L-2011-119, Submittal of Steam Generator Tube Inspection Report

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Submittal of Steam Generator Tube Inspection Report
ML11119A006
Person / Time
Site: Turkey Point NextEra Energy icon.png
Issue date: 04/19/2011
From: Kiley M
Florida Power & Light Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
L-2011-119
Download: ML11119A006 (28)
v • d • e


Text

POWERING TODAY.

~APR 19 2011 EMPOWERING TOMORROW. L-2011-119 10 CFR 50.36 U. S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555-00001 Re: Turkey Point Unit 3 Docket No. 50-250 Steam Generator Tube Inspection Report The attached Turkey Point Unit 3 Refueling Outage 25 Steam Generator Tube Inspection Report is submitted to NRC in accordance with Turkey Point Technical Specification 6.9.1.8, and within 180 days after the initial entry to MODE 4 following completion of the inspections performed in accordance with Technical Specification 6.8.4.j, Steam Generator (SG) Program.

The report includes the following:

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,
h. The effective plugging percentage for all plugging in each SG,
i. The primary to secondary leakage rate observed in each SG during the cycle preceding the inspection which is the subject of the report,
j. The calculated accident induced leakage rate from the portion of the tubes below 17.28 inches from the top of the tubesheet for the most limiting accident in the most limiting SG, and
k. The results of monitoring for tube axial displacement (slippage).

I an FPL Group company

L-2011-119 Page 2 of 2 Should there be any questions, please contact Robert Tomonto at (305) 246-7327.

Sincerely, Michael Kiley Vice President Turkey Point Nuclear Plant Enclosure Attachments cc: Regional Administrator, Region II, USNRC.

Senior Resident Inspector, USNRC, Turkey Point Plant

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 1 of 11 Attachment 1

Background

This report is provided in accordance with Turkey Point Unit 3 Technical Specification 6.9.1.8, "Steam Generator Tube Inspection Report" for the inspection conducted October 7th to 12th, 2010 during refueling outage twenty-five (TP3-25). TP3-25 is the third refueling outage in the third ( 3 rd)

ISI period (60 EFPM). The replacement Westinghouse model 44F steam generators (SGs) were installed in PTN Unit 3 in April, 1982. The TP3-25 inspection was the second inspection in the 3 rd ISI period and also the last scheduled inspection in the 3 rd ISI period. The SGs have accumulated 22.19 effective full power years of operation at the TP3-25 refueling outage.

Following the TP3-25 refueling outage, Turkey Point Unit 3 initially entered HOT SHUTDOWN on November 2, 2010.

The TP3-25 SG tube inspections were conducted in all three SGs (3A, 3B, & 3C) as described below.

a. The scope of inspection performed on each steam generator The scope of this examination is summarized in Table 1 below and is established to meet the following requirements:
a. Technical Specification 6.8.4.j "Steam Generator (SG) Program"
b. Technical Specification 6.8.4.j.d.2 "Inspect 100% of the tubes at sequential periods of 120, 90, and, thereafter, 60 effective full power months. The first sequential period shall be considered to begin after the first inservice inspection of the SGs. In addition, inspect 50% of the tubes by the refueling outage nearest the midpoint of the period and the remaining 50% by the refueling outages nearest the end of the period. No SG shall operate for more than 48 effective full power months or two refueling outages (whichever is less) without being inspected."
c. Steam Generator Management Program: Pressurized Water Reactor Steam Generator Examination Guidelines: Revision 7. EPRI, Palo Alto, CA: 2007. 1013706.

The TP3-25 inspections are intended to satisfy the surveillance requirement for the 2nd half of the 3rd ISI Period.

The basis for bobbin and +PointTM tube examinations is given in Table 1.

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 2 of 11 Attachment 1 TABLE 1 BASIS FOR TUBE EXAMINATION SAMPLES Technique Examination Sample Required or Basis Potential Supplemental Degradation 100% full length in rows 3 and higher. Row 1 & 2 examinations were limited to the hot Wear/

leg and cold leg straight sections. Required Degradation Assessment ODSCC Bobbin Screening of 100% of dings < 5 volts in straight sections (verticals). This included Required Degradation Assessment ODSCC tubes with low-voltage u-bend offset (LVU) tubes per AREVA FDMS (')

50% of the hot leg tubesheet to the extent of TTS +3.00 to -17.28 inches. This Required ENG CSI-2.2, Rev. 32, Foreign Object included minimum 50% sample of BLG & OXP indications within the TS. Checklist item 1..D, and the Wear The hot leg full depth tubesheet examination included one unexpanded tube in SG 3A, Degradation Assessment. PWSCC two unexpanded tubes in SG 3B, and five unexpanded tubes in SG 3C identified with Required previous NTE indications (No Tube Expansion) that required a full tubesheet ODSCC inspection from TEH to TSH +3.00 Inches. Note: Unexpanded tubes required plugging, based on LAR 241 (2)to limit tubesheet inspection to a depth of 17.28".

All Hot Leg and Cold Leg Periphery Expansion Transitions - +3"/-2" from top of ENG CSI-2.2, Rev. 32, Foreign Object tubesheet. "Periphery Tubes" are defined as the two outer-most peripheral tubes Required Checklist item 1.D., and the Wear exposed to the annulus, and all open row 1 and 2 tubes in columns 1-92. Degradation Assessment.

Cold Leg full depth tubesheet: Required ENG CSI-2.2, Rev. 32, PWSCC Checklist item 1I.D., and the ODSCC One unexpanded tube in SG 3B identified with previous NTE indications (No Tube Degradation Assessment.

Note:

+PnTMExpansion) required a full tubesheet inspection from TEC to TSC +3.00 Inches.

+Pointa Unexpanded tubes required plugging, based on LAR 241 (2) to limit tubesheet inspection to a depth of 17.28".

Tight radius u-bends - Required Degradation Assessment. PWSCC

-50% of row 1 and 2 (not inspected in prior inspection) ODSCC PWSCC ODSCC 50% of hot leg freespan dings > 5 volts between TSH and 06H +1.00" (not inspected Required Degradation Assessment.

in prior inspection) ____

PWSCC Required Degradation Assessment. ODSCC 50% of u-bend dings (not inspected in prior inspection)

PWSCC 50% of hot leg dents/dings at structures (not inspected in prior inspection) Required Degradation Assessment. ODSCC (1) AREVA FDMS is AREVA's Data Management System I,

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 3 of 11 Attachment 1

b. Active degradation mechanism found The TP3-25 bobbin and +PointTM examination results for Turkey Point Unit 3 identified mechanical wear degradation at the following locations:

" Wear at anti-vibration bars

" Wear at tube support plates

  • Wear at flow baffle plates Other than wear degradation as discussed above, there were no indications of any tube degradation in the +PointTM probe examination samples identified in Table 1.
c. Nondestructive examination techniques utilized for each degradation mechanism Turkey Point Unit 3 Examination Techniques for TP3-25 (October 2010)

TABLE 2 Industry Damage Demonstrated EKtended Depth Sizing Site.Specific Review Technique Qualification Mechanism Applicability Applicability Technique Deemed Acceptable Applied Detection Sizinci BobbinT Top of Tubeshneet Above Tubesheet Diferertial MYes For Inrormation Revision 11 and TSP Phase Anatys s 2 Bobn60r AVBs TSPs Differential Mix Bobbin 3ear Diagonal and Vertical Straes None Amplitude Analysis Yes For Service 1UsingVert-Max) 96004.2 WerAVs TSS Absolute /ix 3 Bobbin Bobin Reison13Diagonal RevisiWAns 13 and Vertical Strapos None Amplitude Anatlysi (Using vart--Max) Yes For Information 4 96005.2 Piing Freespan in the Presence of Sludge Pile Not Sized with Bolsn Yes For Information Bobin 4 Revision 9 Copper 5 Bobbin 240`13.1 Revision 2 ODSCC Freescman Dings _5.00 Volts None Not Sized writhBobln Yes For Information B bn1-2,6411 6 Drilled TSP Wit*h/ArMnut Nose Sized with Boblin Yes ForInformation Bobbin Revision 2 Axial DSCC I Dents - 2.0 Volts Not 7~Bobn Bob

