ML090060111

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Steam Generator Tube Inservice Inspection Report for the 2008 Refueling Outage
ML090060111
Person / Time
Site: Surry Dominion icon.png
Issue date: 11/14/2008
From: Gerald Bichof
Virginia Electric & Power Co (VEPCO)
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
08-0687
Download: ML090060111 (18)
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Text

VIRGINIA ELECTRIC AND POWER COMPANY RICHMOND, VIRGINIA 23261 November 14, 2008 Attention: Document Control Desk Serial No. 08-0687 U.S. Nuclear Regulatory Commission SS&L/TJN R1 Washington, D. C. 20555-0001 Docket No. 50-281 License No. DPR-37 Gentlemen:

VIRGINIA ELECTRIC AND POWER COMPANY SURRY POWER STATION UNIT 2 STEAM GENERATOR TUBE INSERVICE INSPECTION REPORT FOR THE 2008 REFUELING OUTAGE Technical Specification 6.6.A.3 for Surry Power Station Units 1 and 2 requires the submittal of a Steam Generator Tube Inspection Report to the NRC within 180 days after Tavg exceeds 200 0 F following completion of an inspection performed in accordance with the Technical Specification 6.4.Q, Steam Generator Program.

Attached is the Surry Power Station Unit 2 report for the 2008 refueling outage.

If you have any questions or require additional information, please contact Mr. Trace JS Niemi at 757-365-2848.

Sincerely, G. T. Bischof .

Site Vice President Surry Power Station Attachment Commitments made in this letter: None Ir 104

Serial No. 08-0687 Docket No.: 50-281 copy: US Nuclear Regulatory Commission Region II Sam Nunn Atlanta Federal Center 61 Forsyth Street, S.W., Suite 23T85 Atlanta, Georgia 30303-8931 NRC Senior Resident Inspector Surry Power Station Mr. J. F. Stang, Jr.

NRC Project Manager.

U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 8G9A 11555 Rockville Pike Rockville, Maryland 20852 Ms. D. N. Wright NRC Project Manager U. S. Nuclear Regulatory Commission One White Flint North Mail Stop 8H4A 11555 Rockville Pike Rockville, Maryland 20852 Mr. R. A. Smith Authorized Nuclear Inspector Surry Power Station

Serial No. 08-0687 Docket No.: 50-281 ATTACHMENT 1 SURRY UNIT 2 180-DAY NRC REPORT REGARDING STEAM GENERATOR TUBE.

INSPECTION PER TECHNICAL SPECIFICATION 6.6.A.3 SURRY POWER STATION UNIT 2 VIRGINIA ELECTRIC AND POWER COMPANY

Serial No. 08-0687 Docket No. 50-281 Attachment Page 1 of 15 180-DAY NRC REPORT REGARDING STEAM GENERATOR TUBE INSPECTION SURRY UNIT 2 - SPRING 2008 The following satisfies the Surry Power Station Technical Specification (TS) reporting requirement section 6.6.A.3. During the Surry spring 2008 refueling outage, steam generator inspections in accordance with TS 6.4.Q were completed for two of the three steam generators

("B", "C"). A 100 percent scope expansion of the last 4 inches of the tube end was also completed in SG ("A"). This was the initial inspection under the modified Technical Specifications resulting from the TSTF-449 generic specification issued to the industry.

Consequently, the referenced outage is the starting point for compliance to the periodicity and tube inspection coverage requirements of 6.4.Q. A Table of Acronyms is at the end of this attachment.

The Surry Steam Generators are replacement Model 51 F with the lower assemblies (i.e. tube bundle, lower shell, and channel head) having been replaced in 1980 and 1981 for Unit 2 and Unit 1, respectively. The primary moisture separator assemblies were also replaced with the "F" type design. The moisture separators were subsequently upgraded to support a core power up-rate implemented in 1995. The following are key design parameters of each of the steam generators.

Heat Transfer Area: 51,500 sq. ft.

Tubing Material: Alloy 600 TT with post bend stress relief of U-bends 1-8 Number of tubes: 3342 Tube Size: 7/8 inch OD, 0.050 inch wall thickness Tube Pitch/Layout 1.281 inches/Square Pitch Support Plates: Seven broached quatrefoil 405 SS with (1) "doughnut opening" baffle plate No. 1 Anti-vibration Bars: Two chrome plated Alloy 600 bars encompassing all tubes in rows 8 through 12 Surry Unit 2 exceeded 2001F on May 18, 2008; therefore, this report is required to be submitted by November 14, 2008.

