NRC 2016-0044, Spring 2016 U1R36 180-Day Steam Generator Tube Inspection Report

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Spring 2016 U1R36 180-Day Steam Generator Tube Inspection Report
ML16264A202
Person / Time
Site: Point Beach NextEra Energy icon.png
Issue date: 09/20/2016
From: Woyak B
Point Beach
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
NRC 2016-0044
Download: ML16264A202 (20)
v • d • e


Text

NEXTera.

ENERGV_~

September 20, 2016

~

NRC 2016-0044 TS 5.6.8 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555 Point Beach Nuclear Plant, Unit 1 Docket 50-266 Renewed License No. DPR-24 Spring 2016 Unit 1 (U1 R36)

Steam Generator Tube Inspection Report Pursuant to the requirements of Point Beach Nuclear Plant (PBNP) Technical Specification ,

TS 5.6.8 "Steam Generator Tube Inspection Report," NextEra Energy, LLC is submitting the 180-day Steam Generator Tube Inspection Report. The enclosure to this letter provides the results of the spring 2016, Unit 1 (U1 R36) steam generator tube inspections.

If you have questions or require additional information, please contact Mr. Edward Korkowski at 561/904-5779.

Sincerely, NextEra Energy Point Beach , LLC G~;

Bryan Woyak Licensing Manager Enclosure cc: Administrator, Region Ill, USNRC Project Manager, Point Beach Nuclear Plant, USNRC Resident Inspector, Point Beach Nuclear Plant, USNRC PSCW NextEra Energy Point Beach , LLC , 6610 Nuclear Road , Two Rivers, WI 54241

ENCLOSURE1 NEXTERA ENERGY POINT BEACH, LLC POINT BEACH NUCLEAR PLANT, UNIT 1 SPRING 2016 UNIT 1 (U1 R36)

STEAM GENERATOR TUBE INSPECTION REPORT 18 pages follow

Enclosure 1 U1R36 Steam Generator Tube Inspection Report

Background

This report is provided in accordance with Point Beach Technical Specification Section 5.6 .8, "Steam Generator Tube Inspection Report" for the inspection conducted in March, 2016 during refueling outage U1 R36. The U1 R36 inspection was the first inspection in the 4th Inspection Period (72 EFPM).

The inspections performed at U 1R36 satisfied the inspection requirements defined in Point Beach Technical Specification Section 5.5.8.d.2.i.

Point Beach Unit 1 contains two (2) Westinghouse Model 44F steam generators (SGs), which were installed in 1983 to replace the original Unit 1 SGs. The replacement 44F SGs are tubed with thermally treated lnconel 600 (1600TT) tubing. At the completion of Cycle 36 (U1 R36), the Unit 1 SGs had accumulated 27.1 Effective Full Power Years (EFPY) of operation. The hot leg operating temperature (T-Hat) of Point Beach Unit 1 is currently -611 degrees F.

Following the U1 R36 refueling outage, Point Beach Unit 1 initially entered HOT SHUTDOWN (Mode

4) on April 2, 2016, which marked the beginning of Cycle 37 for Unit 1. Pursuant to Point Beach Technical Specification 5.6.8, this Steam Generator Tube Inspection Report is required to be submitted to the NRC within 180 days after initial entry into Mode 4.

Implementation of TSTF-51 0 (Reference 1) was approved by License Amendments 254 and 258 (Reference 2) on Nov. 25, 2015, and incorporated into the Point Beach technical specifications to make changes to the sections pertaining to SG tube integrity, the SG program (inspection frequency),

and the SG Tube Inspection Report. When TSTF-51 0 was implemented at Point Beach, the inspection period durations for Unit 1 were adjusted (per the approved license amendments) as follows :

  • 2nd inspection period (90 EFPM) was adjusted to 96 EFPM
  • 3rd subsequent inspection periods (60 EFPM) were adjusted to 72 EFPM.

Upon implementation of TSTF-51 0, the U1 R36 inspection shifted (in periodicity position) from the last inspection in the 4th period (old 60-EFPM period) to the first inspection in the 4th period (new 72-EFPM period) .