~ 129412 Revision 2 AxialODSCC Freespan None Not Sized wth Bobbin Yes For Infomtation 8 Bobbin 1-28A13 AxialODSCC Broached TSP. Sludge Pile None Not Sized with Bobbin Yes For Intormation 9 __obb__e 2Revision2 9 Bobbin 27091.2 PLP Wear (DatPLP iiar 0 Revision Part Present N/A Yes N/A not prensent) 10 Poirt- 95511.11.2 Revision PWSCC Low Row U-bend None Single Frequency PhaseFor Infomtn 16 Analysis 11 *Point" 20510.1 Deit, Dings, Non-Dented Single Frequency Phase Yes For Information

-Point- 7 Circ PWSCC Expansion Transition Support St ctures, Yes ForInfrmais Tubesbeet 12 -Point- 20511.1 Aiiai PwSCC Expansion Transition Non-Dented Support Single Frequency Phase Revision 8 Structures, Tubesheet Analysis Yes For Inrom-_tion 13 -Point 96703.1 Aa Non-Dented Support Single Frequency Phase Yes For Information Revision 17 PWSCC DentStructres Tubesheet Anas 14 -Point- 22401.1 4 AxialODSCC Dented Support Stsuctures None Single Frequency Yes For Informaton Revision Analysis Phase ___F____r __o 1-969101 Differential MixAmplitude Revision 10 Wear Broached TSP None Analysis Yes For Serce (Using Vert-Max)

Single Frequency For Sevce only If Revision 4 Volumetric Freespan None Amplitude Analysis Yes nForrvion

'16 +Poinp" Revision 4 (Using Peak-Peak) non-cerrosise 17+on- Revision 22842.35 ODSCC Circ Dented Support Structures None Longitt Sizingo using FromrS Yes For Information TSP, Freespan, Sludge 21410.1 6 Revision C Pile, Dings.

Tubesheet Dents, Single Frequency 18 -Point-Circ Expansion I

gDSCC

.ansition U-ltend Analysis Phase ForInforton AxialI Circ "" 15  : e The sizing parameters in EPRI ETSS 21410.1 are equivalent to those listed in EPRI Report TR 107"197-P1 See Section 3.0

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 4 of 11 Attachment 1 Table 2 (Cont.)

Industry Damage Demonstrated Extended Depth Sizing Site-Specific Review Technique Qualification Mechanism Applicability Applicability Technique Deemed Acceptable Applied Detection Sizing S-ngle Frequency 19 Point Revision 12 COrcPWSCC Expansion Transition Dents, Dings, Tuttesheet (Us*nA*Peak-Peak)nBased Yes For Informayios on Max Depth Phase 27901 1 27902.1 27904.1 PLP Wear Morphology PLP Wear Morphology 20 *Point' 27905.1 PLP Wear Dependent None Dependent Yes For Service 27906.1 (part not present) (part not present) 27907.1 Revision 0 21 -Pit- Revision 2 Axial ODSCC Sludge Pile Pitting IntheSludge Pile Not qualified Yes No 22 22 ÷PinF-Poinr, Revision 1-2e425 2 AIal O0CC Freespan. Broached TSP None Not qualified Yes No 23 +Point" 1-28431 None Single Frequency/

Revision Iat OOSCC Sludge Pita Amplitude Analysis No For Information 24 2Piontl 1-28432 1 Revision AxialODSCC Freaspan, Brched TSP None Single Frequency Amplitude Analysis No For Irformation 25 .115Pancake 21401.1 1 AllLocations exceot Ubends, None Single Frequency PhaseFor Inortion Revision Dents. Expansions Analysis Is the prinary detection coil 26 .115Pancake 21402.1 Single Frequency Phase

.15 acae Reison1 6 Revision Circ ODSCC Expansion Transition Sludge Pile Analysi ynalasesFor Informa__

221503.1 1P e.115Pancake 27 Revision 4 AxialExpansionSingle Aal PSCC psin Transition Sludge Pile Frequency AnalysisPot Phase For Infor on 21041Single Ffequenrl Phase is the primary 2a .115Pancake Revision 4 Circ PWSCC Expansion TransitSnn Sludge Pile Ps detection coil For Infornmation Single Frequency Info only: Use 29 .115Pancahe 1 Pitting Freespan in the Presence o1 None Amphtude Analysis 96005.2 psu pine for For Informration Revision 5 Copper (Using Peak-Peak) sludge pile _________

96911.1 Absolute M9m 30 .115 Pancake Revision 9 Wear Broached TSP PLP Wear Amplitude Analysis For Service (Using Vert-MEx) 580 F 21051 inge Frqueny Phse +Point'*

31 .080 HF 215051 3 Axial PWSCC Expansion Transition Sludge Pile Single Frequency Pancake Revision Analysis Phase Isthe pnnriar detection coil For Information 32 .080 HF 21506.1 Single Frequency Phase ForInsormation Pancake Revision 4 Circ PWSCC Expansion Transition Sledge Pe Analysis support structures, Expanssion Transition Single Frequency Phase yes For Inlormation 21409i AxialODSCC Freespan region,sludge p0l AxialI Circ Analysis 33 I Point Revision 7 I and tubesheet crevice I I I I The sizing parameters in EPRI ETSS 21410.1 are equivalent to those listed in EPRI Report TR 107 197-Pi.

d. Location, orientation (if linear) and measured sizes (if available) of service induced indications Please refer to Attachments 2, 3 & 4 for indication listings for SG 3A, 3B and 3C respectively. All wear indications are on the outside surface (OD) of the tubes.
e. Number of tubes plugged during the inspection for each nonconforming condition (See Next Page)

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 5 of 11 Attachment 1 Turkey point Unit 3 Tube Plugging TP3-25(')

Table 3 Nonconforming Condition SG A SG B SG C Total No Tube Expansion (NTE) for H*criteria 1 3 5 9 Preventative Tube Plug (PTP), or, 0 2(2) 3(3) 5 Tube to Be Plugged (TBP) I I I I _ _ _

Total 1 5 8 14 (1) Row 33 column 44 in SG 3A was un-plugged and tested with bobbin and +PointTM to address previous AVB wear. This tube was stabilized and re-plugged, but is not counted in Table 3 above.

(2) Two tubes (R6-C45 and R7-C45) were plugged based on the presence of wear coincident with a small foreign object located at the top of the second cold leg support (020). Aqualified sizing technique is not available to size the tubes for service when a foreign object is still present. The indications in these tubes were sized at 8% and 14%, respectively, for integrity assessment purposes.

(3) Two tubes (R21 -C61 & R29-C77) were plugged based on wear adjacent to the lower edge of the 04H and 03H supports, respectively. Tube R30-C45 was PTP based on measured AVB wear at AV3.

f. Total number and percentage of tubes plugged to date Table 4 Turkey Point Unit 3 Steam Generator Cumulative Tube Plugging Summary TP3-25 SG # Plugged  % Plugged 3A 48 1.5%

3B 74 2.3%

3C 62 1.9%

g. The results of condition monitoring including the results of the tube pulls and in-situ testing All tubes inspected met the tube integrity performance criteria in TS 6.8.4.j.b and condition monitoring requirements. No tubes required in-situ pressure testing. No tube removal was required.

TURKEY POINT UNIT 3 L-201 1-119 Steam Generator Tube Inspection Report Page 6 of 11 Attachment 1

h. The effective plugging percentage for all plugging in each steam generator No tube repair methods (i.e. sleeving) are approved for Turkey Point Unit 3 that would have an effect on the effective plugging percentages. Therefore, the effective plugging percentage is equal to the % Plugged in item f. above.

The primary to secondary leakage rate 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 subject to the report.

No primary to secondary leakage was reported during the preceding cycle of operation.

j. The calculated accident induced leakage rate from the portion of the tubes below 17.28 inches from the top of the tubesheet for the most limiting accident in the most limiting SG. In addition, if the calculated accident induced leakage rate from the most limiting SG is less than 1.82 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined The accident induced leakage rate from the portion of the tubes below 17.28 inches from the top of the tubesheet is calculated as a ratio of observed normal operating leakage that cannot be attributed to a source other than the tubesheet expansion region. For the operating period preceding the TP3-25 inspection, no operational primary-to-secondary leakage has been observed.

Further, there are no degradation mechanisms that have the potential for leakage.

For Turkey Point Unit 3, the maximum operational primary to secondary leakage rate from the portion of the tubes below 17.28 inches from the top of the tubesheet is multiplied by a factor of 1.82 to determine the accident induced leakage. Since no operational primary-to-secondary leakage has been observed, the calculated accident induced leakage rate from the portion of the tubes below 17.28 inches from the top of the tubesheet is zero.

Therefore, neither the normal operating leakage limit nor the accident induced leakage limits will be challenged during the next operating period.

