Text

Steam Generator Tube Inspection Report for Refueling Outage 17
	ML14318A211
Person / Time
Site:	Braidwood ; (NPF-077)
Issue date:	11/14/2014
From:	Kanavos M; Exelon Generation Co
To:	; Document Control Desk, Office of Nuclear Reactor Regulation
References
	BW140098
	Download: ML14318A211 (39)
	v • d • e

November 14, 2014 BW140098 ti U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Unit 2 Facility Operating License No. NPF-77 NRC Docket No. STN 50-457 Exelon Generation Company, Braidwood Station 35100 South Route 53, Suite 84 Braceville, 60407-9619

Subject:

Braidwood Station, Unit 2 Steam Generator Tube Inspection Report for Refueling Outage 17 In accordance with Technical Specification 5.6.9, "Steam Generator (SG) Tube Inspection Report,"

Exelon Generation Company, LLC is reporting the results of the SG inspections that were completed during Braidwood Station, Unit 2 Refueling Outage 17 (A2R17).

Please direct any questions you may have regarding this submittal to Mr. Phil Raush, Regulatory Assurance Manager, at (815) 417-2800.

z;z,;t:_

Mark E. Kanavos Site Vice President Braidwood Station

Attachment:

Braidwood Station, Unit 2 Steam Generator Tube Inspection Report Refueling Outage 17 cc:

Regional Administrator, NRC Region Ill NRC Senior Resident Inspector-Braidwood Station Illinois Emergency Management Agency - Division of Nuclear Safety

EXELON GENERATION COMPANY, LLC BRAIDWOOD STATION, UNIT 2 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: October 17, 1988 STEAM GENERATOR TUBE INSPECTION REPORT REFUELING OUTAGE 17 (A2R17)

May 2014 Mailing Address 4300 Winfield Road Warrenville, IL 60555

Introduction Braidwood Station, Unit 2, operates with four Westinghouse Model D-5 recirculating steam generators (SGs) in the four loop pressurized water reactor system. Each SG contains 4570 thermally treated Alloy-600 U-tubes that have a nominal outside diameter of 0.750 inches and a nominal thickness of 0.043 inches. The tubes are hydraulically expanded into the full depth of the tubesheet. The tubes are supported by stainless steel quatrefoil support plates (TSPs) and chrome plated Alloy-600 anti-vibration bars (AVBs). The tube support plates within the pre-heater region are 0.75" stainless steel drilled hole baffle plates. The lowest tube support plate (TSP 01) on the hot and cold leg sides is a flow distribution baffle that is also stainless steel of 0.75" thick with enlarged drilled tube holes to distribute the feed flow. See attached Figure 1 for a diagram of the D-5 SG TSP and AVB configuration.

Technical Specification (TS) 5.5.9.d provides the requirements for SG inspection frequencies and requires periodic SG tube inspections to be performed. TS 5.5.9 requires that 100% of the Unit 2 tubes are to be inspected at sequential periods of 120, 96, and thereafter 72 effective full power months (EFPM). The first sequential period shall be considered to begin after the first inservice inspection of the SGs.

At the start of A2R17, the Braidwood Unit 2 SGs had accumulated a total of 22.72 EFPY, and 21.54 EFPY since the first inservice inspection (ISi) during A2R01 (subtracting the first operating cycle of 1.18 EFPY from the cumulative EFPY of 22.72 EFPY since commercial operation). The current 72 EFPM period started with A2R15 and will end with A2R18; A2R17 was at 42.47 EFPM within the first 72 EFPM period.

The A2R17 SG inspections were performed consistent with the Electric Power Research Institute (EPRI) "PWR Steam Generator Examination Guidelines: Revision 7," applicable interim guidance and Nuclear Energy Institute (NEI) 97-06, "Steam Generator Program Guidelines" Revision 3. The field inspection activities were conducted from May 7, 2014 through May 14, 2014 by the Westinghouse Electric Company LLC.

Steam Generator Inspection Scope (TS 5.6.9.a)

Braidwood Unit 2 Refueling Outage 17 (A2R17) was the last inspection outage of the first 72 EFPM period, and the last refuel outage within the current 72 EFPM period will be A2R18. The following inspections were performed during A2R17 to ensure that 100% of the tubes were inspected during the period as required by TS 5.5.9.d.3.

Eddy Current Scope:

All in-service tubes in all four SGs were inspected full length with a bobbin coil probe, with the exception of the Row 1 and Row 2 U-Bend region, which were inspected as part of the 50% +Point' probe inspections.

50% of the Row 1 and Row 2 U-Bends in all four SGs were inspected from the top tube support plate (TSP) on the hot leg side to the top TSP on the cold leg side with a +Point' probe. In addition to the 50% Row 1 and Row 2 U-Bends inspection, all thirty nine (39) tubes identified with manufacturing artifacts were inspected with a +Point' probe.

Page 2 of 38

50% of the hot leg bulges 2:: 18 volts and over expansions 2:: 1.5 mils within the top 15 inches of the hot leg tubesheet in all four SGs were inspected with a +Point' probe.

50% of the tubes in all four SGs were inspected in the hot leg tubesheet region from 4 inches above the top of tubesheet (TTS) to 15 inches below the TTS, which encompassed the hot leg TTS expansion transition region

(+/-3 inches), with a X-Probe. This fully encompasses the H* region of TTS-14.01inches.

Three tubes deep around the entire periphery, including no tube lane and T-slot, in all four SGs were inspected with a X-Probe. This included the hot leg tubesheet region from 4 inches above the TTS to 15 inches below the TTS, which encompassed the hot leg TTS expansion transition region

(+/-3 inches).

