ML17058A085
| ML17058A085 | |
| Person / Time | |
|---|---|
| Site: | Braidwood  |
| Issue date: | 02/27/2017 |
| From: | Marchionda-Palmer M Exelon Generation Co |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| BW170017 | |
| Download: ML17058A085 (15) | |
Text
ti Exelon Generation Braidwood Station South Route 84 Braceville, IL 60407-9619 www.exeloncoro.com February 27, 2017 BW170017 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Unit 1 Renewed Facility Operating License No. NPF-72 NRC Docket No. STN 50-456
Subject:
Braidwood Station, Unit 1 Steam Generator Tube Inspection Report for Refueling Outage 19 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 1 Refueling Outage 19 (A 1R19).
Please direct any questions you may have regarding this submittal to Mr. Steven Reynolds, Regulatory Assurance Manager, at (815) 417-2800.
Respectfully,
/JtAMJ~
Marri Marchionda-Palmer Site Vice President Braidwood Station
Attachment:
Braidwood Station, Unit 1 Steam Generator Tube Inspection Report Refueling Outage 19 cc: NRC Regional Administrator, Region Ill NRC Senior Resident Inspector- Braidwood Station NRC Project Manager, NRA- Braidwood and Byron Stations Illinois Emergency Management Agency - Division of Nuclear Safety
Exelon Generation Company, LLC BRAIDWOOD STATION UNIT 1 35100 South Rte. 53, Suite 84 Braceville, IL 60407 COMMERCIAL OPERATION: July 29, 1988 BRAIDWOOD STATION UNIT 1 STEAM GENERATOR EDDY CURRENT INSPECTION REPORT REFUELING OUTAGE 19 (A1R19)
September 2016 Mailing Address 4300 Winfield Road Warrenville, IL 60555 Page 1 of 14
TABLE OF CONTENTS Introduction .............................................................................................. 3 Steam Generator Inspection Scope (TS 5.6.9.a) .............................................. 3 Degradation Mechanisms Found (TS 5.6.9.b) ................................................. .4 Nondestructive Examination Techniques Utilized for Each Degradation Mechanism Found During A1 R19 (TS 5.6.9.c) ................................................ 4 Location, Orientation (if linear), and Measured Sizes of Service Induced Indications (TS 5.6.9.d) ............................................................................5-6 Plugging Summary (TS 5.6.9.e and TS 5.6.9.f) ............................................... 7 Results of Condition Monitoring (TS 5.6.9.g) ................................................... 8-11 Attachment A- Fan Bar Wear Indications ................................................... 12-14 Page 2of14
Introduction Braidwood Station Unit 1 operates with four Babcock & Wilcox Replacement Steam Generators (SGs) in the four loop pressurized water reactor system. The SGs each contain 6633 thermally treated Alloy-690 U-tubes that have a nominal diameter of 0.6875 inches and a nominal thickness of 0.040 inches. The tubes are supported by stainless steel lattice grid structures and fan bars. The tubes are hydraulically expanded into the full depth of the tubesheet. Main Feedwater enters the SGs above the tube bundle through a feedring and J-tubes. The replacement SGs were installed at the end of Cycle 7, in fall 1998.
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.d require that 100% of the Unit 1 tubes are to be inspected at sequential periods of 144, 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.
The Braidwood Unit 1 replacement SGs are currently in their thirteenth (13th) cycle of operation and are on an 18-month fuel cycle. During Cycles 17, 18, and 19, Braidwood Unit 1 operated a total of 4.218 Effective Full Power Year (EFPY) since the previous SG inspection during A1 R16. The replacement SG's have operated a total of 16.972 EFPY through the end of Cycle 19, which is 44.16 EFPM within the 120 EFPM inspection period.
The A 1R19 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 September 29, 2016 through October 5, 2016 by the Westinghouse Electric Company LLC.
Steam Generator Inspection Scope {TS 5.6.9.a)
Braidwood Unit 1 Refueling Outage 19 (A 1R19) was the third outage and first SG inspection of the 120 EFPM period, the next SG inspection is planned for A 1R22, which will be the sixth refuel outage within the 120 EFPM period. The following inspections were performed during A 1R 19 to ensure that 100% of the tubes were inspected during the period as required by TS 5.5.9.d.
Primary Side Scope:
- 100% full-length bobbin coil eddy current examination of all four SGs.