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

Monitoring for tube slippage was completed in accordance with commitment #1 in Ref. 1. No tube slippage was discovered based on the results of the TP3-25 SG inspections.

References

1. FPL Letter # L-2009-209 to the US NRC, dated September 30, 2009 'Turkey Points Unit 3 and 4, Docket Nos. 50-250 and 50-251, Response to Request for Additional Information, License Amendment Request for H*: Alternate Repair Criteria for Steam Generator Tubesheet Expansion Region".

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 7 of 1I Attachment 1 Abbreviations CSI - Component Support and Inspections SG - Steam Generator ISI - In-service Inspection ECT - Eddy Current Testing NEI - Nuclear Energy Institute EPRI - Electric Power Research Institute Acronyms H/L - Hot Leg C/L - Cold Leg VOL - Volumetric Indication SVI - Single Volumetric Indication PIT - Pit Indication PLP - Possible Loose Part WAR - Mechanical Wear TWD - Through Wall Depth TSH - Tubesheet Hot Leg TEH - Tube End Hot Leg TSC - Tubesheet Cold Leg TEC - Tube End Cold PTP - Preventative Tube Plug

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 8 of 11 Attachment 1 ADDITIONAL INFORMATION The following information is included to assist the staff in their review of the information provided in this report.

Secondary Side Inspection Secondary side inspection information is not required by TS Section 6.9.1.8. However, this information is being provided based on NRC requests for additional information regarding previous reports submitted by FPL in accordance with this specification:

Secondary Side Inspections (SSI) during the TP3-25 refueling outage include the following:

  • Upper Bundle Flush (UBF)
  • Sludge Lance
  • FOSAR (Foreign Object Search and Retrieval)
  • Upper Bundle and Top Down Inspection in one SG Upper bundle flush and sludge lancing was completed in all three steam generators. The processes recovered 49 lbs of sludge from SG 3A, 70.5 lbs from SG 3B and 66.0 lbs from SG 3C. Pre -bundle flush upper bundle and top down inspections were completed in only SG 3B. Deposits observed were very light and therefore, post-flush inspections were not warranted. No abnormalities were noted.

SG 3A During post-lance inspections of SG 3A, one legacy foreign object was removed from the hot leg at location R14-15 C68-69. (Item 1 in Table 5). No tube damage was identified by visual or ECT methods.

One ECT PLP was investigated at R3 C57. (Item 2 in Table 5). The object was fused to the tubesheet within a hard deposit and could not be removed.

SG 3B During post-lance inspections of SG 3B, two foreign objects were successfully removed. One item was located in the H/L at R43 C46-47 (Item 11 in Table 5). The second item was in the H/L annulus, but had no tube contact (Item 12 in Table 5). No tube damage was reported by visual or ECT methods.

Several legacy foreign objects were re-investigated for presence, signs of movement, and the possibility of removal. (Items 3,5,6,8,9 in Table 5). These items remain fixed in their locations and were not removed. No tube damage was reported at these locations by visual or ECT methods.

TURKEY POINT UNIT 3 L-2011-119 Steam Generator Tube Inspection Report Page 9 of 11 Attachment 1 SG 3B (Cont.) Possible Loose Part (PLP) Signals Reported by ECT Possible Loose Part (PLP) Signals reported during the ECT Exam are investigated during FOSAR operations. During TP3-25, five such PLP indication locations were investigated, and no foreign objects were found at those locations. In SG B, PLP indications were reported during the ECT examination, at the 02C location in tubes R6-C45 and R7-C45. These locations were not accessible due to the location in the tube bundle. Tubes R6-C45 and R7-C45 were plugged based on the presence of wear coincident with the PLP indications. The indications in those tubes were sized at 8% and 14%, respectively, for integrity assessment purposes.

SG 3C Post sludge lancing inspections in SG 3C identified the three new metallic foreign objects in the H/L tube bundle and annulus (Items 14,16,17 in Table 5). All three objects were removed and no tube damage was observed by ECT or visual.

One legacy foreign object (Item 13 in Table 5) and one new object (Item 15 in Table 5) were seen and are firmly wedged or fused in place. Retrieval attempts were not successful. No tube damage was reported by ECT or visual.

Foreign Object Tracking for SGs A, B, C Items 2, 3, 5, 6, 8, 9, 13, 15 in Table 5 were unable to be retrieved from the SGs. These items will continue to be actively tracked during future FOSAR inspections.

Items 1, 11,12,14,16,17 in Table 5 were removed from the SGs during the TP3-25 FOSAR inspections and will not be actively tracked in the future.

Items 4 and 7 were not observed in either the TP3-23 or TP3-25 FOSAR inspections. These items have been documented, but will not be actively tracked in future outages.

Item 10 in Table 5 was not observed during the TP3-25 FOSAR inspection. Item 10 will continue to be actively tracked during the next FOSAR inspection.

No tube degradation was associated with any of the objects in Table 5. All objects remaining in the SGs have been evaluated for potential impact on plant operation and tube integrity and were determined to be acceptable for the planned operating period.

TURKEY POINT UNIT 3 L-2011-119' Steam Generator Tube Inspection Report Page 10 of 11 Attachment 1 Table 5 Initial TP3-20 Location TP3-21 Location & TP3-22 Location TP3-23 Location TP3-25 Location Item SIG Description Location & Basis & Basis (03/03) Basis (10/04) & Basis (3/06) & Basis (9/07) & Basis (10/10) 2.25" L X 1/8" W FOSAR -

H/L R14 C68 & No History, new No History, new object No History, new Observed. No Seen By FOSAR 1 3A Metallic Piece (Previously called C69 object TP3-23 TP3-23 Object TP3-23 retrieval attempted, Retrieved 10-10-10 tube scale) 9/16/07

.359"L x .05"W Seen By ECT Seen by 2 3A object embedded H/L R3 C57 in No History had NodeositNot History No History No History FOSAR New Object Retrievable in hard deposit 10-10-10 HL TS; R44 FOSAR - Observed, current FOSAR- Observed location remains unchanged, FOSAR- Observed FOSAR- Observed 3 3B IX 1/4" SLAG C40, R44 C41, 1R45C41, R45 Same as initial location& basis new dimensions reported 1" x.359". ECT - N/A, these Retrieval unsuccessful 3-15-06 Retrieval 10/13/10 10/13/10 C42 ECT 03/97 tubes are plugged 9/14/07

<0.365"X0.5"L FOSAR-Observed, current FOSAR Observed.

4 3B Shaped Object CL TS; R9 C2 Same as initial location Remains Retrieval unsuccessful. FOSAR-Object not FOSAR-Object not (CRO3-0684) FOSAR 03/03 location & basis. unchanged. ECT Not 3-15-06found. 9/14/07 Found. 10/13/10 observed.

FOSAR- Observed FOSAR - Observed. FOSAR- Observed RetriealvNo HL TS, R22 No history object FOSAR - Observed, retrieval Retrieval unsuccessful. Retrieval Retrieval Not 0.5" L x 0.365" 53B Rock like piece C77, R23 C77 initially observed unsuccessful. Object is fixed Sludge rock remains. 3- unsuccessful Attempted FOSAR 10/04 TP3-21. ECT - Not observed 15-06 9/14/07 Hard Sludge 10/13/10 Seen SeeBy ECT FOS AR-d Hard FOSAR - Observed. FOSAR- Observed 0.5" L x 0.359" CL TS; R I No history object FOSAR - Observed, retrieval Retrieval unsuccessful. Retrieval Observed Hard 6 3B Flake shaped C72, RI C73 initially observed unsuccessful. Object is fixed Sludge rock remains.3- Unsuccessful Deposit object FOSAR 10/04 TP3-21. ECT - Not observed 15-06 9/14/07 Retrieval Unsuccessful 10/13/10 HL TS; R32

.25" L x .25" W C60, R32 No history object FOSAR - Observed, retrieval FOSAR- Observed FOSAR - Not FOSAR - Not 7 3B Rock shaped C61, R33 C60, initially observed unsuccessful. Object is fixed Retrieval unsuccessful observed. 9/14/07 Observed. 10/13/10 object R33 C61 TP3-21. ECT - Observed, no tube 3-15-06 FOSAR 10/04 wall damage.