All 68 in-service tubes identified in all four SGs as having potentially increased residual stress (-2 sigma tubes) were inspected with a X-Probe in the hot leg tubesheet region from 4 inches above the TTS to 15 inches below the TTS, as well as at all quatrefoil and baffle TSP intersections. Additionally, all hot leg dents (;::2.0V) I dings (;::5.0V) and non-quantifiable indications that were detected by the bobbin coil examination in these tubes were inspected with a +Point' probe.

50% of the pre-heater baffle plate hydraulic expansion transitions(+/- 3 inches) in all SGs at baffle plates 02C and 03C were inspected with a X-Probe. Additionally, the pre-heater baffle plate hydraulic expansions at baffle plate 02C in the peripheral tubes near the flow blocking region (also called corner tubes) of the pre-heater in all SGs were inspected with a X-Probe. This location has historically been known as a location in which secondary side foreign objects (FO) may collect due to the flow conditions in the region.

Dent/Ding Special Interest Scope:

For the 2A, 28, and 2D SGs the following were included in the

+Point' probe inspections: 50% Hot Leg (HL) dents ;::2.ov, 100%

dings 2!5.0V at all locations (HL, Cold Leg (CL), and U-bend), 100%

dents ;::5_ov CL, 100% dents ;::2.ov at AVB 1 and AVB 2, 50% dents

2.0V at AVB 3, AVB 4, and the 11tti TSP on the CL (11C).

For the 2C SG the following were included in the +Point' probe inspections: 100% HL dents ;::2.ov, 100% dings ;::5.0V at all locations (HL, CL, and U-bend), 100% dents ;::5.0V CL, 100% dents

2.ov at AVB 1 and AVB 2, 100% dents ;

:2.ov at AVB 3, AVB 4, and the 11 1h TSP CL (11C).

All in-service tubes containing historical foreign object wear in all four SGs were inspected with a +Point' probe.

Page 3 of 38

Diagnostic examinations were conducted on non-quantifiable indications that were detected by the bobbin coil examination. Diagnostic examinations were also conducted on tubes in the vicinity of potential foreign objects in order to determine the extent of tubes potentially affected by the objects. These examinations were performed with a

+Point'.

Monitored all in-service tubes for axial tube displacement (slippage) in both the hot and cold leg tubesheet region.

Other SG Inspections Visual Inspection of Installed Tube Plugs -All previously installed tube plugs were visually inspected for signs of degradation and leakage. In addition, all plugs installed during A2R17 were also visually inspected, and the installation parameters were reviewed for acceptable installation.

No anomalies were found.

SG Channel Head Bowl Visual Inspections-Each SG primary channel head was visually examined in accordance with the recommendations of Westinghouse NSAL 12-01 and NRC IN 2013-20 for evidence of breaches in the cladding or divider to channel head weld and for evidence of wastage of the carbon steel channel head. No evidence of cladding or weld breaches or evidence of channel head wastage was identified.

Secondary Side Visual Inspections -SG secondary side TTS sludge lancing was not performed during A2R17. TTS foreign object search and retrieval (FOSAR) was a planned contingency if potential FOs were detected by eddy current. This contingency was executed in the 20 SG for two adjacent possible loose part (PLP) indications at the hot leg TTS region in tubes R3-C1 and R4-C1. FOSAR did not confirm a FO, but showed an area of sludge (iron oxide) deposits. The 100% bobbin full length inspection, the 50% TTS X-Probe inspection, and the X-Probe periphery tube inspection was adequate to address the potential for secondary side FO wear. Additionally, a full FOSAR of the pre-heater baffle plate TSP 02C was performed in the 20 SG preheater high flow regions on the pre-heater tube support baffle plate TSP 02C, which is the first support that experiences incoming main feedwater flow. The high flow regions included the preheater waterbox rib and cap plate region.

No evidence of degradation or anomalies was reported in the 20 SG preheater.

Visual inspection was performed of the 2C SG upper bundle. The upper bundle region was inspected through the 2.5" inspection ports located at the 9th and 11th TSPs. The inspections included the tube lanes and four in-bundle columns at each TSP. The purpose of these inspections was to assess the general condition of the upper tube bundle, which included quatrefoil blockage. The quatrefoils on the cold leg were free of blockage with trace amounts of scale. The quatrefoils on the hot leg side however contained minor accumulations of deposits within the flow hole and evidence of partial flow hole blockage around the bottom of the quatrefoil.

Page 4 of 38

It was identified that the blockage appears to affect more quatrefoil flow holes as compared to the previous outage. No other anomalous structural conditions, foreign objects, or erosion was observed in the visual inspections of the upper bundle.

Visual inspections supplemented, as applicable, by ultrasonic thickness measurements of the 2A and 2B SG primary and secondary side moisture separator regions were performed during the A2R17 outage. The results show wear is present and progressing slowly. The minimum component thickness measured by ultrasonic measurement techniques was 0.099 inches compared to the nominal component thickness of 0.25 inches. No repairs were required, and it was concluded that a 2-cycle inspection interval was justified with no adverse consequences for the moisture separators in all 4 SGs.

Degradation Mechanisms Found (TS 5.6.9.b)

The Table below provides a summary of all the degradation, by mechanism, identified during the A2R17 inspections (all mechanisms were present during previous inspections).

