -0.16 Leave in Service 40 24 41 65 0.18 9 osc 0.4 Leave in Service 41 24 43 39 0.46 15 AV1 0.12 Leave in Service

NL-18-063 Enclosure Page 13 of 19

.¢gwfit~,
rs.Gt: "'RowI ,ccit11mit: >~61ts:Jl}'J;~w,;; .::Lo'!£tir~:}, :;1n90/:lf:i/~ti fReb'ijiWor:a:xE,iav~1rrr::.s~i;vice:'Cri 42 24 45 41 1.11 29 AV2 0.14 Removed From Service 43 24 45 41 1.93 37 AV3 -0.24 Removed From Service

~--~-~--~-

Tube R41 C65 in BOLD is TSP wear, all other tubes are AVB wear

NL-18-063 Enclosure Page 14 of 19 ATTACHMENT B Indian Point 2 Listing of Individual Tubes Plugged This Inspection

NL-18-063 Enclosure Page 15 of 19

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,,,.;*t:-::;;_.

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1 23 35 59 Plugged due to AVB Wear of 41% Through Wall No 2 23 39 56 Preventatively plugged due to AVB Wear No 3 24 45 41 Preventatively plugged due to AVB Wear No 4 Preventatively plugged due to a possible loose part 24 39 24 Yes indication detected by eddy current 5 Preventatively plugged due to a possible loose part 24 38 24 indication detected by eddy current Yes Preventatively plugged due to a possible loose part 6 24 38 23 indication detected by eddy current Yes

NL-18-063 Enclosure Page 16 of 19 ATTACHMENT C Indian Point 2 Steam Generator Tubesheet Map

NL-18-063 Enclosure Page 17 of 19 Indian Point 2 Steam Generator Tubesheet Map 0 v N 0 00 CD v N 0 00 CD v N 0 00 CD v N 0 00 CD v N 0::: v v v (") (") (") (") (") N N N N N ~ ~ ~ ~ ~

Col No.

1 2

3 4

5 6

7 8

9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

>, 25 co 26 27 sen 28 29 E 30 31 -

I- 32 Q) 33 34 N 35 N 36 0 37 z 38 39 40 41 42 43 44 45 46 47 -

48 49 50 51 52 53

>, 54 55

~ 56 58 57

-~

.c 60 59 I- 61

>, 62 co 63 3: 64 65 C

co 66 67

~ 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92

NL-18-063 Enclosure Page 18 of 19 ATTACHMENT D Indian Point 2 Steam Generator Landmark Information

NL-18-063 Enclosure Page 19 of 19 Indian Point 2 Steam Generator Location Landmarks AV2 AV3 AV1 AV4 6H 6C SH SC 4H 4C 3H 3C 2H 2C 1H 1C BPH BPC TSH ~"7777770'7777777777?777;'7"77,n,j',.,.._TSC TEH TEC Westinghouse Model 44F Steam Generator Legend AV= Anti-Vibration Bar (AVB)

C = cold leg H = hot leg

  1. = support plate (TSP)

BP = baffle plate (FOB)

TS= tubesheet TE= tube end

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