The examination performed during U1 R36 met the requirements of the following:

  • The U1 R36 inspection scope and plan were based on the Degradation Assessment that was prepared prior to the refueling outage.

Page 1 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report Steam Generator Tube Inspection Report Note: The previous SG Tube Inspection Repmi from UlR34 is available under NRC Adams Accession# ML13268A108 (Reference 3). Subsequent NRC RAI's (and Nextera Responses) for the U1R34 report are available under NRC Adams Accession # ML14062A047 (Reference 4).

Following is the Steam Generator Tube Inspection Report for U1 R36:

Each applicable reporting requirement of TS 5.6 .8 is addressed below in items "a" through "g" for the U1 R36 inspection in 2016.

a. The Scope of Inspections Performed on each SG (Both SGs were examined during U1 R36).

The inspection program for the Unit 1 Steam Generators consisted of:

Bobbin Probe

  • 100% full length in rows 3 and higher; Row 1 & 2 examinations limited to the hot leg (HL) and cold leg (CL) straight sections.

+Point' Rotating Probe

  • 50% of tight radius u-bends in Row 1 and Row 2
  • 50% of HL freespan Dings/Dents >5.0 volts between TSH and 06H +1 .00".
  • 50% Dings/Dents >5.0 volts in the u-bends.
  • 50% Dings/Dents >5.0 volts at HL tube supports .
  • 50% of the hot leg tubesheet to the extent of TSH +3.00 to TEH.

(This includes minimum 50% sample of BLG & OXP indications within the Tubesheet).

  • 100% of potential high stress tubes [see Note 11 at hot leg tubesheet locations to the extent of TSH

+3.00 to TEH.

  • All H/L supports (including FOB) and top C/L TSPs in 25% sample of potential high stress tubes [see Note 11 .
  • All Hot Leg and Cold Leg Periphery Expansion Transitions - +3"/-3" from top of tubesheet. "Periphery Tubes" are defined as the three outer-most peripheral tubes exposed to the annulus, and all open row 1 and 2 tubes in columns 1-92 .
  • All tubes adjacent to previously reported foreign objects from FOSAR.
  • All tubes adjacent to "PLP" indications reported during U1 R34 +Point' examination.
  • Diagnostic rotating probe examinations (Special interest, Sl) were completed as required based on the results of the bobbin coil.

Note 1: The Point Beach tubes identified as "Potential High Stress Tubes" are commonly referred to in the industry as "minus 2 sigma tubes" or, "Seabrook Signature Tubes" .

Page 2 of 18

Enclosure 1 UlR36 Steam Generator Tube Inspection Report Plug Visual Inspection 100% of the installed tube plugs in the Unit 1 SGs were visually inspected during U1 R36.

This included :

  • Five (5) H/L plugs and five (5) C/L plugs in SG A
  • Eight (8) H/L plugs and eight (8) C/L plugs in SG B All of the plugs were confirmed to be present in their correct locations and were free from degradation and visible signs of leakage based on the visual examination .

Primary Side Inspections to address Westinghouse NSAL 12-01 Westinghouse Letter NSAL 12-01 (Reference 6) recommended a visual inspection of the channel heads near the bowl drain line to determine if degradation of the cladding and potential degradation of the channel head base material had occurred. The visual examinations were performed per the guidance provided in the NSAL letter, and no anomalies were identified in the channel head bowls (H/L and C/L) of either SG.

During U1 R30, rust coloration was reported inside the channel head near the primary manway; the rust coloration was reported again during U 1R34. A visual inspection of the same area was performed during U1 R36 and no such rust coloration was observed. The issue of the rust coloration was previously discussed in Reference 4.

Secondary Side Cleaning and Inspections The following secondary side work was performed in both steam generators:

  • Sludge Lancing at the top-of-tubesheet
  • FOSAR (Foreign Object Search and Retrieval)
  • Upper Steam Drum internals visual inspection (in one selected SG, SG B)
  • Upper Tube Bundle visual inspection through top inspection port (in one selected SG, SGB) .

The sludge lancing process resulted in the removal of the following amounts of sludge:

  • 12 lbs of sludge from SG A,
  • 13 lbs of sludge from SG B.