SUMMARY

OF A2R17 DEGRADATION INDICATIONS BY MECHANISM De~radation Mechanism SG2A SG 28 SG2C SG2D AVB Wear 406 115 294 183 TSP Wear & Pre-heater 1

3 0

1 Drilled Baffle Plate Wear New Secondary Side FO 1

0 0

2 Wear Historical Secondary Side FO 4

4 0

2 Wear Remaininq In Service Nondestructive Examination Techniques Utilized for Each Degradation Mechanism Found During A2R17 (TS 5.6.9.c)

Total 998 5

3 10 All SG eddy current examination techniques used (see Table below) were qualified in accordance with Appendix H or Appendix I of the EPRI PWR SG Examination Guidelines Revision 7. Each examination technique was evaluated to be applicable to the tubing and the degradation mechanisms found in the Braidwood Station Unit 2 SGs during A2R17.

Page 5 of 38

EPRI APPENDIX H & APPENDIX I TECHNIQUES EPRI ETSS Technique Probe Degradation Applicability1 ETSS Rev.

21998.1 4

+Point' Detection/Sizing Volumetric Wear at Foreign Object Wear Locations and Freespan Flaws (Volumetric Indications)

Detection/Sizing Volumetric Pitting at Freespan 27091.22'3 1

Bobbin Detection Volumetric Wear at Foreign Object Wear Locations and Freespan Flaws (Volumetric Indications)

Detection/Sizing Volumetric Wear at AVBs and Drilled 96004.3 13 Bobbin TSPs Detection Volumetric Wear at Broached TSPs 96043.2 1

Bobbin Sizing Volumetric Wear (Single Land) at Broached TSPs 96910.1 3,4 10

+Point' Detection/Sizing Volumetric Wear (Tapered) at TSPs, Foreign Object Wear Locations, and Freespan Flaws (Volumetric Indications)

Notes: 1.

TSP - Tube Support Plate AVB-Anti-Vibration Bar PLP - Possible Loose Part

2.

Extended inspection technique qualified for A690 tubing to A600 tubing because the relative current density is +/-1 0% or smaller.

3.

Extended technique for use with a PLP present within a structure or freespan because the mix suppresses structures and/or loose part signals.

4.

Extended inspection technique to detect/size freespan foreign object wear because signal characteristics resemble tube wear from a broached TSP.

Location, Orientation (if linear), and Measured Sizes of Service Induced Indications (TS 5.6.9.d)

Anti-Vibration Bar {AVB) Wear-Tube degradation was found during bobbin coil examination in the U-Bend region due to fretting of the A VB on the outer surf ace of the tube. A total of 998 indications were reported. The EPRI Appendix H bobbin coil technique 96004.3, Revision 13 was used for depth sizing of all AVB wear. The largest indication left inservice during A2R17 was measured at 39% through-wall (TW). Three tubes had indications of AVB wear exceeding 40% TW plugging limit, and the three tubes were removed from service by mechanical tube plugging; one tube had two indications ~40% TW. The Table below provides a summary of AVB wear degradation. Refer to Attachment A for detailed locations and sizing for all AVB wear indications.

A2R17 AVB Wear Summary SG2A SG2B SG2C SG2D

of Ind.

of Ind.

of Ind.

of Ind.

10-39% TW 1

406 112 293 183

>= 40% TW 0

3 1

0 TOTAL 406 115 294 183 Page 6 of 38

Note: 1) Reporting criteria is <::15% TW for AVB; however, historical indications previously reported were re-sized during A2R17 and some were sized smaller (i.e. 10% TW to <15% TW).

Mechanical Wear at Tube Support Plates <TSPs) - Identified tube degradation attributed to wear in the pre-heater TSPs, which are drilled support baffle plates.

Additionally identified tube degradation attributed to wear at broached quatrefoil support plates. Wear was found in two tubes at broached quatrefoil TSPs, defined as single land wear in the Table below. The depth of the TSP wear ranged from 2%

TW to 26% TW. The depth was measured by either EPRI Appendix H qualified bobbin coil technique 96004.3, Revision 13 if the wear was at a drilled hole support or 96043.2, Revision 1 if the wear was at a quatrefoil single land location. There was no tapered wear identified during A2R17. The Table below provides a summary of the tubes that contain indications of pre-heater or quatrefoil TSP wear as identified during A2R17.

A2R17 TSP Wear Summary Wear NOE SG Tube Location Location Depth2 (o/oTW) 2B 47-39 03C Pre-Heater 2

Drilled Hole 2B 47-41 03C Pre-Heater 5

Drilled Hole 2B 49-49 05C Pre-Heater 3

Drilled Hole 2D 49-53 07C Broached 18 Single Land Broached 2A 22-98 10C Single Land 26 (Atypical Wear) 1 Notes: 1) R22-C98 in SG 2A exhibited atypical wear indicative of being caused by an asperity or burr on the surface of the TSP. The wear was a small volumetric indication in the center of the TSP location. The flaw was present in prior outages with little to no change.

2) Reporting criteria is 2:6% TW for preheater drilled hole wear; however, historical indications previously reported were re-sized during A2R17 and some were sized smaller (i.e.

<6%TW).

Foreign Object Wear - EPRI Appendix H +Point' coil sizing technique 21998.1, Revision 4 was used to size indications of secondary side FO wear identified during A2R17. A total of 13 indications of secondary side FO wear were identified in 12 tubes. The indications ranged from 11 % TW to 33% TW. Ten indications had been identified in previous outages and were allowed to remain in service based on being below the 40% TW plugging limit and showing no significant change in eddy current signal response outside of typical eddy current repeatability uncertainty. All FOs associated with the historical wear flaws were removed in a prior outage. Inspection Page 7 of 38

SG 2A 2A 2A 2A 28 28 28 28 20 20 2A 20 20 of these locations during A2R17 confirmed that these wear indications had not grown since originally identified, therefore the tubes remain in service.