- All Hot leg Dent & Dings 2::,2.0 volts in all four SG's with + Point'.
- Special Interest inspection of bobbin and X-Probe indications with +Point'.
- Bobbin examinations of all in-service tubes within five tube of the no-tube lane or periphery using Westinghouse ETSS-FOW-AHC-BOB for foreign object wear detection.
- Visual Inspection of all existing tube plugs (85 plugs)
- Visual inspection of tubesheet, divider plate, channel head welds and cladding for degradation.
Secondary Side Scope:
- Sludge lancing in all four SGs including "post sludge lance" Foreign Object Search and Retrieval (FOSAR)
- Feedring Inspection (1 DSG)
- Steam Drum Internal Inspection (1 DSG)
- Upper Bundle Inspection (1 DSG)
Page 3 of 14
Degradation Mechanisms Found (TS 5.6.9.b)
No evidence of cladding or weld breaches or evidence of channel head wastage was identified during the primary side visual inspections of all four SG's. In addition, no degradation or structural distortion was observed during Foreign Object Search and Retrieval (FOSAR) or during visual inspections of the 1D SG upper bundle, feedring, and steam drum region.
The Table below provides a summary of all the degradation, by mechanism, identified during the A 1R19 inspections (all mechanisms were present during previous inspections). No evidence of any cracking was found. No degradation was identified during the secondary side visual inspections.
Summary of A1R19 Degradation Indications by Mechanism Degradation Mechanism 1ASG 1B SG 1CSG 1DSG Total Fan Bar Wear 8 18 38 20 84 Lattice Grid Wear 4 4 2 1 11 Foreign Object Wear 9 1 3 0 13 Nondestructive Examination Techniques Utilized for Each Degradation Mechanism Found During A1 R19 (TS 5.6.9.c)
Steam Generator eddy current examination techniques used (see Table below) were qualified in accordance with Appendix Hor 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 1 SGs during A 1R19.
APPENDIX H & APPENDIX I TECHNIQUES Degradation ETSS Location Orientation ETSS Probe Mode Rev Fan Bar 96004.1 (D)
Wear Vol 13 Bobbin 96004.3 (S)
Lattice 96004.1 (D)
Wear Vol 13 Bobbin Grid 96004.3 (S) 96004.1 (D) 13 Bobbin 27091.1 /.2(D) 2 Bobbin 96910.1 (D) 7 +Point Foreign Wear Vol 13091.1 (D&S) 0 +Point Objects 128413 (D) 3 Bobbin FOW-AHC-BOB (D) 0 Bobbin 27902.1 (S) 2 +Point (D) = Detection (S) =Sizing Page 4of14
Location, Orientation (if linear), and Measured Sizes of Service Induced Indications (TS 5.6.9.d)
- Fan bar Wear -A total of 84 indications of fan bar wear were found in the Steam Generators.
The deepest indication measured 16%TW as measured by the EPRI Appendix H qualified bobbin coil examination technique 96004.3 which is consistent with results from previous inspections. No tubes were plugged as a result of fan bar wear. The Table below provides a summary of Fan bar wear degradation. Refer to Attachment A for detailed locations and sizing for all Fan Bar wear indications.
A1R19 Fan Bar Wear Summary 1ASG 1BSG 1CSG 1DSG Total Indications Indications Indications Indications
<10% TW 8 18 32 9 67 10-19% TW 0 0 6 11 17
>=20% TW 0 0 0 0 0 TOTAL 8 18 38 20 84
- Lattice Grid Wear - Eleven (11) indications of wear related to the lattice grid supports in eleven tubes were reported during the A 1R19 outage. The deepest indication measured 9%TW as measured by the EPRI Appendix H qualified bobbin coil examination technique 96004.3. Two (2) of these indications were newly reported, not present in past history. These indications were inspected with +Point' to confirm that the morphologies of the indications were consistent with lattice grid wear. The new number of indications is in line with Byron Unit-1 SGs, which are of the same design. No tubes were plugged as a result of lattice grid wear. The table below provides a listing of all tubes that contain lattice grid wear.
A1 R19 Lattice Grid Wear Indication Listing Newly A1R19 Reported SG Row Col Location Depth or
(%lW)
Repeat?