Post sludge lancing FOSAR (at the Top of Tubesheet) was performed in both steam generators.

Twenty-seven (27) newly-identified foreign objects in SG A, and twenty-five (25) newly-identified foreign objects in SG B were reported during FOSAR. Most of these foreign objects were sludge rocks and small-grade wire bristles up to -0 .020" in diameter.

In SG A, six (6) of the twenty-seven (27) identified foreign objects were retrieved. In SG B, three (3) of the twenty-five (25) identified foreign objects were retrieved . There was no foreign object wear reported by visual or Eddy Current inspections.

Page 3 of 18

Enclosure 1 UlR36 Steam Generator Tube Inspection Report An engineering evaluation was performed for all of the parts that were not removed from the SGs during U1 R36. The engineering evaluation determined that the foreign objects left in the SGs will not pose a threat to tube integrity over the next two cycles of operation, and will likely be removed from the SG during normal SG operation. There were no fixed foreign objects being tracked prior to the U1 R36 inspection.

The locations of the non-retrieved foreign objects from U1 R36 will be visually examined the next time that FOSAR is performed. In addition to the FOSAR, primary side eddy current inspections using the rotating +Point' coil were performed on all periphery tubes at the top-of-tubesheet locations (in the hot leg and cold leg of both SGs). No foreign object wear was reported during those periphery tube +Point' coil examinations .

Upper Steam Drum Inspection Upper Steam Drum Inspections were also performed in one SG (SG B) . The upper internal components inspected included primary separators, secondary separator perforated plates, drain pipes, feedring J-Nozzles and general areas.

The general area of the steam drum was visually inspected . No anomalies were observed during the inspection. All accessible Upper Steam Drum areas which were part of the Moisture Carryover modification (mid deck extension and brackets, flow diverters, hatch and bolts and secondary moisture separators) were inspected with no anomalies reported. All thirty six (36) J-nozzles and the feedring were visually inspected. All J-nozzles were inspected; no issues were identified. All other areas inspected appeared normal. The one hundred and twelve (112)

Primary Moisture Separators were visually inspected. All primary moisture separators appeared to be covered in a light coating of magnetite. No anomalies were observed during inspection.

Informational UT thickness measurements were made on the feedring and eight (8) primary moisture separators of SG B for trending. There were no abnormal thickness values or negative trends from the baseline measurements taken in U1 R33.

Upper Tube Bundle Inspection Inner tube bundle inspections were performed above the 6th (uppermost) broached TSP location in SG B to determine the general secondary side conditions in the upper tube bundle. In the cold leg, an even coating of sludge covering the support plate, there was also one foreign object (small wire bristle) that was retrieved (no wear was detected in association with the retrieved piece of wire) . In the hot leg there was more of a buildup of sludge in-bundle rising up the sides of the tubes. The quatrefoils were open but with some build-up of sludge.

b. Degradation Mechanisms Found There were no indications of corrosion-related tube degradation reported during the U 1 R36 inspections.

The U1 R36 examination results for Point Beach Unit 1 identified mechanical wear at the following locations:

Page 4 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report

  • Mechanical Wear Indications at Anti-vibration Bar (AVB)
  • Mechanical Wear at Broached Tube Support Plates Mechanical Wear Indications at Anti-vibration Bar (AVB)

Table 1 lists the AVB wear indications identified in SG A during U 1R36 , with each indication's historical depth measurements. In SG A , there were one hundred-four (1 04) indications in fifty-seven (57) tubes with indications of wear at the Anti-Vibration Bars. All one hundred-four (104) AVB wear indications were sized with the bobbin coil.

Table 2 lists the AVB wear indications identified in SG B during U1R36, with each indication's historical depth measurements . In SG B, there were seventy-six (76) indications in fifty-two (52) tubes with indications of wear at the Anti-Vibration Bars . All seventy-six (76) AVB wear indications were sized with the bobbin coil.

The deepest wear indication in SG A was 34% through-wall (TW). The deepest wear indication SG B was 22% TW. None of these indications required plugging per Technical Specifications and all remained in service.