Hard sludge -1" FSR above HL FOSAR - Observed, Visually FOSAR Observed.-

tubesheet On tube HL Tubesheet No history object verified as hard sludge collar r Observed. Observed. Seen By ECT Seen By 8 3B tself Scal 3BSitself Scale e R3 C43 FOSAR 10/04 initially observed TP3-21.

on tube. Retrieval unsuccessful. Observed by retrieval unsuccessful. Retrieval FOSAR Not Retrieved unsuccessful 10/13/10 Embedded in hard FOSA 1/ u ucessfu Obsered l 15-06 9/14/07 pile ECT, no tube wall damage.

TURKEY POINT UNIT 3 L-2011-119' Steam Generator Tube Inspection Report Page 11 of 11 Attachment 1 Table 5 (Cont.)

Initial TP3-20 Location TP3-21 Location & TP3-22 Location TP3-23 Location TP3-25 Location Item SIG Description Location & Basis & Basis (03/03) Basis (10/04) & Basis (3/06) & Basis (9/07) & Basis (10/10)

FOSAR - Observed, FOSAR - Observed.

Hard sludge On HL Tubesheet No history object Visually verified as Broke into smaller initially observed hard sludge in the FOSAR - Not Seen By FOSAR not 9 3B Tubesheet between B

R20 C59 observed. 9/14/07 retrievable 10/13/10 tubes .395 W x R20 C60 TP3-21. oarea, intiy retrieval pieces during retrieval attempt.

1/16"High FOSAR 10/04 unsuccessful. ECT - 3-15-06 Not observed

.395" x .395" H/L R30 - No history, object No history, object FOSAR - Sludge FOSAR-Part FOSAR Not 10 3B Sludge Rock H/L C74 / 75 initially observed initially observed rock remains, remains. Observed Observed R30 - C74 / 75 TP3-22 TP3-22. 3-15-06 at R30 C72 C73 10-13-10

.75"L x. 10" H/L R43 C47 Observed by FOSAR 11 31 Crescent shaped R43 C46, No History No History No History No History New Item Retrieved metallic object 10-13-10 H/L Annulus Observed by FOSAR 3" L x. 10 W 12 3B Metallic wire No tube Contact No History No History No History No History New Item Retrieved 10-13-10 FOSAR - Observed, FOSAR- observed.

HL Tubesheet No history object retrieval unsuccessful. FOSAR - Rock shaped FOSAR Observed

.395"L x .25"W 13 3C R Rock like objec R13 C21 FOSAR 10/04 initially observed Object fixed ECT - Observed. Adhered Fused to tubesheet TP3-21. Observed, no tube to tubesheet 3-16-06 sludge particulate. 10-7-10 wall damage. 9/18/07 1.5"L x. 13W H/L No History No History No History No History Observed by FOSAR 14 3C Metallic Pin R38 C37-39 Retrievedl0-7-10 Observed by FOSAR 15 Flat Object H/L No History No History No History No History New Item Tightly 15 C "L by. 12"W R33-34 C36-37 Wedged/Retrieval Unsuccessful 10-7-10 f/L Annulus Observed By FOSAR 3"L x. 13 W 16 3C Metall Pin elic No tube contact No History No History No History No History New Item Retrieved 10-7-10 Observed By FOSAR 1.5"L x. 12W 17 X Metallic Pin H/L R32 C60-61 No History No History No History No History New Item Retrieved 1 _10-8-10

Turkey Point Unit 3 L-2011-119 Steam Generator Tube Inspection Report Attachment 2 SG 3A, Page 1 of 4 SG 3A Indication Listings Listing Description Page No.

Tubes Plugged Listing 2 Bobbin WEAR at AVB locations 20-100%TWD 2 Bobbin WEAR at AVB locations 1-19% TWD 3 WEAR (WAR) sized by +PointTM probe 1-100% (AVB) 3 WEAR (WAR) sized by +PointTM probe 1-100% (Broach/Baffle) 4

(

Turkey Point Unit 3 L-2011-119 Steam Generator Tube Inspection Report Attachment 2 SG 3A, Page 2 of 4 Turkey Point Unit 3 (TP3-25)

SG 3A Tubes Plugged Listing 10/10 - TP3-25 TP3-25 ECT Results for Tubes Repaired by Plugging ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 32 47 NDD TEH TSH 15 HOT 720PP 5.03 41 2 NTE TSH +0.00 TEC TEH 6 HOT 720UL 5.31 41 2 PID TSH +0.00 TEC TEH HR 6 HOT 720UL PTP TEC TEH 6 HOT 720UL

  • 33 44 0.69 101 P5 WAR AV3 -0.27 06H 06C 31 96910.1 42 COLD 6801P 1.50 87 P5 WAR AV3 +0.28 06H 06C 50 96910.1 42 COLD 6801P 2.30 75 P5 WAR AV2 -0.06 06H 06C 64 96910.1 42 COLD 6801P 0.50 104 P5 WAR AV2 +0.44 06H 06C 25 96910.1 42 COLD 6801P 0.73 103 P5 WAR AV4 -0.19 06H 06C 32 96910.1 42 COLD 6801P 0.69 105 P5 WAR AVI +0.42 06H 06C 31 96910.1 42 COLD 6801P 0.87 112 P2 TWD 24 AVI -0.06 TEH TEC 18 COLD 720UL 7.82 93 P2 TWD 60 AV2 -0.15 TEH TEC 18 COLD 720UL 0.46 96 P2 TWD 18 AV2 +0.36 TEH TEC 18 COLD 720UL 1.31 111 P2 TWD 29 AV3 -0.34 TEH TEC 18 COLD 720UL 4.57 95 P2 TWD 50 AV3 +0.27 TEH TEC 18 COLD 720UL 1.08 126 P2 TWD 26 AV4 -0.25 TEH TEC 18 COLD 720UL 7.82 93 P2 PID AV2 -0.15 TEH TEC HR 18 COLD 720UL TBP TEH TEC 18 COLD 720UL Total Tubes 2
  • NOTE 1 Tube 33-44 was de-plugged, inspected with ECT, and re-plugged during TP3-25.

NOTE 2 Tubes with no tube expansion have "NTE" in the "IND" column. +PointTM depth estimates are in the "UTIL I" column. Bobbin depth estimates are in the "%TW" column.

Turkey Point Unit 3 (TP3-25)

SG 3A 10/10 - TP3-25 Bobbin WAR at AVB's 20-100%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 28 59 0.69 69 P2 TWD 21 AV3 +0.00 TEC TEH 6 HOT 720UL 0.96 93 P2 TWD 26 AV2 +0.00 TEC TEH 6 HOT 720UL 30 52 0.86 100 P2 TWD 24 AV3 -0.18 TEC TEH 6 HOT 720UL 31 44 0.79 98 P2 TWD 21 AV3 +0.35 TEH TEC 2 COLD 720UL 37 47 1.48 88 P2 TWD 33 AV3 +0.00 TEC TEH 5 HOT 720UL 38 65 0.63 59 P2 TWD 20 AV3 +0.04 TEC TEH 7 HOT 720UL Total Tubes  : 5 Total Records: 6

Turkey Point Unit 3 L-2011-119 Steam Generator Tube Inspection Report Attachment 2 SG 3A, Page 3 of 4 Turkey Point Unit 3 (TP3-25)

SG 3A 10/10 - TP3-25 Bobbin WAR at AVB's 1-19%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 9 62 0.35 88 P2 TWD 13 AV4 +0.00 TEC TEH 2 HOT 720UL 22 44 0.31 54 P2 TWD 9 AV4 +0.04 TEH TEC 1 COLD 720UL 24 10 0.28 146 P2 TWD 8 AV4 -0.11 TEH TEC 7 COLD 720UL 24 40 0.28 138 P2 TWD 8 AV2 -0.35 TEH TEC 1 COLD 720UL 25 67 0.30 110 P2 TWD 11 AV2 -0.24 TEC TEH 7 HOT 720UL 28 59 0.35 97 P2 TWD 13 AVI -0.27 TEC TEH 6 HOT 720UL 0.36 96 P2 TWD 13 AV4 -0.04 TEC TEH 6 HOT 720UL 31 13 0.21 38 P2 TWD 8 AVI +0.24 TEH TEC 6 COLD 720UL 31 41 0.32 89 P2 TWD 9 AV4 +0.00 TEH TEC 1 COLD 720UL 31 44 0.31 60 P2 TWD 10 AV3 -0.35 TEH TEC 2 COLD 720UL 32 42 0.33 122 P2 TWD 9 AV3 -0.27 TEH TEC 1 COLD 720UL 33 15 0.33 157 P2 TWO 12 AV3 -0.33 TEH TEC 6 COLD 720UL 33 43 0.27 110 P2 TWD 9 AV2 -0.15 TEH TEC 2 COLD 720UL 34 31 0.37 74 P2 TWD 13 AV2 -0.26 TEH TEC 4 COLD 720UL 34 46 0.37 45 P2 TWD 10 AV3 +0.40 TEH TEC 1 COLD 720UL 37 47 0.30 134 P2 TWD 12 AV4 -0.20 TEC TEH 5 HOT 720UL Total Tubes  : 15 Total Records: 16 Turkey Point Unit 3 (TP3-25)