For EOC21, an Interim Alternate Repair Criterion (IARC) to address primary water stress corrosion indications was submitted for the bottom 4 inches of the tubesheet expansion zone (Surry Unit 2 Tech Spec Amendment 258). The IARC requires inspection of the tubesheet region, and plugging of any tubes which exhibit circumferentially oriented cracks greater than 940 in the 1 inch span above the tube-end, and greater than 2030 in the 3 inches above the 1 inch zone. Circumferentially oriented cracks of less than these magnitudes and all axial cracks are acceptable for continued operation in these regions. Leakage observed from the tubesheet expansion zone must be multiplied by a factor of 2.5 to determine accident induced leakage from the tubesheet region.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 2 of 15 The report information is provided under each bold italicizedTS 6.6.A.3 item shown below.

A report shall be submitted within 180 days after Tavg exceeds 2000 F following completion of an inspection performed in accordance with the Specification 6.4.Q, "Steam Generator(SG) Program." The reportshall include:

a. The scope of inspectionsperformed on each SG The following inspections were performed in Steam Generators "B" and "C"
  • Pre and post tubesheet and channel head video scan, including visual examination of all installed tube plugs 0 Diaphragm removal, cleaning, inspection and re-installation 0 100% bobbin probe examination full length, except for straight leg only in Row 1 HL and CL
  • 20% +PointTM probe examination of top of tubesheet HL from +3 inches to the tube end with a minimum of 50% in the Critical Zone. Note: Critical Zone is defined as location of secondary side sludge pile
  • 20% +PointTM probe examination of TEH + 4 inches for locations included in the 20% HL top of the tubesheet program (See Note below)
  • 100% +PointTM probe examination of Row 1 U-bends from 7 th TSP HL to 7 th TSP CL
  • 100% +PointTM examination of HL Dents/Dings > 5 volts
  • 20% +PointTM examination of HL Dents/Dings > 2 volts 0 100% +PointTM examination of all HL OVR calls
  • 50% +PointTM examination of all HL OXP calls and 10 largest voltage CL OXP calls
  • +PointTM examination of all HL/CL reported NTE/PTE
  • Miscellaneous +PointTM probe exams: confirmation/characterization of bobbin indications (NQI's, etc) per Dominion Analysis Guidelines and other special area of interest locations During 100% bobbin program all tubes were evaluated for the u-bend off-set signal. No offset signals were noted.

Note: Due to the detection of crack-like indications in the HL tube ends during the 20% +Point TM tubesheet program, the +PointTM tubesheet scope was expanded to 100% of the HL tube ends in SGs "B" and "C" and a 20% sample in the unscheduled "A" SG. The scope in SG "A" was expanded to 100% after finding indications during the 20% sample. The HL tube end inspection was performed from the tube end to 4 inches above the tube end (TEH + 4 inches).

Serial No. 08-0687 Docket No. 50-281 Attachment Page 3 of 15 The following secondary side activities were conducted:

SG "B":

  • Steam drum visual inspection and video documentation
  • In bundle Top of Tubesheet exams SG "A", "B":
  • Upper bundle flush (UBF)
  • Upper bundle and 7th Tube Support Plate (TSP) examinations SG "A", "B", "C":
  • Baffle plate and top of tubesheet sludge lance 0 Peripheral area cleanliness and foreign object search and retrieval (FOSAR) visual inspections
  • Sludge sample retrieval for chemical analysis
b. Active degradationmechanisms found Axial and circumferential indications suggestive of flaws at the tube end ID were reported in all three SGs. The indications were identified within 0.2 inches from the tube end. SG "A" had 60 tubes with 60 indications (3 axial and 57 circumferential), SG "B" had 37 tubes with 39 indications (9 axial and 30 circumferential), and SG "C" had 20 tubes with 21 indications (6 axial and 15 circumferential). (See Tables 9, 10 and 11 below)

Minimal growth of existing AVB wear indications was observed in SGs "B" and "C". No new AVB wear indications were reported. No bobbin inspection was performed in SG "A" during the EOC21 inspection efforts.

Seven foreign objects (PLPs) were confirmed by eddy current in SG "B" and SG "C". No PLPs were reported in SG "A", since only the tube ends were inspected. The PLP locations were "boxed in" to determine the extent of the foreign object and to determine if tube wear had occurred.