Wear at Broached Tube Support Plates Table 3 lists the TSP wear indications (in both SGs) identified in U1 R36 , w ith each indication's historical depth measurements. There were ten (1 0) wear indications reported at broached tube support plates; six (6) in SG A and four (4) in SG B.

The results of the sizing showed land contact wear at each of the broached support locations with wear depths ranging from 8% to 16% through -wall. Table 3 shows all TSP wear indications (in both SGs) along with historical comparisons .

Mechanical Wear Indications at Foreign Object Locations and Top-of-Tubesheet Locations During the U 1R33 inspection in 2011 , mechanical wear at one foreign object location, and mechanical wear at several top-of-tubesheet locations was reported. (See Table 5-5 and 5-6 of Reference 5) . All of those signals that were previously reported as mechanical wear in U1 R33 were deemed to be non-reportable during U1 R34. Those signals were reclassified as "INR" (Indication Not Reportable) during U1 R34 (See Tables 5-5 and 5-6 in Reference 3) . The signals are attributed to interaction with sludge lance equipment used in the past. During U1 R36, there were no mechanical wear indications reported at foreign object or top-of-tubesheet locations. Therefore, there are no longer any instances of mechanical wear at foreign object or top-of-tubesheet locations in the Unit 1 SGs.

Possible Loose Parts During U1 R36, no tube wear associated with foreign objects was reported. As in the past, PLP signals reported during the Eddy Current examination are reconciled with secondary side inspection activities and dispositioned accordingly . No tube wear was associated with any of the PLPs reported during the U1 R36 Eddy Current examination. Similarly, no wear was associated with any of the foreign objects reported during the secondary side visual examination .

Page 5 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report Any foreign objects remaining in the SGs were evaluated and all were found acceptable to remain in the SGs until the next Eddy Current and FOSAR inspections scheduled for U1 R38.

c. Nondestructive examination techniques utilized for each degradation mechanism The following is the list of EPRI technique sheets (ETSSs) used for detection for the specific types of degradation listed below.

U1R36 Detection Techniques AVB Wear 96041 .1 (Bobbin Coil)

TSP/FDB Wear 96004.1 (Bobbin Coil)

Loose Part (Foreign Object) Wear 27091.2 (Bobbin Coil)

Pitting in Sludge Pile 96005.2 (Bobbin Coil)

Ding/Dent ODSCC 24013.1; (Bobbin Coil)

Axial ODSCC at Flow Baffle 128411 (Bobbin Coil)

Axial ODSCC at TSP and free span 128413 (Bobbin Coil)

Transition Zone ODSCC and sludge pile 128424; 21410.1 (+Point' Coil)

Axial ODSCC at Flow Baffle 128424 (+Point1M Coil)

Axial ODSCC at TSP and free span 128425 (+Point' Coil)

Low Row U-bend ODSCC 10411.1; 21410.1 (+Point1 M Coil)

Ding/Dent ODSCC 22841.3 ; 22842.3 (+Point' Coil)

Low Row U-bend Axial PWSCC 96511.2; 99997.1 (+Point' Coil)

PWSCC in Tubesheet and Tube Ends 20511.1; 20510.1 (+Point 1M Coil)

Transition Zone PWSCC 20511.1; 20510.1 (+Point 1M Coil)

Only two types of degradation were detected during U1 R36; wear at AVBs and wear at broached TSPs. The following list provides the EPRI technique sheets (ETSSs) used for sizing those specific types of degradation .

U1R36 Sizing Techniques AVB Wear 96041.1 (Bobbin Coil)

Broached TSP Wear 96910.1 (+Point' Coil)

Page 6 of 18

Enclosure 1 UlR36 Steam Generator Tube Inspection Report

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications, Table 1 lists the AVB wear indications in SG A identified in U1 R36, with each indication's historical depth measurements.

Table 2 lists the AVB wear indications in SG B identified in U1 R36 , with each indication's historical depth measurements.

Table 3 lists the broached TSP wear indications identified in U1 R36 (in both SGs), with each indication's historical depth measurements.

e. Number of tubes plugged during the inspection outage for each degradation mechanism, No tubes were plugged during U1R36.