One indication of FO wear in tube SG 2A R15-C47 was newly detected during A2R17 with no FO present. Review of historical eddy current data indicated that there had not been any change to the bobbin coil signal in the prior outage. Since there was no FO present and the indication did not change from the prior outage, the tube was left in service. Two FO wear indications in adjacent tubes in the 20 SG at TSP 08C in tubes R13-C92 and R14-C92 were also newly detected during A2R17 and were associated with a PLP in an inaccessible region of the SG. The FO wear in tube R13-C92 also appears to have been present in prior outages with little change in the bobbin coil data since 2009, based on reanalysis. The two tubes were preventively plugged and stabilized due to the presence of tube wear and a PLP signal. Additionally, an adjacent tube R13-C91 in the 20 SG was also plugged and stabilized due to the presence of a PLP signal with no wear.

The Table below provides a summary of the indications of secondary side foreign object wear as identified during A2R17.

A2R17 F ore1Qn Ob' tW S

11ec ear ummarv NOE Row Col Location Depth Comment

(%TW) 30 53 01H

+0.45 11 Historical - No Chanqe - Object No Lonqer Present 31 52 01H

+0.51 31 Historical - No Change - Object No Longer Present 32 53 01H

+0.41 16 Historical - No Change - Object No Longer Present 42 22 02C

+0.72 15 Historical - No Change - Object No Longer Present 49 51 TSC

+0.67 22 Historical - No Change - Object No Longer Present 49 52 TSC

+0.39 24 Historical - No Change - Object No Longer Present 49 52 TSC

+0.96 33 Historical - No Change - Object No Longer Present 49 53 TSC

+0.50 14 Historical - No Change - Object No Longer Present 31 48 01H

+0.33 22 Historical - No Change - Object No Longer Present 36 61 TSH

+0.04 17 Historical - No Change - Object No Longer Present 15 47 07H

-0.60 20 New in A2R17-Appears to have been present in a prior outaqe with no chanqe-no FO detected 13 92 08C

+0.59 33 Location Not accessible - Tube Pluaaed/Stabilized 14 92 08C

+0.65 21 Location Not accessible - Tube Pluaaed/Stabilized All newly identified indications of secondary side FO wear received additional +Point' inspection of the surroundin~ tubes to make certain that the wear region was adequately bounded. Additional +Point M inspection was performed on tubes surrounding historical secondary side FOs that could not be confirmed in its originally identified location to ensure that no wear occurred due to the migration of the object. Furthermore, +Point' inspections were performed on tubes surrounding secondary side FOs to ensure that no wear resulted from the object. As shown in the Table above, tubes that contained indications of secondary side FO wear in regions that were not accessible for visual inspection were conservatively stabilized through the region of wear and plugged regardless of the flaw size.

Page 8 of 38

Plugging Summary (TS 5.6.9.e and TS 5.6.9.f)

As a result of the A2R17 SG inspections, performed in accordance with TS 5.5.9.d, the modes of tube degradation found were Anti-Vibration Bar (AVB) wear, tube support plate

{TSP) wear, and secondary side foreign object (FO) wear. A total of eight (8) tubes were removed from service by mechanical tube plugging. The eight (8) tubes removed from service are as follows:

Three (3) tubes were plugged due to having AVB wear exceeding 40% TW Technical Specification 5.5.9.c plugging criteria.

Two (2) tubes were preventatively plugged due to large magnetic permeability indications resulting in a high noise portion of the tube and a potential for masking flaws due a low flaw signal to noise ratio.

Two (2) tubes were preventatively plugged and stabilized due to foreign object wear in the presence of a foreign object.

One (1) tube was preventatively plugged and stabilized due to the presence of a foreign object (adjacent to tubes above).

A2R17 TUBE PLUGGING BY DEGRADATION MECHANISM (TS 5.6.9.E)

Degradation Mechanism SG2A SG2B SG2C SG2D Total AVB Wear 0

2 1

0 3

TSP/Pre-heater Wear 0

0 0

Axial ODSCC 0

0 0

FO Wear 1

0 0

0 3

3 Preventative~

0 1

1 0

2 Total Pluqqed during A2R17 0

3 2

3 8

Notes: 1) The 3 FO wear tubes were preventatively plugged due to volumetric wear identified on two tubes; one tube contained a Possible Loose Part (PLP) indication and one tube was without a PLP indication, and a third tube only contained a PLP indication and no associated volumetric wear was found. These 3 tubes were adjacent to one another thus categorized collectively as foreign object wear.

1) Tubes were preventatively plugged due to large Permeability Variation Noise (PVN) indications.

Tube plugging was conducted in accordance with ASME Section XI, 2001 Edition through 2003 Addenda. All tube plugging was performed by Westinghouse using an Alloy 690 mechanical tube plugging process in accordance with ASME Section XI IWA-4713, "Heat Exchanger Tube Plugging by Expansion." All repairs were performed in accordance with Westinghouse approved procedures. There are no approved tube repair methods for the Unit 2 SGs. No tube sleeving was performed.

TUBE PLUGGING TO DATE (NUMBER AND PERCENTAGE PER SG) (TS 5.6.9.F)

SG2A SG2B SG2C SG2D Total Total Pluqqed durinq A2R17 0

3 2

3 8

Total Stabilized during A2R17 1

0 0

0 3

3 Total Pluaaed through A2R17 100 66 72 40 278 Total Percent Plu~ged through A2R17 *3 2.19%

1.44%

1.58%

0.88%

1.52%

Notes: 1)

Tubes that were stabilized were also plugged.

2)

Plugging percent is based on 4570 per SG for all 4 SGs.

3)

Plugging limit is 5% in any one SG.