SG 3A 10/10 - TP3-25

+PointTM WAR at AVBs ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE

  • 33 44 0.69 101 P5 WAR AV3 -0.27 06H 06C 31 96910.1 42 COLD 6801P 1.50 87 P5 WAR AV3 +0.28 06H 06C 50 96910.1 42 COLD 6801P 2.30 75 P5 WAR AV2 -0.06 06H 06C 64 96910.1 42 COLD 6801P
0. 50 104 P5 WAR AV2 +0.44 06H 06C 25 96910.1 42 COLD 6801P 0.73 103 P5 WAR AV4 -0.19 06H 06C 32 96910.1 42 COLD 6801P 0.69 105 P5 WAR AVI +0.42 06H 06C 31 96910.1 42 COLD 6801P Total Tubes  : 1 Total Records: 6
  • NOTE 1: Tube 33-44 is the tube de-plugged, inspected with ECT, then re-plugged during 10/10 - TP3-25.

Note 2: The qualified EPRI sizing technique used for depth estimates is identified in the Util 2 field and the +PointTm depth is in the "UTIL 1" column.

Turkey Point Unit 3 L-2011-119 Steam Generator Tube Inspection Report Attachment 2 SG 3A, Page 4 of 4 Turkey Point Unit 3 (TP3-25)

SG 3A 10/10 - TP3-25

+PointTm WAR at Supports (Broach support and Baffle Plate)

ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 1 5 0.11 89 2 WAR TSC +3.31 TSC TSC 8 27902.1 22 COLD 680PP 12 19 0.32 92 P5 WAR 03H -0.68 03H 03H 15 96910.1 44 HOT 680PP 14 4 0.41 88 2 WAR 06C -0.73 06C 06C 16 27905.1 36 COLD 680PP Total Tubes  : 3 Total Records: 3 Note: The qualified EPRI sizing technique used for depth estimates is identified in the Util 2 field and the +PointTM depth is in the "UTIL 1" column.

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 3 SG 3B, Page 1 of 4 SG 3B Indication Listings Listing Description Page No.

Tubes Plugged Listing 2 Bobbin WEAR at AVB locations 20-100%TWD 3 Bobbin WEAR at AVB locations 1-19% TWD 3 WEAR (WAR) sized by +PointTM probe 1-100% (AVB) 4 WEAR (WAR) sized by +PointTM probe 1-100% (Broach/Baffle) 4

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 3 SG 3B, Page 2 of 4 Turkey Point Unit 3 (TP3-25)

SG 3B Tubes Plugged Listing 10/10 - TP3-25 TP3-25 ECT Results for Tubes Repaired by Plugging ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 87 NDD 06H TEH 6 HOT 720UL 0.86 104 5 DFH 04H +50.24 06H TEH 6 HOT 720UL NDD TSH TSH 20 HOT 680PP 0.89 12 2 NSU 06H +7.00 06C 06H 20 COLD 6801P 0.21 0 2 NSU 06H +7.00 06C 06H 20 COLD 6801P NDD TEC TSC 15 COLD 680PP NDD 06H TEH 6 HOT 720UL NDD 06C 06H 20 COLD 6801P NDD 06C TEC 8 COLD 720UL 78.09 10 2 NTE TEC +0.65 06C TEC 8 COLD 720UL 78.09 10 2 PID TEC +0.65 06C TEC HR 8 COLD 720UL PTP 06C TEC 8 COLD 720UL 6 45 NDD TSH TSH 38 HOT 680PP 9.24 8 SLG TSH +1.68 TEH TEC 23 COLD 720UL 9.76 8 SLG TSC +0.84 TEH TEC 23 COLD 720UL 0.30 117 Pl DSI 02C +0.62 TEH TEC 23 COLD 720UL 0.14 125 P5 WAR 02C +0.60 02C 02C 8 96910.1 29 COLD 680PP 0.93 94 7 PLP 02C +0.63 02C 02C LAR 29 COLD 680PP 0.9-3 94 7 PID 02C +0.63 02C 02C HR 29 COLD 680PP PTP 02C +0.60 02C 02C 29 COLD 680PP 90 P5 CLP 02C +0.60 02C 02C 0.26 0.17 29 COLD 680PP 7 45 0.34 93 P5 WAR 02C +0.63 02C 02C 14 96910.1 29 COLD 680PP 0.58 94 7 PLP 02C +0.56 02C 02C LAR 29 COLD 680PP 0.58 94 7 PID 02C +0.56 02C 02C HR 29 COLD 680PP PTP 02C +0.56 02C 02C 29 COLD 68OPP 90 P5 CLP 02C +0.63 02C 02C 0.30 0.27 29 COLD 680PP 0.78 115 P1 DSI 02C +0.64 TEH TEC 22 COLD 720UL 0.69 108 5 DFH TSC +12.81 TEH TEC 22 COLD 720UL 11.54 8 SLG TSH +1.60 TEH TEC 22 COLD 720UL 8.46 8 SLG TSC +0.81 TEH TEC 22 COLD 720UL NDD TSH TSH 39 HOT 680PP 19 6 3.49 229 2 NTE TSH +0.00 TEN TEC 6 COLD 720UL 3.49 229 2 PlO TSH +0.00 TEH TEC HR 6 COLD 720UL PTP TEH TEC 6 COLD 720UL NDD TEH TSH 27 HOT 680PP 24 8 4.00 217 2 NTE TSH +0.00 TEH TEC 6 COLD 720UL 4.00 217 2 PID TSH +0.00 TEH TEC HR 6 COLD 720UL PTP TEH TEC 6 COLD 720UL NDD TEH TSH 27 HOT 680PP Total Tubes  : 5 NOTE  : Tubes with no tube expansion have "NTE" under the "IND" column. +PointTM depth estimates are in the "UTIL 1" column.

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 3 SG 3B, Page 3 of 4 Turkey Point Unit 3 (TP3-25)

SG 3B 0/10 - TP3-25 Bobbin WAR at AVB's 20-100%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 30 42 0.94 67 P2 TWD 23 AV2 +0.07 TEH TEC 4 COLD 720UL 1.28 109 P2 TWD 28 AV3 +0.13 TEH TEC 4 COLD 720UL 0.98 88 P2 TWD 23 AV4 -0.19 TEH TEC 4 COLD 720UL 34 31 0.77 81 P2 TWD 20 AV3 +0.00 TEH TEC 4 COLD 720UL 34 53 1.08 98 P2 TWD 28 AV2 +0.02 TEC TEH 9 HOT 720UL 0.87 103 P2 TWD 25 AVI +0.07 TEC TEH 9 HOT 720UL 35 48 0.74 99 P2 TWD 22 AV3 +0.20 TEC TEH 10 HOT 720UL 0.77 72 P2 TWD 23 AV2 +0.02 TEC TEH 10 HOT 720UL Total Tubes  : 4 Total Records: 8 Turkey Point Unit 3 (TP3-25)