A total of 15 tubes were identified with volumetric indications attributed to foreign objects. Nine indications were reported in previous inspections, while six were not previously reported. The volumetric indications were evaluated and none required plugging.

The secondary side inspections did not identify any component degradation that would compromise tube integrity.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 4 of 15

c. Nondestructive examination techniques utilized for each degradationmechanism The SG inspections focused on the following degradation mechanisms listed in Table 1 utilizing the referenced eddy current techniques.

Table 1 - Inspection Method for Applicable De cradation Modes Classification Degradation Location Probe Type Mechanism Bobbin - Detection Existing Tube Wear Anti-Vibration Bars Bobbin and +PointT TM- Sizing Flow Distribution Bobbin - Detection Potential Tube Wear Baffle Bobbin and +PointM- Sizing Bobbin - Detection Existing Tube Wear Tube Support Plate TM Bobbin and +Point. - Sizing Tube Wear Straight Leg &AVB Bobbin - Detection Potential Tangents Bobbin or +PointTM- Sizing Tube Wear (foreign Freespan andBobbin - Detection Existing objects) +PointM- Sizing Hot Leg Top-of- Bobbin and +PointTM - Detection Potential ODSCC/PWSCC Tubesheet Sludge TM Pile Area +PointM- Sizing Hot Leg Top-of-Relevant/Informational Tubesheet Sludge PWSCC Pile Area and Within +PointM - Detection and Sizing Inspection Tubesheet Anomaly locations Existing PWSCC At the Tube Ends +PointTM - Detection and Sizing Relevant/Informational vInfetional ODSCC DSCC Row 1 U-bends +PointTM - Detection and Sizing Inspection PWSCC Relevant/Informational Freespan and Tube Tm InpcinODSCC Inspection Suprs Supports +Point - Detection and Sizing TM Relevant/Informational OD Pitting Top-of-Tubesheet Bobbin and +Point - Detection Inspection +PointM- Sizing

Serial No. 08-0687 Docket No. 50-281 Attachment Page 5 of 15

d. Location, orientation (if linear), and measured sizes (if available) of service induced indications As stated in the (b) response above, several wear type indications were noted. Tables 2 through 5 below provide the detailed information regarding these indications.

Table 2 - SG "B" AVB Indication Summary - EOC21 Depth (%TW) Adjusted Upper (ETSS 96004.1) 2008 2008 2009 Depth Depth Depth Col AVB # 2003 2008 (%TW) (%TW) 2 (%TW) 3 Row 32 69 AV2 12 12 15.1 28.8 34.4 38 74 AV1 10 A 14 17.1 30.8 36.4 38 74 AV2 17 17 20.0 33.7 39.3 38 51 AV4 13 16 19.0 32.7 38.3 24 57 AV1 19 20 22.9 36.6 42.2 45 57 AV1 10 A 11 14.2 27.9 33.4 31 58 AV2 15 16 19.0 32.7 38.3 33 60 AV3 15 16 19.0 32.7 38.3 44 60 AV2 10 A 12 15.1 28.8 34.4

1. 2008 measured wear depth percent corrected according to the following equation, (0.97) x (Field Call) + (3.49)
2. Corrected 2008 wear depth percent plus total eddy current uncertainty of 13.7%
3. Upper bound 2008 percent depth plus SG B 95/50 growth rate/cycle, i.e., 5.58% / Cycle A. Not reported in 2005 - used 10% as default depth

Serial No. 08-0687 Docket No. 50-281 Attachment Page 6 of 15 Table 3 - SG "C" AVB Indication Summary - EOC21 Depth (%TW) Adjusted Upper Projected (ETSS 96004.1) 2008 Bound 2009 Depth 1et Depth 2008 Deth)