Page 9 of 38

Results of Condition Monitoring (TS 5.6.9.g)

A condition monitoring assessment was performed for each inservice degradation mechanism found during the A2R17 SG inspection. The condition monitoring assessment was performed in accordance with TS 5.5.9.a and NEI 97-06 Revision 3 using the EPRI Steam Generator Integrity Assessment Guidelines, Revision 3. For each identified degradation mechanism, the as-found condition was compared to the appropriate performance criteria for tube structural integrity, accident induced leakage, and operational leakage as defined in TS 5.5.9.b. For each degradation mechanism a tube structural limit was determined to ensure that SG tube integrity would be maintained over the full range of normal operating conditions, all anticipated transients in the design specifications, and design basis accidents. This includes retaining a safety factor of 3.0 against burst under normal steady state full power operation primary to secondary pressure differential and a safety factor of 1.4 against burst under the limiting design basis accident pressure differential. The structural limits for wear related degradation were performed in accordance with the EPRI Steam Generator Integrity Assessment Guidelines and the EPRI Steam Generator Degradation Specific Management Flaw Handbook, Revision 1 (Flaw Handbook).

The as-found condition of each degradation mechanism found during the A2R17 outage was shown to meet the appropriate limiting structural integrity performance parameter with a probability of 0.95 at 50% confidence, including consideration of relevant uncertainties thus satisfying the condition monitoring requirements. The NOE measured flaw depths are compared to the structural integrity condition monitoring (CM) limits, which account for tube material strength, burst relation and NOE measurement uncertainties with a 0.95 probability at 50% confidence. Therefore, the NOE measured flaw sizes are directly compared to the CM limit. No indications met the requirements for proof or leakage testing; therefore, no In Situ Pressure tests were performed during A2R17.

No tube pulls were performed during A2R17.

The sections below provide a summary of the condition monitoring assessment for each degradation mechanism found during A2R17.

AVB Wear-The largest AVB wear indication found during the A2R17 inspection was 44% TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision 13. This is below the AVB wear structural limit of 73.66% TW, and it is less than the AVB wear CM limit of 64.96% TW.

The tube with this indication was plugged in accordance with TS 5.5.9.c SG tube plugging criteria.

Pre-Heater Baffle/TSP Wear - The largest pre-heater baffle plate drilled hole wear indication found during the A2R17 inspection was 5% TW as measured by the EPRI Appendix H qualified technique 96004.3, Revision 13. This is below the baffle plate wear (0.75-inch axially thinning) structural limit of 70.05% TW, and it is less than the baffle plate wear (0. 75-inch axially thinning) CM limit of 61.46% TW.

Page 10 of 38

The largest tube support plate (TSP) at a single land quatrefoil wear indication found during the A2R17 inspection was 26% TW as measured by the EPRI Appendix H qualified technique 96043.2, Revision 1. This indication was not characteristic of typical wear at TSP quatrefoil land locations. The likely cause of the indication is a small asperity or burr within the land contact that caused a small volumetric indication. It was conservative to assume the atypical wear indication to be uniformly deep (26% TW) for the entire length of the 1.125 inch quatrefoil TSP. This indication is below the 1.125-inch quatrefoil TSP single land wear structural limit of 67.65% TW, and it is less than the 1.125-inch quatrefoil TSP single land wear CM limit of 58.71% TW.

Foreign Object Wear - The largest foreign object wear indication found during the A2R17 inspection was 33% TW with axial length of 0.19 inches as measured by the EPRI Appendix H qualified technique 21998.1, Revision 4. This is below the foreign object wear (0.5-inches axial thinning) structural limit of 73.66% TW, and it is less than the foreign object wear (0.5-inches axial thinning) CM limit of 54.00% TW.

Primary to Secondary Leakage Assessment (TS 5.6.9.h and TS 5.6.9.i)

Braidwood TS 5.6.9.h reporting requirement states:

"For Unit 2, the operational primary to secondary leakage rate observed (greater than three gallons per day) in each steam generator (if it is not practical to assign the leakage to an individual steam generator, 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,"

Braidwood Station, Unit 2 did not observe any operational SG primary to secondary leakage over the preceding cycle. This is based on chemistry sampling taken from the Steam Jet Air Ejector and liquid SG blowdown sample locations.

Braidwood TS 5.6.9.i reporting requirement states:

"For Unit 2, the calculated accident induced leakage rate from the portion of the tubes below 14.01 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 accident is less than 3.11 times the maximum operational primary to secondary leakage rate, the report should describe how it was determined,"

Regarding Condition Monitoring requirements, since Braidwood Station, Unit 2 did not observe any SG primary to secondary operational leakage over the preceding cycle, the calculated accident leakage rate from flaws below 14.01 inches from the TIS is not quantifiable.

Page 11 of 38

Results of Monitoring for Tube Axial Displacement (Slippage) (TS 5.6.9.j)

All in-service tubes were monitored for tube axial displacement (slippage) in both the hot and cold leg tubesheet region in accordance with industry developed guidance. This was performed to ensure tubes had not severed within the tubesheet in regions of the tubesheet that were not required to be inspected with +Point'. The absence of tube sever indications (TSI) from the entirety of the collected bobbin coil inspection data confirms no tubes had tube slippage.