1A 39 70 01H -1.51 8 Repeat 1A 72 19 05H + 0.2 2 Repeat 1A 75 108 07H-1.48 7 Repeat 1A 118 71 01C + 0.9 4 Repeat 18 47 24 08H-1.6 5 Repeat 18 87 24 01C - 0.76 9 New 18 90 107 07H + 055 8 Repeat 18 119 70 02C + 1.13 9 Repeat 1C 9 92 05C-1.54 8 Repeat 1C 73 90 05H + 1.27 2 New 10 41 70 08H-1.55 7 Repeat Page 5 of 14
- Foreign Object Wear - A total of 13 indications of secondary side foreign object (FO) wear were reported in 12 tubes during A 1R19. The largest depth measured was 27% TW using Examination Technique Specification Sheet {ETSS) 27902.1. Four tubes in SG 1A (R81 C22, R82C23, R83C22*, and R84C23) are clustered around a foreign object that could not be removed during the FOSAR effort. These four tubes were plugged and stabilized. The remaining nine tubes with foreign object wear indications were left in service since the object that presumably caused the indication is no longer present and the measured depth was less than the Technical Specification limit of 40%TW.
- Tube R83C22 only contained a PLP (Possible Loose Part) signal without wear.
A1 R19 Foreign Object Wear Foreign A1R19 A1R19 A1R19 Object Axial Circumferential SG Row Col Location Depth Still Extent Extent
(%TW) Present?
(Inches) (lnches)/(Degrees)
SG1A 17 138 TSH + 0.19 16 0.17" 0.37"/62 0
No SG1A 20 139 TSH + 0.09 7 0.14" 0.34"/57 0
No 0
Yes SG1A 81 22 TSC + 1.12 27 0.53" 0.42"/71 0
Yes SG1A 82 23 TSC +0.77 24 0.33" 0.29"/48 0
Yes SG1A 82 23 TSC + 0.21 22 0.25" 0.17"/28 0
Yes SG1A 84 23 TSC + 0.21 19 0.23" 0.2"/34 SG1A 96 107 TSH + 0.13 12 0.14" 0.22"/37 0
No SG1A 97 108 TSH +0.27 11 0.11" 0.29"/48 0
No SG1A 98 107 TSH + 0.12 10 0.12" 0.2"/34 0
No SG1B 98 47 TSH +0.03 16 0.11" 0.22"/37 0
No SG1C 1 72 TSH + 0.22 1 0.15" 0.26"/43 0
No SG1C 2 73 TSH + 0.33 1 0.21" 0.31"/52 0
No SG1C 5 72 TSH + 0.22 25 0.3" 0.28"/46 0
No Page 6 of 14
Plugging Summary {TS 5.6.9.e and TS 5.6.9.f)
As a result of the A 1R19 SG inspections, performed in accordance with TS 5.5.9.d, the modes of tube degradation found were Fan Bar wear, Lattice Grid wear, and secondary side foreign object (FO) wear.
Four (4) tubes in 1A SG (R81C22, R82C23, R83C22, and R84C23) were stabilized and plugged based on an irretrievable object in 1A Steam Generator. Inspection results justified a 3-cycle inspection interval with no adverse consequences for all four SGs.
Note: There are no approved tube repair methods for the Unit 1 SGs. No tube sleeving was performed.
A1 R19 Tube Plugging by Degradation Mechanism {TS 5.6.9.e)
Degradation Mechanism 1ASG 18 SG 1CSG 1DSG Total Fan Bar Wear 0 0 0 0 0 Lattice Grid Wear 0 0 0 0 0 Foreiqn Object Wear 0 0 0 0 0 Preventative 4 0 0 0 4 Total Pluaaed during A 1R 19 4 0 0 0 4 Tube Plugging to Date {Number and Percentage per SG) {TS 5.6.9.f) 1ASG 1BSG 1CSG 1DSG Total Total Pluaaed during A 1R 19 4 0 0 0 4 Total Stabilized during A1 R19 4 0 0 0 4 Total Pluqaed throuah A1R19 32 40 16 1 89 Total Percent Plugged through 0.48% 0.60% 0.24% 0.02% 0.33%
A1R19 Page 7 of 14
Results of Condition Monitoring (TS 5.6.9.g)
A Condition Monitoring (CM) assessment was performed for each inservice degradation mechanism found during the A 1R19 SG inspection. The condition monitoring assessment was performed in accordance with TS 5.5.9.a and NEI 97-06 Rev. 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. 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).