Row Col AVB # 2003 2008 (%TW)1 (%TW)2 Dept 24 8 AV4 10 12 15.1 28.8 30.4 25 9 AV3 12 11 14.2 27.9 29.4 26 26 AV3 18 17 20.0 33.7 35.4 26 26 AV4 17 16 19.0 32.7 34.4 25 27 AV1 12 15 18.0 31.7 33.4 25 27 AV2 27 29 31.6 45.3 47.4 25 27 AV4 13 11 14.2 27.9 29.4 38 28 AV1 11 10 13.2 26.9 28.4 38 28 AV3 15 15 18.0 31.7 33.4 25 29 AV3 23 19 21.9 35.6 37.4 34 29 AV4 15 15 18.0 31.7 33.4 40 33 AV2 19 22 24.8 38.5 40.4 40 33 AV3 23 23 25.8 39.5 41.4 26 39 AV3 10 20 22.9 36.6 38.4 43 39 AV2 10A 19 21.9 35.6 37.4 38 43 AV3 10A 15 18.0 31.7 33.4 46 45 AV2 10 12 15.1 28.8 30.4 39 50 AV3 10A 13 16.1 29.8 31.4 39 53 AV3 24 26 28.7 42.4 44.4 39 55 AV3 24 22 24.8 38.5 40.4 39 55 AV3 15 13 16.1 29.8 31.4 39 55 AV4 19 22 24.8 38.5 40.4 33 59 AV3 10 A 17 20.0 33.7 35.4 43 61 AV1 21 21 23.9 37.6 39.4 44 61 AV1 10l 10 13.2 26.9 28.4 37 63 AV2 13 10 13.2 26.9 28.4 40 63 AV3 18 15 18.0 31.7 33.4 40 63 AV4 18 16 19.0 32.7 34.4 43 63 AV1 1 0 A 12 15.1 28.8 30.4 31 65 AV2 13 12 15.1 28.8 30.4 33 68 AV1 17 18 21.0 34.7 36.4 33 68 AV2 20 18 21.0 34.7 36.4 31 69 AV2 19 18 21.0 34.7 36.4 31 69 AV3 10A 13 16.1 29.8 31.4 33 70 AV1 10 10 13.2 26.9 28.4 33 70 AV2 8 8 11.3 25.0 26.4 33 70 AV3 18 16 19.0 32.7 34.4 33 73 AV3 15 15 18.0 31.7 33.4 38 73 AV1 10 10 13.2 26.9 28.4 31 75 AV3 14 13 16.1 29.8 31.4 31 75 AV4 16 13 16.1 29.8 31.4 35 77 AV2 10 10 13.2 26.9 28.4 27 84 AV4 10 10 13.2 26.9 28.4

1. 2008 measured wear depth percent corrected according to the following equation, (0.97) x (Field Call) + (3.49)
2. Corrected 2008 wear depth percent plus total eddy current uncertainty of 13.7%
3. Upper bound 2008 percent depth plus SG B 95/50 growth rate/cycle, i.e., 5.58% / Cycle A. Not reported in 2005 - used 10% as default depth B. Depth based on 2000 inspection results

Serial No. 08-0687 Docket No. 50-281 Attachment Page 7 of 15 Table 4 - Summary of Non-AVB Wear Volumetric Degradation Identified in SG "B" Row Col Volts Ind TW % Wear Wear Loc Inch History in Length Arc in Review 2008 in Degrees Inches Percent (volumetric) indication and PLP reported in EOC21 36 26 0.71 VOL 28 0.26 271 TSC 0.07 NDD History 36 1 27 0.29 VOL 17 0.34 51 1 TSC 0.16 NDD History Percent (volumetric) indication reported in EOC21 and no PLP reported in EOC21 37 27 0.17 VOL 7 0.23 34 TSC 0.14 NDD History 22 82 0.71 VOL 30 0.41 50 TSH 0.33 NDD History 23 82 0.11 VOL 5 0.29 31 TSH 0.02 NDD History No percent (volumetric) indication reported in EOC21 but a PLP reported in EOC21 1 13 0.72 0 0 TSH 0.13 PLP in 2005 37 36 0.61

-no wear 0 0 0 TSC 0.17 NDD History Table 5 - Summary of Non-AVB Wear Volumetric Degradation Identified in SG "C" Row Col Volts Ind TW % Wear Wear Loc Inch History in Length Arc in Review 2008 in Degrees Inches Percent (volumetric) indication and PLP reported in EOC21 34 35 0.2 VOL 12 0.25 39 BPH 0.51 NDD History 34 36 0.34 VOL 18 0.26 39 BPH 10.56 NDD History 33 37 0.27 VOL 1161 0.3 37 BPH 0.24 NDD History Percent (volumetric) indication reported in EOC21 and no PLP reported in EOC21 SVI called in 37 35 0.24 VOL 13 0.24 35 BPH 0.60 2005 -no PLP reported SVI called in 35 37 0.17 VOL 9 0.30 34 BPH 0.58 2005- no PLP reported SVI called in 33 .17 0.09 VOL 6 0.29 29 TSH 2.41 2005- no PLP reported SVI called in 34 18 0.13 VOL 8 0.29 31 TSH 1.01 2005 -no PLP reported 35 22 0.17 VOL 13 0.29 35 TSH 1.00 calledandin PLP SVI 2005 SVI called in 44 43 0.13 VOL 8 0.27 39 TSH 0.23 2005 -no PLP reported SVI called in 36 68 0.38 VOL 18 0.49 39 TSH 0.30 2005- no PLP reported