Page 12 of 38

Figure 1 Westinghouse Model D-5 TSP and AVB Configuration AV2 AV3 Anti-vibration bars 11H 11C 43" 43" 10H 10C 43" 43" 09H 09C 43" 43" 08H oac 43" 43" 07H 07C 18" 36" 06C 05H 05C 04C Feedwater 03C Inlet 03H 02C 01H 01C TSH TSC TEH TEC Nozzle Note: AVB bars are denoted as AV in the figure Page 13 of 38

Attachment A: AVB Wear Indication Tables Page 14 of 38

SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R17 COE 20140501 05/14/2014 08:31:50

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LI

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

26 8

2.38 0

PCT 28 P2 AVl

.00 TEC TEH

.610 NBAZC 29 HI 26 8

1.00 0

PCT 17 P2 AV2

.00 TEC TEH

.610 NBAZC 29 HI 26 8

1.30 0

PCT 20 P2 AV4

.00 TEC TEH

.610 NBAZC 29 HI 26 30 30 29 28 30 30 31 33 31 31 34 34 34 35 36 36 36 36 38 38 38 38 39 39 39 39 39 39 39 39 39 39 30 38 38 38 40 40 40 40 41 41 40 40 40 40 10 11 11 12 13 13 13 13 13 14 14 14 14 14 14 16 18 18 19 20 20 20 20 20 20 20 20 21 21 21 21 22 22 24 24 24 24 24

24.

24 24 24 24 25 25 25 25

.61

.70

.86 1.16

.88 1.39

.97

.84 1.54

.72

.68

.89 1.39 1.33

.64 2.62 1.30

.96

.69 1.15 2.45 1.82 2.46 2.44 1.43 3.47 1.57

.94 2.53 1.35

.90 1.10

1. 74

.98

.86 1.58 1.65

.91 3.48

.78

.89 1.94 1.87 1.43 1.89 2.65

.59 0

PCT 0

PCT 37 PCT 21 PCT 25 PCT 0

PCT 0

PCT 12 12 14 19 14 19 15 14 21 13 13 16 21 20 12 29 19 16 13 18 28 24 28 28 21 34 22 16 29 20 16 17 23 P2 AV2 P2 AVl P2 AV3 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 16 P2 AV4 15 P2 AVl 22 P2 AV2 22 P2 AV3 15 P2 AVl 34 P2 AV2 14 P2 AV3 15 P2 AV4 25 P2 AV2 24 P2 AV3 21 P2 AVl 25 P2 AV2 30 P2 AV3 12 P2 AV4

-.14

.00

.10

.00

.24

-.07

.00

.13

.20

-.27

-.08

.00

.20

.17

.10

.05

.24

-.05

.17

-.05

-.18

-.02

-.05

.00

-.03 TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH TEC TEH TEC TEH

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29 HI I

27 HI 27 HI I

29 HI I

27 HI I

27 HI 27 HI I

27 HI I

29 HI 29 HI I

29 HI 29 HI 29 HI I

23 HI I

23 HI 23 HI I

25 HI I

23 HI 23 HI 23 HI 23 HI I

25 HI 25 HI 25 HI 25 HI I

23 H

23 H 23 H

23 H

25 H 25 HI 25 HI 25 HI

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LI

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INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LI

+-----------+----+----+-----*--*+----+----+----+----+----+---------+---------+----+----+------+------+------+*-+

36 26 37 26 38 26 38 26 38 26 40 26 40 26 42 26 42 26 38 27 38 27 30 28 38 28 38 28 42 28 42 28 42 28 40 29 40 29 47 29 47 29 36 30 36 30 36 30 38 30 38 30 41 30 42 30 42 30 47 30 47 30 38 31 38 31 38 31 40 31 40 31 40 31 40 31 38 33 38 33 40 33 46 33 38 34 40 34 47 34 47 34 29 35

.93

.90

.70

.99 2.80

.81 3.12

.79 1.51

.73 1.15

.77

.69 1.35

.87 1.01

.71 2.17 1.83 2.08 1.69 1.42

.76 1.05 1.41 2.02

.93

.80

.87 1.15

.64

1. 72 2.21

.78

.92 1.51 2.09 1.00

.95 1.13

.82

.97

.66 1.12

.64

.84 1.08 0

PCT 0

PCT 15 P2 AV2 15 P2 AV3 12 P2 AVl 16 P2 AV2 30 P2 AV3 14 P2 AV2 32 P2 AV3 14 P2 AV2 21 P2 AV3 14 P2 AV2 19 P2 AV3 13 P2 AV3 12 P2 AV2 20 P2 AV3 15 P2 AV2 16 P2 AV3 13 P2 AV4 27 P2 AV2 25 P2 AV3 26 P2 AV2 23 P2 AV3 20 P2 AVl 13 P2 AV2 17 P2 AV3 20 P2 AV2 25 P2 AV3 15 P2 AV2 14 P2 AV2 15 P2 AV3 18 P2 AV2 12 P2 AV3 24 P2 AV2 27 P2 AV3 14 P2 AV4 16 P2 AVl 22 P2 AV2 26 P2 AV3 17 P2 AV4 16 P2 AV2 18 P2 AV3 15 P2 AV3 15 P2 AV4 11 P2 AV2 18 P2 AV2 12 P2 AVl 15 P2 AV4 19 P2 AV4

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-. 27

-.15

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.. 05

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.17

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.27

-.07

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.34

-.07

.26

-.12

.00

.10

-.12

-.28

.00

.05

-. 07

.10 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.00 TEC TEH TEC TEH

.00 TEC TEH

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

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.610 NBAZC I

23 H

23 H 23 H 23 H

23 H 23 H

I 25 HI 25 HI I

23 H 23 H 23 H

25 H

25 HI 25 HI I

23 H

23 H 23 H

23 H 23 H 23 H

23 H 23 H

25 H

25 H 25 H

25 H 37 H 37 H

37 H

39 H 35 H

37 H

45 H

45 H 37 H

+-----------+----+----+---------+----+---*+----+----+----+---------+--------*+---*+----+------+------+-**---+--+

INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LI

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- 40 38 40 38 41 38 30 39 30 39 30 39 41 39 41 39 41 39 24 40 24 40 24 40 40 40 45 40 26 41 30 41 39 41 41 41 41 41 45 41 49 41 37 42 37 42 41 42 41 42 40 43 40 43 45 45 45 45 45 46 40 47 39 50 1.94