Total Tubes Plugged and Plugging Percentage SGA SGB Total Tubes Plugged 5 of3214 8 of3214 Plugging Percentage 0.156% 0.249%

f. The number and percentage of tubes plugged to date, and the effective plugging percentage in each steam generator, No tube repair methods (i.e. sleeving) are approved for Point Beach Unit 1 that would have an effect on the effective plugging percentages. Therefore, the applicable effective plugging percentage is synonymous with the % Plugged in the table shown above in item "e".
g. The results of condition monitoring, including the results of tube pulls and in-situ testing.

All tubes satisfied the structural integrity and accident-induced leakage performance criteria based on the CM evaluation performed at the U1 R36 inspection. No tubes required in-situ pressure testing for either tube burst or leakage. Therefore, all tubes met the structural and leakage integrity requirements of the Point Beach Technical Specifications. No tube pulls were required. The following section provides more detailed discussion of the conditioning monitoring performed at U1 R36 .

Page 7 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report AVB Wear The listing for AVB wear reported during U1 R36 is provided in Tables 1 and 2. The actual number of indications detected at U 1R36 is 104 in SG A and 76 in SG B. The deepest indication was in SG A and measured 34% TW which is well below the condition monitoring limit of 55% TW, satisfying the condition monitoring requirements.

Wear at Tube Support Plates The listing for TSP wear reported during U1 R36 is provided in Table 3. The actual number of TSP wear indications detected at U1 R36 is six (6) in SG A and four (4) in SG B. The deepest indication was in SG A and measured 16% TW, which is well below the condition monitoring limit of 44% TW, satisfying the condition monitoring requirements.

Observed Leak Rates The primary-to-secondary leak rate from both steam generators (combined) continues to be in the range of 0.0 to 0.4 gallons per day (gpd). The Unit 1 steam generator primary-to-secondary operational leakage remains at a constant low level and was evident prior to the spring 1991 outage . This normal operation leakage is very small compared to the operating leakage limit of 150 gpd per SG. The current leak rate has remained essentially the same for many cycles and is expected to remain at these low levels. Point Beach will continue to monitor the leakage with the primary-to-secondary operational leak monitoring procedure .

This leakage has been previously reported to the NRC in Reference 3 (U1 R34 SG Tube Inspection Report), and discussed further in Reference 4 (RAI responses to U 1R34 SG Tube Inspection Report) .

Page 8 of 18

Table 1 A VB Wear History- SG A 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW II 45 AVI 13 10 - - - - - - -

11 53 AV4 8 9 9 7 4 - - - -

15 87 AV2 INR INR INR 5 - - - - -

AV3 INR INR INR 5 - - - - -

I9 54 AVI 9 10 10 7 8 - - - -

AV2 19 18 I7 I2 I7 12 14 13 7 AV3 10 10 11 8 10 - - - -

AV4 15 17 17 13 I7 I2 16 12 13 I9 6I AVI I6 I6 17 12 I3 12 I8 IO 12 AV2 20 I8 I9 I4 I6 15 23 13 14 AV4 9 9 9 6 5 6 8 - -

22 8 AV3 5 5 4 3 3 - - - -

AV4 4 4 5 3 - - - - -

24 63 AVI II I4 12 8 - I4 - INR 9 AV2 I8 18 12 - - - - - -

AV3 18 20 16 - - - - - -

AV4 8 9 - - - - - - -

24 85 AV2 8 8 7 5 5 - - - -

26 83 AV3 8 8 8 6 - - - - -

26 84 AVI INR 5 6 4 - - - - -

AV2 INR 6 5 3 - - - - -

27 7I AV2 II 1I I2 8 10 6 II 5 4 AV3 16 17 18 14 15 IO 12 3 2 AV4 8 9 II 8 7 5 6 0 0 29 41 AV2 II 10 - - - - - - -

29 81 AV2 6 6 6 4 7 - - - -

31 35 AV4 12 9 - - - - - - -

31 36 AV4 8 - - - - - - - -

31 63 AV2 I4 17 16 13 18 20 14 9 12 AV3 10 II 10 7 1I IO 5 5 2 3I 79 AV3 4 5 7 5 6 - - - -

32 I4 AV2 5 6 6 4 - - - - -

AV3 9 9 8 7 7 5 3 I4 11 AV4 8 8 9 5 7 - - - -

Page 9 of 18

Table 1 A VB Wear History - SG A 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col .Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW 32 68 AVI 10 7 12 10 - 9 - - -