Serial No. 08-0687 Docket No. 50-281 Attachment Page 8 of 15

e. Number of tubes plugged during the inspection outage for each active degradation mechanism In accordance with the NRC approval of the Surry IARC, six tubes were plugged due to tube end indications. Three additional tubes were plugged and stabilized due to foreign object wear and the inability to remove the object causing the wear. No other tubes required plugging.

There were no tube pulls and no tubes required in-situ testing. The tubes plugged in EOC21 are listed in Table 6. The plugging performed during EOC21 was based on the following:

" Each identified tube location was plugged using an Alloy 690TT Westinghouse Mechanical Plug and installed per the station approved Westinghouse Procedure.

" Each identified tube location was reviewed for skip rolls, over expansions, dents, bulges and additional indications.

" Requirement for installation of stabilizers was reviewed for each identified tube location.

  • Each identified tube location was screened against the in-situ screening criteria.

" The indications queried by the site steam generator degradation database to generate the tube plug list were consistent with those specified in the Surry Site Specific Eddy Current Analysis Guideline, Revision 13, April 20, 2008.

  • Detailed flaw sizing and reasons for plugging were documented and included in the Condition Monitoring and Operational Assessment.
  • Required and planned eddy current examinations were successfully completed and confirmed.

Table 6- EOC21 Plug List Tube SG Location Reason for Plugging Stabilized Ri 046 Tube end circumferential crack No exceeding 940 IARC Criteria Tube end circumferential crack No A R2C31 exceeding 940 IARC Criteria R12C29 Tube end circumferential crack No exceeding 940 IARC Criteria .

B R15C76 Tube end circumferential crack 'No exceeding 940 IARC Criteria Tube end circumferential crack RIC51 exceeding 940 IARC Criteria No Ri 063 Tube end circumferential crack No exceeding 940 IARC Criteria C R34C35 PLP and volumetric wear- unable to Yes - HL retrieve foreign object R34C36 PLP and volumetric wear- unable to Yes - HL retrieve foreign object R33C37 PLP andforeign retrieve volumetric wear- unable to Yes- HL object

Serial No. 08-0687 Docket No. 50-281 Attachment Page 9 of 15

f. Total number and percentageof tubes plugged to date Tables 7 and 8 provide the plugging attributes and percentages of tubes plugged to date.

Table 7 - Tube Plugging Summary Including EOC21 Tube Foreign Tube End SG SG AVB Freespan Pull Objects Pitting Anomalies Cracks Other Total A 1 0 0 4 11 0 3 4 23 B 5 0 0 3 0 0 1 2 11 C 10 0 0 11 1 3 2 3 30 Total By 16 0 0 18 12 3 6 64 Reason Table 8 - Tube Plugging % Summary Including EOC21 SG Tubes Installed Tubes Plugged To-Date A 3,342 23 (0.7%)

B 3,342 11 (0.3%)

C 3,342 30 (0.9%)

Total 10,026 64 (0.6%)

g. The results of condition monitoring, including the results of tube pulls and in-situ testing Based on the integrity evaluations performed following the April 2008 SG inspections, the condition monitoring and operational assessments satisfied all SG tube structural and leakage integrity requirements. The following specific conclusions are provided:
  • SGs "B" and "C" meet all structural and leakage requirements of NEI 97-06 based on the results of the EOC21 inspection. The integrity of SG "A" was documented in the EOC20 CMOA, except for tube-end indications detected during EOC21. The tube-end indications in SG "A" meet the structural and leakage performance criteria based on the EOC21 inspection results. All three SGs met the structural and leakage performance criteria for Cycle 22.
  • AVB wear is an existing degradation mechanism in Surry Unit 2 steam generators. Based on application of conservative AVB wear growth rates, the condition of the Sur'ry Unit 2 SG tubes has been analyzed with respect to continued operability of the SGs until the end of Cycle 22 for SGs "B" and "C". The results show that the structural and leakage performance criteria were met. Conservative projection of the AVB wear in SG "A" until the end of Cycle 22 shows that the structural criteria will continue to be satisfied until that time.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 10 of 15