SG 3B 10/10 - TP3-25 Bobbin WAR at AVB's 1-19%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE

z ==== ý==

17 31 0.40 127 P2 TWO 10 AV3 -0.44 TEH TEC 3 COLD 720UL 0.20 126 P2 TWD 5 AV4 -0.09 TEH TEC 3 COLD 720UL 26 20 0.51 147 P2 TWD 12 AV4 +0.09 TEH TEC 1 COLD 720UL 26 50 0.39 145 P2 TWD 14 AV4 -0.02 TEC TEH 9 HOT 720UL 30 42 0.49 49 P2 TWD 14 AVI +0.00 TEH TEC 4 COLD 720UL 32 27 0.38 36 P2 TWD 11 AV2 +0.02 TEH TEC 2 COLD 720UL 34 20 0.52 28 P2 TWD 13 AV3 -0.33 TEH TEC 1 COLD 720UL 34 31 0.49 90 P2 TWD 14 AV2 +0.00 TEH TEC 4 COLD 720UL 0.37 118 P2 TWD 11 AV4 +0.00 TEH TEC 4 COLD 720UL 34 33 0.50 50 P2 TWD 14 AV3 +0.00 TEH TEC 4 COLD 720UL 34 52 0.36 67 P2 TWD 13 AV4 +0.00 TEC TEH 10 HOT 720UL 34 53 0.50 114 P2 TWD 17 AV3 -0.44 TEC TEH 9 HOT 720UL 34 59 0.53 46 P2 TWD 18 AV2 +0.02 TEC TEH 10 HOT 720UL 0.34 68 P2 TWD 13 AV4 +0.00 TEC TEH 10 HOT 720UL 0.27 48 P2 TWD 10 AVI +0.00 TEC TEH 10 HOT 720UL 34 73 0.32 50 P2 TWD 12 AV2 -0.22 TEC TEH 12 HOT 720UL 35 48 0.32 102 P2 TWD 12 AV3 -0.26 TEC TEH 10 HOT 720UL 40 47 0.49 110 P2 TWD 17 AV3 -0.13 TEC TEH 10 HOT 720UL 41 34 0.36 35 P2 TWD 10 AV2 +0.00 TEH TEC 4 COLD 720UL 42 53 0.40 77 P2 TWD 14 AV4 -0.04 TEC TEH 9 HOT 720UL 0.29 101 P2 TWD 11 AV3 -0.04 TEC TEH 9 HOT 720UL 0.46 47 P2 TWD 16 AV3 +0.41 TEC TEH 9 HOT 720UL 44 37 0.25 131 P2 TWD 8 AV4 +0.02 TEH TEC 4 COLD 720UL 0.26 118 P2 TWD 8 AV4 +0.29 TEH TEC 4 COLD 720UL 45 46 0.56 90 P2 TWO 15 AV2 +0.00 TEH TEC 4 COLD 720UL 45 49 0.30 165 P2 TWD 12 AV4 +0.11 TEC TEH 10 HOT 720UL Total Tubes  : 19 Total Records: 26

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 3 SG 3B, Page 4 of 4 Turkey Point Unit 3 (TP3-25)

SG 3B 10/10 - TP3-25

+PointTM WAR at AVBs ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE Total Tubes  : 0 No wear indications were reported at the Anti-vibration Bars with +PointTM Total Records: 0 Turkey Point Unit 3 (TP3-25)

SG 3B 10/10 - TP3-25

+PointTm WAR at Supports (Broached support and Baffle Plates)

ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 6 45 0.14 125 P5 WAR 02C +0.60 02C 02C 8 96910.1 29 COLD 680PP 7 45 0.34 93 P5 WAR 02C +0.63 02C 02C 14 96910.1 29 COLD 680PP 21 42 0.18 91 P5 WAR 03C +0.51 03C 03C 8 96910.1 29 COLD 680PP 26 41 0.22 74 P5 WAR 03C +0.58 03C 03C 9 96910.1 29 COLD 680PP 39 64 0.50 94 P5 WAR BAB -0.35 BAHH BAH 20 96910.1 40 HOT 680PP 42 44 0.16 127 P5 WAR BAR -0.44 BAHH BAH 8 96910.1 40 HOT 680PP 43 45 0.45 102 P5 WAR BAR -0.33 BAH BAH 18 96910.1 40 HOT 680PP 45 45 0.15 99 P5 WAR BAH -0.12 BAH BAH 7 96910.1 40 HOT 680PP Total Tubes  : 8 Total Records: 8 Note: The qualified EPRI sizing technique used for depth estimates is identified in the Util 2 field and the depth estimate is in the "UTIL 1" column.

Turkey Point Unit 3 L-201 1-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 1 of 7 SG 3C Indication Listings Listing Description Page No.

Tubes Plugged Listing 2 Bobbin WEAR at AVB locations 20-100%TWD 4 Bobbin WEAR at AVB locations 1-19% TWD 4 WEAR (WAR) sized by +PointTM probe 1-100% (AVB) 6 WEAR (WAR) sized by +PointTM probe 1-100% (Broach/Baffle) 7

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 2 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C Tubes Plugged Listing 10/10 - TP3-25 TP3-25 ECT Results for Tubes Repaired by Plugging ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 3 82 NDD TEH TSH 22 HOT 680PP 4.71 35 2 NTE TSH +0.00 06H TEH 4 HOT 720UL 4.71 43 2 PID TSH +0.00 06H TEH HR 4 HOT 720UL PTP 06H TEH 4 HOT 720UL NDD 06H TEH 4 HOT 720UL NDD 06H TEC 21 COLD 700UL NDD 06H TEC 21 COLD 700UL 3 83 NDD 06H TEC 21 COLD 700UL NOD 06H TEC 21 COLD 700UL NDD 06H TEH 4 HOT 720UL 3.95 47 2 NTE TSH +0.00 06H TEH 4 HOT 720UL 3.64 56 2 PID TSH +0.00 06H TEH HR 4 HOT 720UL PTP 06H TEH 4 HOT 720UL NDD TEH TSH 22 HOT 680PP 3 85 NDD TEH TSH 22 HOT 680PP 4.69 43 2 NTE TSH +0.00 06H TEH 4 HOT 720UL 4.68 51 2 PID TSH +0.00 06H TEH HR 4 HOT 720UL PTP 06H TEH 4 HOT 720UL NDD 06H TEH 4 HOT 720UL NDD 06H TEC 21 COLD 700UL NDD 06H TEC 21 COLD 700UL 5 23 NDD TEH TEC 7 COLD 720UL 4.66 219 2 NTE TSH +0.02 TEH TEC 7 COLD 720UL 4.87 219 2 PID TSH +0.02 TEH TEC HR 7 COLD 720UL PTP TEH TEC 7 COLD 720UL NDD TEH TSH 22 HOT 680PP 21 61 4 CLP 04H -0.76 04H 04H 0.30 0.43 37 HOT 680PP 1.32 74 P5 WAR 04H -0.76 04H 04H 37 96910.1 37 HOT 680PP 1.46 70 2 PID 04H -0.76 04H 04H 37 HOT 680PP TBP 04C 04C 37 HOT 680PP 0 1 CLP 04H -0.76 04H 04H 0.30 0.33 29 HOT 680PP TBP 04H 04H 29 HOT 680PP RBS 04H 04H LAR 29 HOT 680PP NDD TSH TSH 16 HOT 680PP 0.53 84 Pl DSI 04H -0.55 TEH TEC 13 COLD 720UL 4.27 179 Pl DNG 06C +0.53 TEH TEC 13 COLD 720UL 3.51 177 Pl DNG 06C -0.58 TEH TEC 13 COLD 720UL 2.29 176 Pl DNG 05C +0.49 TEH TEC 13 COLD 720UL 29 77 3.45 185 Pl DNG 06H +10.73 TEH TEC 11 COLD 720UL 0.43 87 Pl DSI 03H -0.67 TEH TEC 11 COLD 720UL NDF 06H +10.71 06H AVI 35 HOT 6801P 0.88 82 P5 WAR 03H -0.81 03H 03H 31 96910.1 37 HOT 680PP 4 CLP 03H -0.81 03H 03H 0.24 0.31 37 HOT 680PP 0.88 82 P5 PID 03H -0.81 03H 03H 37 HOT 680PP PTP 03H 03H 37 HOT 680PP NOD TSH TSH 18 HOT 680PP

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 3 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C Tubes Plugged Listing (continued) 10/10 - TP3-25 TP3-25 ECT Results for Tubes Repaired by Plugging ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 30 45 16.11 183 P1 DNG 06C +0.49 TEH TEC 1 COLD 720UL 14.32 183 P1 DNG 06C -0.69 TEH TEC 1 COLD 720UL 8.43 182 P1 DNG 05C +0.43 TEH TEC 1 COLD 720UL 10.47 183 P1 DNG 05C -0.67 TEH TEC 1 COLD 720UL 3.41 180 P1 DNG 04C +0.38 TEH TEC 1 COLD 720UL 4.54 180 P1 DNG 04C -0.76 TEH TEC 1 COLD 720UL 0.65 106 P5 WAR AV3 +0.06 AV3 AV3 21 96910.1 33 HOT 6801P 0 1 CLP AV3 +0.06 AV3 AV3 0.31 0.26 33 HOT 6801P NDD TSH TSH 14 HOT 680PP PTP TEH TEC 1 COLD 720UL PRA AV3 AV3 39 HOT 6801P 0.25 34 P2 TWD 12 AV2 -0.20 TEH TEC 1 COLD 720UL 1.56 119 P2 TWD 37 AV3 +0.04 TEH TEC 1 COLD 720UL 1.56 119 P2 PID AV3 +0.22 TEH TEC HR 1 COLD 720UL 41 43 2.48 176 P1 DNG 06C +0.43 TEN TEC 2 COLD 720UL 2.34 176 P1 DNG 06C -0.72 TEH TEC 2 COLD 720UL 2.07 177 P1 DNG 05C +0.47 TEH TEC 2 COLD 720UL 4.18 222 2 NTE TSN +0.00 TEH TEC 2 COLD 720UL 4.79 219 2 PID TSH +0.00 TEH TEC NR 2 COLD 720UL PTP TEH TEC 2 COLD 720UL NDD TEH TSH 22 HOT 680PP Total Tubes  : 8 Total Records: 67 NOTE: Tubes with no tube expansion have "NTE" in the "IND" column. +PointTM depth estimates are in the "UTIL I" column. Bobbin depth estimates are in the "%TW" column.