.75

.84

.99 1.88 1.64

.89 2.92

.93

1. 53 1.54

.97 1.27

.73

.72 1.39

.79 1.61 1.35 1.13 1.00 1.25 1.57

.78 1.02 1.49

.76 1.36

.60 1.00

.92

.86 1.17

.96

.98 2.05 1.01

.63

.63 1.93

.77 1.44

.88 0

PCT 26 0

PCT 12 0

PCT 15 0

PCT 18 0

PCT 26 0

PCT 24 0

PCT 15 0

PCT 31 0

PCT 14 0

PCT 20 0

PCT 14 0

PCT 17 0

PCT 11 0

PCT 13 0

PCT 21 0

PCT 15 0

PCT 23 0

PCT 21 0

PCT 18 0

PCT 16 0

PCT 19 0

PCT 21 0

PCT 12 0

PCT 16 0

PCT 22 0

PCT 14 0

PCT 21 0

PCT 12 0

PCT 17 0

PCT 15 0

PCT 14 0

PCT 16 0

PCT 14 0

PCT 24 0

PCT 17 0

PCT 12 0

PCT 11 0

PCT 25 0

PCT 13 0

PCT 21 0

PCT 13 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AV2 P2 AV2 P2 AV3 P2 AV4 P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AVl P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AVl P2 AV2 P2 AV2 P2 AV2 P2 AV3

-. 27

.00

-.05

.00

.14

-.05

.00

-.04

.15

.05

.12

-.17

-.29

.12

.02

.00

-. 02

.00

-.17

.00

.22

-. 31

-.12

.00

.36

.00

.25

.00

-. 05

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.610 NBAZC

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37 HI I

35 HI I

45 HI I

37 HI I

37 HI 37 HI I

43 HI 43 HI I

35 HI 35 HI I

35 HI 35 HI 35 HI 35 HI I

35 HI I

37 HI 37 HI 37 HI I

31 HI 31 HI 31 HI I

35 HI I

43 HI I

37 HI I

37 HI 37 HI I

43 HI I

35 HI 35 H

35 H 35 H

37 H

37 H 43 H 43 H

43 H 37 H

35 H

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+-**---+--+

INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LI

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INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH!

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39 51

. 50 0

PCT 10 P2 AV3

-. 05 TEC TEH

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42 51 1.39 0

PCT 20 P2 AV2

.00 TEC TEH

.610 NBAZC 45 HI I

45 51

.94 0

PCT 15 P2 AV3

.00 TEC TEH

.610 NBAZC 43 H

41 52 45 52 44 55 45 55 45 55 42 56 45 59 45 59 20 60 20 60 44 60 46 60 46 60 40 61 40 61 45 61 45 61 45 61 45 61 42 62 42 62 45 62 40 64 39 65 39 65 39 65 45 65 36 66 40 66 39 67 39 67 44 67 39 68 40 68 40 68 41 68 41 68 40 69 41 69 41 69 41 69

.85

.76

.68 1.44 1.97 1.00 1.15 1.88 3.45 1.43

.72 1.33 2.44 3.95 2.43

.74

.82 3.65

.77

.80

.69

.60

.75

.86 1.41 2.13

.92 1.50

.79

.66

.91

.66

.66 1.40

.70 1.15 2.64

.72

.66

.84 1.02 0

PCT 13 0

PCT 21 0

PCT 25 0

PCT 15 0

PCT 18 0

PCT 25 0

PCT 34 0

PCT 20 0

PCT 11 0

PCT 18 0

PCT 27 0

PCT 36 0

PCT 28 0

PCT 13 0

PCT 14 0

PCT 35 0

PCT 14 0

PCT 15 0

PCT 13 0

PCT 10 0

PCT 14 0

PCT 15 0

PCT 20 0

PCT 26 0

PCT 15 0

PCT 22 0

PCT 15 0

PCT 12 0

PCT 15 0

PCT 12 0

PCT 21 0

PCT 13 0

PCT 18 0

PCT 30 0

PCT 12 0

PCT 14 0

PCT 16 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AVl P2 AV4 P2 AV4 P2 AVl P2 AV2 P2 AV2 P2 AV3 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AV2 P2 AV3 P2 AV3 P2 AV3 P2 AVl P2 AV2 P2 AV3 P2 AV3 P2 AV3 P2 AV2 P2 AVl P2 AV2 P2 AVl P2 AVl P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AVl P2 AVl P2 AV2 P2 AV3

.00

.00.

.02

.12

.00

.06

.00

.03

.00

.05

.00

.02

.. 07

.21

.00

.13

.00

.07

.00

.. 17

.00

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

.610 NBAZC

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41 H

41 H 39 H 41 H 41 H 13 H

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13 H

13 H 13 H

43 H 19 H 15 H 17 H 17 H 45 H

19 H

19 HI I

19 HI 19 HI I

17 HI I

17 HI 17 HI 17 Hi I

+-----------+----+----+--*******+****+****+****+****+****+*********+*********+****+****+******+*-**-*+******+**+

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+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 8EGT ENDT PDIA PTYPE CAL LI

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

39 39 45 45 42 43 43 43 46 46 39 41 43 43 47 32 32 32 32 37 37 37 37 39 39 39 40 40 40 46 46 46 16 37 37 40 37 37 39 40 41 41 41 30 30 37 37 37 37 70 70 70 70 71 71 71 71 71 71 72 72 72 72 72 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 73 74 74 74 74 75 75 75 75 75 75 75 76 76 76 76 76 76 2.36