" Indications of PWSCC were observed at the HL tube-ends in SGs "A", "B", and "C". All indications were no more than 0.2 inches from the tube-end. Indications with circumferential extent greater than 940 were plugged. All axial indications and circumferentially oriented indications 940 or less in circumferential extent were left in service consistent with the licensed IARC. Axial indications and indications with circumferential extent of up to, and including, 940 do not challenge the structural and leakage integrity requirements of NEI 97-06, Rev. 2. Axially oriented indications do not affect structural integrity of the tubes.

Circumferential indications that were left in service in accordance with the IARC include a conservative allowance for growth over the next operating cycle until EOC22.

  • No other corrosion related degradation mechanisms were observed.

" No tube pull or in-situ testing was required.

  • Existing wear (volumetric) indications detected at the TTS and flow distribution baffle have not changed since the prior inspection in 2005. The likely source of these indications is wear due to a transient foreign object at a prior time. Three tubes in SG "C" were identified with volumetric degradation approximately 8-9 inches above the TTS. These indications were previously noted (1996), but recorded under a different code, and have not changed since that time. No foreign objects were found among the tubes with volumetric indications and their neighboring tubes. The largest indication is 32% TW degradation, which poses no challenge to the condition monitoring performance criteria.

" No degradation indications related to potential precursor signals such as dents and dings, or to EC signal interferences such as permeability variations, etc. were observed.

  • No precursor signals (e.g., DSI) were found in tubes identified as potentially having an elevated residual stress condition. Therefore, operation until the next inspection at EOC22 is justified without concern for incidence of SCC above the top of the tubesheet in any of the tubes.

" All plugs were found to be in acceptable condition, based on visual inspection and comparison to known visual standards.

h. The effective plugging percentage for all plugging in each SG There were no sleeves installed in the Surry Unit 2 steam generators therefore, the effective plugging percentage remains the same as stated in item (f) above.
i. Following completion of a Unit 2 inspection performed in.Refueling Outage 21 (and any inspections performed in the subsequent operatingcycle), the number of indicationsand location, size, orientation,whether initiatedon primary or secondary side for each service-induced flaw within the thickness of the tubesheet, and the total of the circumferentialcomponents and any circumferentialoverlap below 17 inches from the top of the tubesheet as determined in accordancewith TS 6.4.Q.3.a Tables 9 through 11 below provide the detailed information regarding these indications.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 11 of 15 Table 9 - S mayof Indications Identified in the Hot Leo Tube Ends in SG "A" Row Col Volts Indication Location Inch from Crack Circumferential TEH Length Extent 1 42 0.96 SCI TEH 0.06 27 1 1 0.92 SCI TEH 0.08 - 29 1 90 0.47 SCI TEH 0.04 - 29 1 27 0.96 SCI TEH 1.09 - 34 1 25 1.23 SCI TEH 0.05 - 37 1 76 0.89 MCI TEH 0 - 43 1 89 0.92 SCI TEH 0 - 48 1 69 6.62 SAI TEH 1.06 0.32 1 46 4.46 SCI TEH 0.03 - 116 2 79 0.38 SCI TEH 0 26 2 78 0.9 SCI TEH 0 - 55 2 48 2.34 SC, TEH 0.07 - 71 2 31 2.83 SC! TEH 0.04 - 106 3 63 0.76 SCI TEH 0.1 - 24 3 61 1.72 SCI TEH 0.09 - 27 3 30 0.75 SCI TEH 0.08 29 3 48 1.02 SCI TEH 0.01 - 31 3 88 1.95 SAI TEH 0 0.18 _