AV2 9 10 10 8 - 9 - - -

32 71 AV2 15 18 18 14 15 11 9 10 6 AV3 11 12 12 8 11 - - - -

32 78 AV3 5 5 6 2 - - - - -

32 79 AV1 5 6 6 4 9 - - - -

33 18 AV3 21 24 21 19 18 25 21 - -

AV4 15 15 15 10 11 16 13 - -

33 36 AV3 9 - - - - - - - -

AV4 10 12 - - - - - - -

33 37 AV3 8 7 7 5 - - - - -

AV4 15 13 12 10 14 9 13 7 8 33 48 AV3 10 11 9 8 9 13 9 - -

AV4 8 7 7 4 - - - - -

33 57 AV1 13 12 10 4 5 - - - -

AV2 15 12 - - - - - - -

33 66 AV1 18 19 18 16 14 20 14 9 8 AV2 14 15 15 13 10 13 11 9 4 AV3 5 6 5 5 4 5 5 4 4 33 71 AV2 18 20 20 16 16 13 17 5 6 AV3 15 14 15 10 14 6 10 0 0 34 33 AV1 14 13 13 8 14 10 10 5 II AV2 21 17 11 6 11 7 7 7 10 34 65 AV3 12 12 13 9 5 9 6 I -

AV4 18 20 17 14 11 15 12 6 7 34 69 AV1 8 9 II 6 8 3 7 I 0 AV2 12 14 16 11 16 11 14 6 9 35 18 AV2 10 10 10 9 II 10 6 INR 9 AV3 10 - - - - - - - -

35 43 AV3 10 10 10 9 - 8 - - -

AV4 17 13 13 11 - 9 - - -

35 56 AV1 23 23 26 21 18 14 15 5 6 AV2 34 34 37 33 27 27 27 9 13 37 20 AV4 8 8 - - - - - - -

Page10of18

Table 1 A VB Wear History- SG A 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW 38 22 AV2 8 9 8 7 7 - - - -

AV3 II 10 11 9 10 12 6 10 8 AV4 7 8 8 6 6 - - - -

38 43 AV1 32 28 27 27 24 23 19 12 11 AV2- 30 26 22 19 17 16 - - -

AV2+ 27 23 25 24 22 23 19 12 8 38 54 AV3 21 22 24 20 26 25 18 14 15 AV4 10 11 11 8 9 - - - -

39 68 AV2 6 8 7 5 - - - - -

AV3 6 7 6 5 - - - - -

AV4 4 5 5 5 9 9 8 9 6 39 69 AV3 10 11 11 7 - - - - -

40 25 AV1 7 7 6 6 - - - - -

AV2 9 9 8 7 9 6 5 9 6 AV3 8 9 9 7 - - - - -

40 27 AV3 8 8 8 6 8 5 4 6 5 40 42 AV1 10 11 10 7 14 12 13 - 23 40 44 AV3 14 14 12 9 11 13 10 7 5 40 47 AV3 15 14 14 10 15 10 13 10 12 40 66 AV1 7 9 9 - - - - - -

42 61 AV1 8 - - - - - - - -

AV4 7 8 9 6 5 - - - -

43 52 AV4 7 9 9 - - - - - -

43 56 AV4 6 7 7 - - - - - -

44 54 AV1 5 7 - - - - - - -

AV4 5 7 - - - - - - -

45 41 AV1 8 9 9 7 10 6 6 7 6 AV4 9 11 10 8 8 7 6 7 6 45 42 AV1 11 10 10 10 14 - - - -

45 43 AV1 7 8 8 7 18 13 12 15 11 AV4 10 11 II 9 9 8 8 - -

45 45 AV4 9 8 - - - - - - -

45 49 AV1 5 6 4 4 15 19 14 13 18 AV2 4 6 5 4 - - - - -

Page 11 of 18

Table 1 A VB Wear History- SG A 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW AV4 7 10 9 7 - - - - -