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 4 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10- TP3-25 Bobbin WAR at AVB's 20-100%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 24 63 0.79 99 P2 TWD 25 AV3 -0.13 TEH TEC 13 COLD 720UL 25 62 0.62 58 P2 TWD 21 AV2 +0.00 TEH TEC 13 COLD 720UL 0.77 102 P2 TWD 25 AV3 +0.00 TEH TEC 13 COLD 720UL 26 58 0.87 77 P2 TWD 24 AV2 -0.02 TEH TEC 14 COLD 720UL 28 48 1.28 97 P2 TWD 32 AV2 +0.22 TEH TEC 13 COLD 720UL 30 31 0.62 76 P2 TWD 24 AVI -0.19 TEH TEC 3 COLD 720UL 0.73 122 P2 TWD 26 AV2 +0.11 TEH TEC 3 COLD 720UL 0.72 75 P2 TWD 26 AV3 +0.00 TEH TEC 3 COLD 720UL 30 45 1.56 119 P2 TWD 37 AV3 +0.04 TEH TEC 1 COLD 720UL 30 61 0.88 121 P2 TWD 27 AV2 +0.13 TEH TEC 11 COLD 720UL 33 43 0.92 61 P2 TWD 25 AV3 +0.00 TEH TEC 2 COLD 720UL 0.66 101 P2 TWD 20 AV2 +0.00 TEH TEC 2 COLD 720UL 34 31 0.86 89 P2 TWD 24 AV2 +0.11 TEH TEC 23 COLD 720UL 1.32 93 P2 TWD 31 AV3 -0.11 TEH TEC 23 COLD 720UL 34 41 0.95 99 P2 TWD 29 AVI -0.04 TEH TEC 1 COLD 720UL 1.17 83 P2 TWD 33 AV2 -0.38 TEH TEC 1 COLD 720UL 1.21 95 P2 TWD 33 AV3 -0.07 TEH TEC 1 COLD 720UL 1.15 106 P2 TWD 32 AV4 +0.00 TEH TEC 1 COLD 720UL 35 36 0.62 55 P2 TWD 20 AV2 +0.04 TEH TEC 2 COLD 720UL 35 49 0.74 55 P2 TWD 20 AV4 +0.00 TEH TEC 12 COLD 720UL 37 28 0.59 77 P2 TWD 23 AV4 +0.16 TEH TEC 3 COLD 720UL 38 65 0.78 102 P2 TWD 26 AV2 +0.00 TEH TEC 9 COLD 720UL 0.80 91 P2 TWD 26 AV4 +0.00 TEH TEC 9 COLD 720UL 38 71 0.75 121 P2 TWD 23 AV3 +0.07 TEH TEC 10 COLD 720UL 40 25 0.84 87 P2 TWD 24 AV3 +0.02 TEH TEC 4 COLD 720UL 40 55 0.63 63 P2 TWD 23 AV3 +0.00 TEH TEC 9 COLD 720UL Total Tubes  : 17 Total Records: 26 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10 - TP3-25 Bobbin WAR at AVB's 1-19%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 18 26 0.17 26 P2 TWO 7 AV2 +0.11 TEN TEC 4 COLD 720UL 20 37 0.32 70 P2 TWD 14 AV3 -0.33 TEH TEC 1 COLD 720UL 21 38 0.52 65 P2 TWD 17 AV2 +0.24 TEH TEC 2 COLD 720UL 0.36 98 P2 TWD 13 AV3 +0.02 TEH TEC 2 COLD 720UL 21 62 0.27 39 P2 TWD 10 AV3 -0.13 TEH TEC 14 COLD 720UL 0.34 61 P2 TWD 13 AV2 +0.13 TEH TEC 14 COLD 720UL 23 45 0.51 138 P2 TWD 17 AV3 +0.00 TEH TEC 23 COLD 720UL 24 11 0.28 120 P2 TWD 11 AV3 +0.00 TEH TEC 2 COLD 720UL 24 12 0.23 27 P2 TWD 11 AVI -0.04 TEH TEC 5 COLD 720UL 24 43 0.24 143 P2 TWD 12 AV2 -0.25 TEH TEC 1 COLD 720UL 24 57 0.42 45 P2 TWD 16 AV2 +0.00 TEH TEC 13 COLD 720UL 24 59 0.49 94 P2 TWD 18 AV2 +0.00 TEH TEC 13 COLD 720UL 0.42 34 P2 TWD 16 AV2 +0.00 TEH TEC 13 COLD 720UL 0.25 100 P2 TWD 11 AV3 +0.07 TEH TEC 13 COLD 720UL 0.28 102 P2 TWD 12 AV4 +0.02 TEH TEC 13 COLD 720UL 24 63 0.45 52 P2 TWD 17 AV2 +0.22 TEH TEC 13 COLD 720UL 26 49 0.25 101 P2 TWD 11 AV3 -0.02 TEH TEC 13 COLD 720UL