3 37 1.52 SCI TEH 0.07 - 50 3 32 2.15 SCI TEH 0.09 - 55 3 15 3.66 SAI TEH 0.17 0.12 _

4 46 0.78 SCI TEH 0.05 32 4 24 1.17 SCI TEH 0.12 40 5 61 0.59 SC! TEH 0.07 27 5 60 0.51 SC! TEH 0.05 32 5 29 1.3 SCl TEH 0.1 35 5 30 1.6 MCI TEH 0.03 51 5 23 0.68 SCI TEH 0.05 59 6 27 1.08 SC! TEH 0.08 27 6 31 2.04 SCl TEH 0.06 48 6 33 4 SC! TEH 0.03 69 6 29 0.68 SCI TEH 0.06 77 7 32 1.22 SCI THE 0.09 43 7 31 0.87 SCI TEH 0.09 55 8 29 1.14 MCI TEH 0.08 31 8 30 3.19 SCI TEH 0.06 42 8 54 1.76 MCI TEH 0 67 9 32 1.45 SC! TEH 0.09 29 9 28 0.78 SCI TEH 0.09 42 10 26 0.79 SCI TEH 0.06 39 10 29 0.95 MCI TEH 0.09 - 47 10 31 0.89 SCI TEH 0.11 - 51 11 31 0.45 SC! TEH 0.07 - 27 11 48 0.9 SCI TEH 0.09 - 35 11 37 0.9 SCI TEH 0.08 - 67 11 56 1.1 SC! TEH 0.13 - 67 12 40 1.62 SCI TEH 0.08 - 37 12 36 3.05 SC! TEH 0.16 - 45 12 29 1.82 MCI TEH 0.09 - 159 13 53 1.56 SCI TEH 0 - 48 14 36 1.09 SCI TEH 0.03 - 26 14 34 1.28 SCI TEH 0.13 - 51 15 26 1.26 SCI TEH 0.07 - 32 15 37 1.24 SCI TEH 0.08 - 51 15 59 3.47 SCI TEH 0.06 - 64 16 32 0.73 SCI TEH 0.07 - 26 18 30 0.97 SCI TEH 0.05 j 35 18 44 1.97 SC! TEH 0.08 55 18 7 13.79 SCI TEH 0.04 79 29 23 0.5 SCI TEH 0.05 24 Note: 60 tube ends with 60 indications (3 axial and 57 circumferential) - R1C46, R2C31, and R12C29 were plugged based on circumferential extent exceeding IARC criteria.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 12 of 15 Table 10 - Summary of Indications Identified in the Hot Leg Tube Ends in SG "B" Row Col Volts Indication Location Inch from Crack Circumferential TEH Length Extent 1 63 1.27 SAI TEH 0.13 0.13 1 63 1.58 SAI TEH 0.13 0.13 2 59 2.45 SAI TEH 0.07 0.16 _

2 69 2.86 SAI TEH 0.08 0.16 2 76 1.7 SCI TEH 0.08 - 69 4 67 1.05 SAI TEH 0.17 0.24 4 50 1.99 SAI TEH 0.09 0.23 4 66 1.22 SCI TEH 0.05 - 64 4 66 2.09 SCI TEH 0.1 - 66 5 67 1.21 SCI TEH 0.09 - 61 6 69 2.09 SAI TEH 0.12 0.15 8 54 0.67 SCI TEH 0.08 - 37 8 50 0.61 SCI TEH 0.08 - 71 9 67 1.08 SCI TEH 0.02 - 40 10 55 1.1 SCI TEH 0.03 - 64 11 62 0.88 SAI TEH 0.16 0.16 11 65 2.34 SAI TEH 0.09 0.19 11 50 1.14 SCI TEH 0.04 - 80 13 77 1.45 SCI TEH 0.13 - 29 14 77 2.05 SCI TEH 0.05 - 39 15 55 0.69 SCI TEH 0.14 - 32 15 59 2.08 SCI TEH 0.07 - 35 15 76 0.78 SCI TEH 0.05 - 117 16 66 0.46 SCI TEH 0.07 - 29 16 59 2.67 MCI TEH 0.01 69 17 70 1.1 SCI TEH 0.06 - 34 17 80 0.62 SCI TEH 0.03 - 37 18 50 1.35 SCI TEH 0.06 - 35 18 62 1.78 SCI TEH 0.06 - 66 19 64 0.9 SCI TEH 0.07 - 40 20 49 1.22 SCI TEH 0.03 - 31 22 50 2.23 SCI TEH 0.07 - 69 22 64 1.01 SCI TEH 0.03 - 88 24 67 2.31 SCI TEH 0.04 - 77 25 49 0.38 SCI TEH 0.05 - 37 27 56 1.25 SCI TEH 0.08 - 32 30 58 1.4 SCI TEH 0.07 - 32 33 59 1.29 SC0 TEH 0.02 34 34 59 1.13 SCI TEH 0.02 - 26 Note: 37 tube ends with 39 indications (9 axial and 30 circumferential) - R1 5C76 was plugged based on circumferential extent exceeding IARC criteria