45 50 AV4 8 10 9 6 4 - - - -

45 51 AV4 6 7 6 6 - - - - -

45 52 AV2 7 10 9 7 - - - - -

AV3 7 - - - - - - - -

AV4 6 - - - - - - - -

TW =Through-wall, INR =Indication Not Reportable Page 12 of 18

Table 2 AVBWear H'Istory- SGB 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW 14 15 AV3 5 7 8 8 - - - - -

15 87 AV3 10 11 - - - - - - -

16 47 AV2 9 8 9 8 5 - - - -

16 70 AV2 INR INR 8 - - - - - -

16 73 AV2 INR INR 9 7 - - - - -

16 77 AV3 INR INR INR 6 - - - - -

17 70 AV3 8 9 8 - - - - - -

17 79 AV2 10 10 9 8 9 - - - -

18 77 AV3 INR INR 7 8 - - - - -

19 36 AV3 8 8 9 8 8 9 9 6 6 21 79 AV2 6 8 9 - - - - - -

AV3 5 7 7 - - - - - -

22 58 AV1 10 10 12 9 10 9 8 8 5 AV2 21 21 21 19 21 21 19 16 16 AV3 19 18 19 17 19 19 16 13 14 AV4 16 15 16 13 15 14 12 11 9 23 33 AVI 11 12 9 8 12 11 6 8 8 AV2 16 18 16 14 16 15 13 16 11 AV3 22 25 25 24 26 25 17 19 18 AV4 5 6 5 4 6 - - - -

23 79 AV2 5 7 9 - - - - - -

23 86 AV2 8 8 7 7 - - - - -

AV3 9 9 9 10 - - - - -

24 13 AV2 6 8 8 7 4 - - - -

25 23 AV3 4 6 8 6 - - - - -

26 28 AV2 9 8 10 - - - - - -

27 82 AV2 8 8 8 - - - - - -

28 13 AV2 5 7 9 7 - - - - -

28 41 AV4 7 8 8 7 - 6 - - -

28 79 AV2 7 9 10 8 - 6 - - -

29 13 AV2 4 6 8 - - - - - -

29 40 AV2 6 8 9 8 - - - - -

29 55 AVI 14 14 13 12 - II - - -

AV3 6 6 5 4 - 8 - - -

Page 13 of 18

Table 2 AVBWear H'IS t ory- SGB 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW 3I 25 AV4 6 6 9 6 5 - - - -

32 I4 AV2 8 7 9 7 3 - - - -

32 32 AV3 II I2 I4 IO I3 I3 I2 8 7 AV4 7 8 10 7 7 6 6 - -

32 44 AV3 4 6 5 5 9 8 7 5 4 32 46 AV1 3 8 8 6 - - - - -

AV2 15 I6 16 I4 I7 I5 II II 8 AV3 17 18 I9 18 21 I8 15 17 12 AV4 12 13 I4 12 IO - - - -

32 49 AVI I6 18 18 17 20 I8 I4 I3 13 AV2 14 I6 I6 13 I6 15 11 10 IO 32 70 AV1 I5 I5 I4 I2 13 II 14 4 5 AV2 18 17 20 16 19 17 17 14 12 33 I6 AV1 5 4 6 4 - 4 - - -

AV3 9 - - - - - - - -

33 17 AV2 10 9 I1 8 - 4 - - -

33 71 AV1 17 19 19 18 20 I9 17 I3 10 AV2 9 11 11 9 10 10 6 - -

AV3 3 7 8 4 - - - - -

34 I7 AV2 9 9 I1 8 - 5 - - -

34 I8 AV2 8 7 8 5 - 5 - - -

34 75 AV2 7 1I IO 9 6 - - - -

35 18 AV2 8 7 9 6 - 3 - - -

35 24 AV4 8 IO - - - - - - -

36 73 AV2 I2 - - - - - - - -

36 74 AV1 7 8 8 5 7 6 7 7 6 AV4 8 8 7 6 - - - - -

37 73 ' AV3 I1 II 10 9 8 - - - -

38 22 AV1 9 9 IO 7 6 - - - -

AV2 8 10 - - - - - - -

39 69 AV2 6 9 9 7 - - - - -

AV3 6 8 9 6 - - - - -

41 29 AV1 6 8 7 5 - I - - -

AV4 7 8 8 6 - I - - -

Page 14 of 18

Table 2 AVBWear H'1story- SGB 2016 2013 2011 2008 2007 2004 2001 1998 1995 Row Col Loc