.94 1.30 1.30

.86 1.39 2.57 1.30 1.11

.66 1.53 1.40

.78

.66

.76

.97

.85 1.09

.76

.87 2.28 1.16

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.89 2.94 1.00 1.02 2.73

1. 74 1.03

.86

.68

.68 3.30 1.37

.81 1.02 1.69 2.85 1.66

.91

.96 1.51 3.76 2.03

.75 0

PCT 0

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-.05

.00

-.02

.00

-.10

.32

.00

-. 02

.26

-.07

.00

-.12

-.07

.00

-.05

.00

.02

.00

-.06

.00

-.02

.00

-. 02

.05

.13

-.02

-.05

.00

.02

-. 07

.05

.00

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

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43 HI I

45 HI 45 HI 45 HI I

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45 H

43 H 17 H 17 H

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PCT 15 P2 AV3

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.84 0

PCT 14 P2 AV4

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.63

.76 1.10

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1. 79 1.46

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.94 1.68

.93 2.86 2.36 1.58 1.03

.70 1.81 1.12

.87 3.87 2.00 1.24

.60 1.15 1.13 0

PCT 0

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-.15

.15

-.03

.00

-.10

-.07

.00

.17

.07

.00

.19

.05

-.15

.29

.02

.00

-.28

.33

.02

.19

-.24

.07

-.10

.26

.00

-. 05

.10

-.10

.02

.00

-. 03

.00

.05

.00 TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH TEC TEH

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19 HI I

17 HI 17 HI I

17 HI I

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17 HI I

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19 HI 19 HI 19 HI I

17 HI I

43 HI 43 HI 43 HI I

43 HI I

19 HI 19 HI 19 HI I

19 HI I

45 HI 45 HI I

45 HI 45 HI 45 HI 45 HI I

45 HI 45 HI I

43 HI I

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INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCH!

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37

~3

. 73 0

PCT 13 P2 AVl

. 00 TEC TEH

. 610 NBAZC 43 HJ 37 83 1.43 0

PCT 20 P2 AV2

.00 TEC TEH

.610 NBAZC 43 HJ 40 40 40 40 39 39 39 39 40 41 39 39 41 41 38 38 38 39 39 29 36 38 39 39 39 40 40 40 40 41 41 33 36 36 40 40 40 83 83 83 83 84 84 84 84 84 84 85 85 85 85 86 86 86 86 86 87 87 87 87 87 87 87 87 87 87 87 87 88 88 88 88 88 88 47 88 20 89 36 89 36 89 38 89 38 89 40 89 40 89 41 89 2.45 2.25 1.19

.95

.87 1.30 1.40

.74

.71 1.04 1.10

1. 72 1.28

.98

'.67 1.69 1.16 1.39

.89

.65 1.09

.76 4.21 1.16

.78

.96 4.23

.96

.99 2.84 2.30 1.14 1.00 1.29 2.63 1.89

.97 1.33

.87

.87 1.00 1.37

.95

.88 1.15 0

PCT 0

PCT 28 27 18 15 15 20 21 14 13 17 18 23 20 16 13 24 19 21 16 12 18 13 37 18 14 16 37 16 16 31 28 19 17 20 30 25 17 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AVl P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV4 P2 AVl P2 AV2 P2 AV3 P2 AV4 P2 AV2 P2 AV3 P2 AV2 P2 AV2 P2 AV3 P2 AV2 P2 AV3 P2 AV4 0

PCT 21 P2 AV4 0

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SG - A ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R17 COE 20140501 05/14/2014 08:31:50

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9 Page 23 of 38 Tubes: 217 Records: 406 ST Max

SG - B ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R17 CDE 20140501 05/14/2014 08:31:50

+-----------+----+----+---------+----+----+----+----+----+---------+---------+----+----+------+------+------+--+

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SG - B ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R17 COE 20140501 05/14/2014 0B:31:50

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3 Page 26 of 38 Tubes: 63 Records: 115 ST Max

SG - C ANTI-VIBRATION BAR WEAR INDICATIONS Braidwood 2 A2R17 COE 20140501 05/14/2014 0B:31:50

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.610 NBAZC

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PCT 0

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71 HI I

73 HI 73 HI I

71 HI I

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73 HI I

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71 HI I

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73 HI I

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71 HI I

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73 HI I

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.88

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.68

.75

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.94

1. 75 0

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.17

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.75

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.79 2.12 1.79 1.81 1.29 1.62 0

PCT 0

PCT 49 PCT 0

PCT 0

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.15

.37

.00

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.23

-.30

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.30

.35

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.. 34

.. 37

.. 27

-.15

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.12

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.10

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.. 38

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.31

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49 H

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49 H

49 H 49 H 49 H 49 H

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J INSPDATE ROW COL VOLTS DEG IND PER CHN LOCN INCHl INCH2 BEGT ENDT PDIA PTYPE CAL LJ

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PCT 18 P2 AV2

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30 101

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27 106

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5 Page 38 of 38 Tubes: 111 Records: 183 ST Max

v t e Letter Sequence Request
TAC:MF5222, (Approved, Closed)
Initiation Request Acceptance... Administration Questions Answers 27 April 2015 Results Approval Other:
MONTHYEAR2015-04-27 [Table View]

BW140098, Steam Generator Tube Inspection Report for Refueling Outage 17

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Person / Time
ML14318A211
Site:	Braidwood (NPF-077)
Issue date:	11/14/2014
From:	Kanavos M Exelon Generation Co
To:	Document Control Desk, Office of Nuclear Reactor Regulation
References
BW140098
Download: ML14318A211 (39)
v • d • e

BW140098, Steam Generator Tube Inspection Report for Refueling Outage 17

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