Serial No. 08-0687 Docket No. 50-281 Attachment Page 13 of 15 Tnh~a41I- -m~mm=a~ nf inrir-ntrnncIrionfifiarl in fIta We~f I Am Tiho Fznric in -qr "C""

LL Z2 Row Col Volts Indication Location Inch from Crack Circumferential TEH Length Extent 4 50 1.41 SCI TEH 0.15 31 17 55 1.77 SCI TEH 0.08 31 11 54 1.14 SCI TEH 0.04 32 9 25 0.62 SCI TEH 0.03 34 3 86 1.11 SAI TEH 0.14 0.12 -

5 50 1.72 SCI TEH 0.08 - 37 1 49 1.88 SCI TEH 0.09 - 42 1 76 1.96 SAI TEH 0.13 0.27 -

1 38 2.63 SAI TEH 0.13 0.18 -

1 38 3.54 SAI TEH 0.18 0.18 -

1 48 1.69 SAI TEH 0.15 0.18 -

.8 50 1.85 SCI TEH 0.03 - 50 2 48 1.76 SCI TEH 0.03 - 51 15 53 1.45 SCI TEH 0.07 55 6 32 0.73 SCI TEH 0.07 56 19 27 2.76 SC0 TEH 0.06 58 3 48 2.72 SCI TEH 0.05 - 61 3 35 5.57 SAI TEH 0.16 0.18 2 50 4.02 SCI TEH 0.06 - 74 1 51 1.84 MCI TEH 0.07 109 1 63 3.07 MCI TEH 0.04 - 117 Note: 20 tube ends with 21 indications (6 axial and 15 circumferential) - R1C51 and R1iC63 were plugged based circumferential extent exceeding IARC criteria

j. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the primary to secondary LEAKAGE rate observed in each steam generator(if it is not practicalto assign leakage to an individual (SG), the entire primary to secondary LEAKAGE should be conservatively assumed to be from one steam generator)during the cycle preceding the inspection which is the subject of the report.

No operating leakage was noted during cycle 21, including prior to the shutdown.

Serial No. 08-0687 Docket No. 50-281 Attachment Page 14 of 15

k. Following completion of a Unit 2 inspection performed in Refueling Outage 21 (and any inspections performed in the subsequent operating cycle), the calculated accident leakage rate from the portion of the tube below 17 inches below the top of the tubesheet for the most limiting accidentin the most limiting steam generator.

The accident condition leak rate from cracks in the tubesheet is limited to the operating leakage times 2.5 or less. Since there was no operating leakage, it follows that there would be not be any leakage at accident conditions. Since the burst and leak rates considerations are satisfied, these indications met the structural and leakage performancecriteria (condition monitoring) prior to shutdown.

I Serial No. 08-0687 Docket No. 50-281 Attachment Page 15 of 15 Table of Acronyms AVB Anti Vibration Bar BLG Bulge BPH Baffle Plate Hot C or Col Column CL Cold Leg CMOA Condition Monitoring and Operational Assessment DEP Deposit DNG Ding DNT Dent DSI Distorted Support Signal EC Eddy Current ECT Eddy Current Testing EFPY Effective Full Power Years EOC End of Cycle ETSS Examination Technique Specification Sheet FB Fan Bar FOSAR Foreign Object Search and Retrieval HL Hot Leg ID Inner Diameter Ind Indication LPI Loose Part Indication MBM Manufacturing Burnish Mark MCI Multiple Circumferential Indication NDD No Discernible Degradation NTE No tube Expansion NQH Non-Quantifiable Historical Indication NQI Non-Quantifiable Indication OD Outer Diameter ODSCC Outer Diameter Stress Corrosion Cracking OVR Over Roll OXP Over Expansion PLP Possible Loose Part PTE Partial Tubesheet Expansion PWSCC Primary Water Stress Corrosion Cracking R Row RPC Rotating Pancake Coil SG Steam Generator SLG Sludge SAI Single Axial Indication SCI Single Circumferential Indication SSI Secondary Side Inspection SVI Single.Volumetric Indication TEC Tube End Cold-leg TEH Tube End Hot-leg TSC Top of Tube Sheet Cold-leg TSP Tube Support Plate TSH Top of Tube Sheet Hot-leg TTS Top Tube Sheet TW Through Wall VOL Volumetric Indication WAR Wear Indication

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