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 5 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10 - TP3-25 Bobbin WAR at AVB's 1-19%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 26 58 0.42 54 P2 TWD 15 AV3 -0.22 TEH TEC 14 COLD 720UL 0.54 81 P2 TWD 18 AVI +0.20 TEH TEC 14 COLD 720UL 28 12 0.26 90 P2 TWD 13 AVI +0.07 TEH TEC 5 COLD 720UL 28 48 0.29 132 P2 TWD 12 AVI +0.09 TEH TEC 13 COLD 720UL 0.28 148 P2 TWO 12 AV3 +0.00 TEH TEC 13 COLD 720UL 28 60 0.26 86 P2 TWD 12 AV2 +0.11 TEH TEC 11 COLD 720UL 29 14 0.24 49 P2 TWD 12 AV3 +0.00 TEH TEC 5 COLD 720UL 0.22 31 P2 TWO 11 AV2 -0.04 TEH TEC 5 COLD 720UL 30 18 0.44 129 P2 TWD 18 AVI -0.13 TEH TEC 5 COLD 720UL 0.25 43 P2 TWD 12 AV3 -0.09 TEH TEC 5 COLD 720UL 30 30 0.32 45 P2 TWD 12 AVI +0.11 TEH TEC 4 COLD 720UL 0.28 127 P2 TWD 11 AV2 +0.15 TEH TEC 4 COLD 720UL 0.29 150 P2 TWD 11 AV3 -0.02 TEH TEC 4 COLD 720UL 0.45 62 P2 TWD 15 AV4 -0.06 TEH TEC 4 COLD 720UL 30 45 0.25 34 P2 TWD 12 AV2 -0.20 TEH TEC 1 COLD 720UL 30 51 0.28 107 P2 TWO 12 AV2 +0.02 TEH TEC 11 COLD 720UL 30 60 0.20 36 P2 TWD 7 AV2 +0.00 TEH TEC 12 COLD 720UL 30 61 0.24 17 P2 TWD 11 AV4 +0.01 TEH TEC 11 COLD 720UL 31 15 0.42 91 P2 TWD 18 AVI +0.13 TEH TEC 5 COLD 720UL 33 28 0.22 156 P2 TWD 11 AV3 +0.09 TEH TEC 3 COLD 720UL 33 31 0.24 118 P2 TWD 9 AV2 +0.29 TEH TEC 4 COLD 720UL 0.22 37 P2 TWD 10 AV4 -0.20 TEH TEC 4 COLD 720UL 0.60 118 P2 TWD 19 AV3 -0.09 TEH TEC 4 COLD 720UL 33 32 0.51 127 P2 TWD 17 AV2 +0.19 TEH TEC 23 COLD 720UL 0.58 104 P2 TWD 19 AV3 +0.24 TEH TEC 23 COLD 720UL 0.31 55 P2 TWO 12 AV4 +0.04 TEH TEC 23 COLD 720UL 33 38 0.32 83 P2 TWD 12 AV3 +0.00 TEH TEC 2 COLD 720UL 33 45 0.24 104 P2 TWD 10 AV2 -0.11 TEH TEC 2 COLD 720UL 33 46 0.26 29 P2 TWO 10 AV3 +0.00 TEH TEC 2 COLD 720UL 33 55 0.41 95 P2 TWD 16 AV3 -0.07 TEH TEC 11 COLD 720UL 34 32 0.21 86 P2 TWD 8 AV3 -0.18 TEH TEC 4 COLD 720UL 34 38 0.30 86 P2 TWD 12 AV4 +0.00 TEH TEC 23 COLD 720UL 34 44 0.60 106 P2 TWD 19 AV3 +0.13 TEH TEC 2 COLD 720UL 0.44 35 P2 TWD 15 AV4 -0.04 TEH TEC 2 COLD 720UL 34 45 0.22 23 P2 TWD 11 AV2 -0.06 TEH TEC 1 COLD 720UL 34 52 0.28 140 P2 TWD 12 AV3 +0.04 TEH TEC 11 COLD 720UL 34 56 0.24 149 P2 TWO 11 AV3 -0.04 TEH TEC 11 COLD 720UL 35 35 0.53 63 P2 TWD 18 AV3 +0.11 TEH TEC 2 COLD 720UL 35 36 0.57 137 P2 TWD 19 AV3 +0.11 TEH TEC 2 COLD 720UL 35 49 0.29 29 P2 TWO 10 AV3 +0.02 TEH TEC 12 COLD 720UL 35 51 0.46 132 P2 TWD 14 AV2 +0.02 TEH TEC 12 COLD 720UL 35 52 0.43 115 P2 TWO 17 AV3 -0.02 TEH TEC 11 COLD 720UL 35 54 0.29 71 P2 TWD 13 AVI -0.02 TEH TEC 11 COLD 720UL 0.46 55 P2 TWD 18 AV2 -0.06 TEH TEC 11 COLD 720UL 35 57 0.26 33 P2 TWD 9 AV2 +0.09 TEH TEC 12 COLD 720UL 36 54 0.24 39 P2 TWD 10 AV2 +0.00 TEH TEC 23 COLD 720UL 36 56 0.23 40 P2 TWD 10 AV3 +0.11 TEH TEC 11 COLD 720UL 36 73 0.26 45 P2 TWD 11 AV3 +0.09 TEH TEC 10 COLD 720UL 37 26 0.29 129 P2 TWD 14 AV4 +0.00 TEH TEC 3 COLD 720UL 37 27 0.24 119 P2 TWD 12 AV3 +0.00 TEH TEC 3 COLD 720UL 38 25 0.30 45 P2 TWD 11 AV3 -0.09 TEH TEC 4 COLD 720UL 38 50 0.23 134 P2 TWO 10 AV2 +0.13 TEH TEC 10 COLD 720UL 38 59 0.22 107 P2 TWO 10 AV2 +0.07 TEH TEC 9 COLD 720UL 38 61 0.44 138 P2 TWD 18 AV2 +0.00 TEH TEC 9 COLD 720UL 38 63 0.47 41 P2 TWD 19 AV2 +0.00 TEH TEC 9 COLD 720UL 38 65 0.38 131 P2 TWD 16 AV3 +0.00 TEH TEC 9 COLD 720UL 38 66 0.33 78 P2 TWD 13 AV3 +0.16 TEH TEC 10 COLD 720UL 39 24 0.23 39 P2 TWD 10 AV3 +0.00 TEH TEC 4 COLD 720UL 39 28 0.21 30 P2 TWD 11 AV4 +0.11 TEH TEC 3 COLD 720UL 39 54 0.44 81 P2 TWD 18 AV3 +0.00 TEH TEC 9 COLD 720UL 0.32 104 P2 TWD 14 AV4 +0.02 TEH TEC TWR 9 COLD 720UL

0 Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 6 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10 - TP3-25 Bobbin WAR at AVB's 1-19%TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 39 55 0.37 46 P2 TWD 14 AV2 +0.11 TEH TEC TWR 10 COLD 720UL 40 25 0.51 113 P2 TWD 17 AV2 +0.07 TEH TEC 4 COLD 720UL 40 28 0.27 43 P2 TWD 10 AV4 +0,07 TEH TEC 4 COLD 720UL 40 44 0.32 73 P2 TWD 15 AV3 +0.02 TEH TEC 1 COLD 720UL 0.28 61 P2 TWD 13 AV4 +0.02 TEH TEC 1 COLD 720UL 40 46 0.26 56 P2 TWD 12 AV4 +0.07 TEH TEC 1 COLD 720UL 40 55 0.39 56 P2 TWD 16 AV4 +0.00 TEH TEC 9 COLD 720UL 40 57 0.27 38 P2 TWD 12 AV3 +0.00 TEH TEC 9 COLD 720UL 0.25 28 P2 TWD 12 AV4 -0.22 TEH TEC 9 COLD 720UL 42 31 0.51 41 P2 TWD 17 AV3 +0.00 TEH TEC 4 COLD 720UL 42 43 0.34 32 P2 TWD 15 AVI -0.02 TEH TEC 1 COLD 720UL 43 33 0.43 45 P2 TWD 15 AV3 -0.13 TEH TEC 4 COLD 720UL 43 35 0.32 43 P2 TWD 12 AV3 +0.00 TEH TEC 2 COLD 720UL 43 60 0.18 166 P2 TWD 8 AV2 +0.13 TEH TEC 10 COLD 720UL 44 36 0.28 39 P2 TWD 11 AV3 +0.13 TEH TEC 2 COLD 720UL 44 37 0.31 59 P2 TWD 12 AV3 +0.09 TEH TEC 2 COLD 720UL 45 52 0.21 167 P2 TWD 9 AV4 +0.25 TEH TEC 10 COLD 720UL Total Tubes  : 74 Total Records: 95 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10 - TP3-25

+PointTM WAR at AVBs ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 30 45 0.65 106 P5 WAR AV3 +0.06 AV3 AV3 21 96910.1 33 HOT 6801P 44 36 0.20 106 P5 WAR AV3 -0.03 AV3 AV4 14 96910.1 31 HOT 6801P Total Tubes  : 2 Total Records: 2 Note: The qualified EPRI sizing technique used for depth estimates is identified in the Util 2 field and the depth is in the "UTIL I" field.

Turkey Point Unit 3 L-2011-109 Steam Generator Tube Inspection Report Attachment 4 SG 3C, Page 7 of 7 Turkey Point Unit 3 (TP3-25)

SG 3C 10/10 - TP3-25

+PointTM WAR at Supports (Broach support and Baffle Plate)

ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 5 85 0.08 112 P5 WAR 03H -0.70 03H 03H 4 96910.1 37 HOT 680PP 15 82 0.33 79 P5 WAR 03H -0.85 03H 03H 16 96910.1 37 HOT 680PP 20 61 0.15 107 P5 WAR 04H -0.64 04H 04H 8 96910.1 37 HOT 680PP 21 61 1.32 74 P5 WAR 04H -0.76 04H 04H 37 96910.1 37 HOT 680PP 23 71 0.20 76 P5 WAR 06H -0.56 06H 06H 10 96910.1 37 HOT 680PP 27 21 0.23 101 P5 WAR 02H -0.90 02H 02H 12 96910.1 37 HOT 680PP 29 73 0.24 77 P5 WAR 02H -0.86 02H 02H 12 96910.1 37 HOT 680PP 29 77 0.88 82 PS WAR 03H -0.81 03H 03H 31 96910.1 37 HOT 680PP 32 19 0.12 119 P5 WAR 03H -0.54 03H 03H 6 96910.1 37 HOT 680PP 35 68 0.12 76 P5 WAR 03H -0.67 03H 03H 6 96910.1 37 HOT 680PP 36 68 0.18 103 P5 WAR 03H -0.69 03H 03H 10 96910.1 37 HOT 680PP Total Tubes :1ii Total Records: 11 Note: The qualified EPRI sizing technique used for depth estimates is identified in the Util 2 field and the depth is in the "UTIL 1" field.

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