%TW %TW %TW %TW %TW %TW %TW %TW %TW 42 31 AV4 11 10 10 7 - 6 - - -

42 32 AV1 13 12 13 11 - - - - -

42 33 AV1 6 7 9 7 - 6 - - -

42 58 AV1 8 11 - - - - - - -

42 59 AV1 9 9 10 - - - - - -

43 59 AV4 7 9 11 - - - - - -

44 50 AV3 7 10 8 9 - - - - -

44 54 AV1 8 9 9 9 8 8 8 - -

AV3 5 9 9 6 - - - - -

45 44 AV1 7 7 8 6 16 14 14 12 13 AV2 6 - - - - - - - -

45 46 AV1 9 - - - - - - - -

TW =Through-wall, INR =Indication Not Reportable Page 15 of 18

Table 3 Wear at Tube Support Plates 2016 2013 2011 2008 2007 2005 2004 SG ROW COL %TW %TW %TW %TW %TW %TW %TW Location A 18 87 12 13 13 N/R N/R N/R N/R 02C A 21 85 15 15 15 13 Nil 12 10 02C A 37 73 8 8 N/R N/R N/R N/R N/R 01C A 39 24 14 13 15 13 Nil 11 12 03C A 39 67 11 11 12 10 Nil 7 N/R 02C A 41 65 16 15 16 14 Nil 16 18 02C B 5 45 11 10 11 N/R N/R N/R N/R 05C B 34 18 15 15 13 12 N/R N/1 N/R 01H B 38 22 12 10 N/R N/R N/R N/R N/R 04C B 39 69 13 12 13 N/R N/R N/R N/R 01C Nil= not inspected, N/R =not reported, TW =through-wall Page 16 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report Appendix A Acronyms AVB Anti Vibration Bar ECT Eddy Current Testing EFPM Effective Full Power Months EPRI Electric Power Research Institute ETSS Examination Technique FDB Flow Distribution Baffle FOSAR Foriegn Object Search and Retrieval DSI Distorted Support Indication GPD(gpd) Gallons per Day HL Hot Leg INR Indication Not Reportable NDD No Degradation Detectable NEI Nuclear Energy Institute OD Outside Diameter ODSCC Outside Diameter Stress Corrosion Cracking PCT Percent PLP Possible Loose Part PWSCC Primary Water Stress Corrosion Cracking RAI Request for Additional Information SG Steam Generator TSP Tube Support Plate TIS Top ofTube Sheet TWD Though Wall Depth Page 17 of 18

Enclosure 1 U1R36 Steam Generator Tube Inspection Report Appendix B References References

1) NRC Document TSTF-510, Rev 2, "Revision to Steam Generator Program Inspection Frequencies and Tube Sample Selection".
2) NRC License Amendment 254 and 25 8, Letter dated November 25, 2015 "Point Beach Nuclear Plant, Units 1 and 2 - Issuance of Amendments for the Steam Generator Technical Specifications, to Reflect Adoption of TSTF-510 RE: (TAC NOS. MF6043 and MF6044)."

(ADAMS Accession No. ML15293A457).

3) "Spring 2013 Unit 1 (U1R34) Steam Generator Tube Inspection Repot1" (NRC Adams Accession # ML13268A108). Document Date 9/24/2013.
4) "Response to Request for Additional Information Spring 2013 Unit 1 (U1R34) Steam Generator Tube Inspection Report".

(NRC Adams Accession # ML14062A047). Document Date 3/3/2014.

5) "Fall 2011 Unit 1 (Ul33) Steam Generator Tube Inspection Report" (NRC Adams Accession # ML12150A287). Document Date 5/29/2012.
6) Westinghouse Nuclear Safety Advisory Letter (NSAL) 12-01, Steam Generator Channel Head Degradation, 01/05/2012.

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