Condition monitoring was verified by comparing the dimensions of each flaw against the CM curves that were documented in the Degradation Assessment (DA). The CM curves are a plot of depth versus axial extent. The curves account for uncertainties in the burst pressure model, material properties, and NOE sizing errors. The CM curves are generated via random sampling of these uncertainties using Monte Carlo simulation techniques. The CM curves account for pressure loading only. Non-pressure loads were also considered. Non-pressure loads are those loads acting on the tube due to mechanical and/or thermal conditions and include bending and/or axial loads. A review of the screening guidance from the EPRI SG Integrity Assessment Guidelines provides the basis for concluding that the structural and CM limits are not impacted by non-pressure loads for Braidwood Unit 1. Therefore, use of the CM curves based on pressure loading only is appropriate and justified.
No indications met the requirements for proof or leakage testing; therefore, no In Situ pressure tests were performed during A 1R19. In addition, no tube pulls were performed during A 1R19.
Braidwood Station Unit 1 did not observe any SG primary to secondary operational leakage over the last 3 operating cycles preceding the inspection. This is based on chemistry sampling taken from the Steam Jet Air Ejector, liquid SG blowdown sample locations, and no potential sources of tube leakage were found during SG tube inspections.
Page 8 of 14
The sections below provide a summary of the condition monitoring assessment for each degradation mechanism found during A 1R19.
Fan Bar Wear- The largest Fan Bar wear indication found during the A 1R19 inspection was 16% TW as measured by the EPRI Appendix H qualified technique 96004.3, Rev. 13. This is well below the Fan Bar wear structural limit and CM limit curves. No tubes were required to be plugged.
Condition Monitoring Results for Fan Bar Wear 100 Note: CM and structural limit curves are based on structural lengths and depths.
90 Indication depths are conservatively plotted using maximum depths.
80 70
'if;J
.t::
Cl
- I 0
60
.t::
I-c:G>
u G>
50
.t::
ii G> 40 Q
~
- I ti 2 30 ii5 --Structural Limit 20 - - CM Limit (96004.3)
Fan Bar Wear Indications 10 0
0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 Structural Length (Inches)
Page 9 of 14
Lattice Grid Wear-The largest Lattice Grid wear indication found during the A1 R19 inspection was 9% TW, as measured by the EPRI Appendix H qualified technique 96004.3, Rev. 13. This is well below the Lattice Grid wear structural limit and CM limit curves. No tubes were required to be plugged.
Condition Monitoring Results for Lattice Grid Wear 100 Note: CM and structural limit curves are based on structural lengths and depths.
90 Indication depths are conservatively plotted using maximum depths.
80 70 1.s:
Cl
- s 60 2
.s:
I-cQ) ----~----~----------
I.)
Q) 50
.s:
ii Q) 40 c
...:::s iii b
2 30 ---Structural Limit tii
- -CM Limit (96004.3) 20 Lattice Grid Wear Indications 10 0
0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 Structural Length (Inches)
Page 10 of 14
Foreign Object Wear* The largest foreign object wear indication found during the A1 R19 inspection was 27% TW with axial length of 0.62 inches as measured by the EPRI Appendix H qualified technique 27902.1, Rev 2. This is well below the Foreign Object wear structural limit and CM limit curves. No tubes were required to be plugged due to FO wear. The four tubes were plugged preventivaly due to the priority "1" object not being retrieved.
Condition Monitoring Results for Foreign Object Wear 100 Note: CM and structural limit curves on this chart are based on the model for 90 . 360' uniform thinning.
80 70
= IC
~Cl
- i 60 2
.r.
I- -
=-=-=----~--~~~-J c
u 50 --------------~
.r.
c ii. 40 E
- i E
- ( 30 -Structural Limit IC
- !iE
- - Condition Monitoring Limit 20 Foreign Object Wear (27902.1) 10 0
0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 Total Length (Inches)
Page 11of14
ATTACHMENT A Fan Bar Wear Indications SG1A SG Date Row Col Ind Per Volts Deg Chn Locn lnch1 BegT EndT PDia PType Cal 1A 01-Sep-16 31 4 PCT 6 0.38 0 P2 F05 0.88 TEC TEH 0.56 C8ACZ 73 1A 01-Sep-16 57 78 PCT 5 0.25 0 P2 F05 1.76 TEC TEH 0.56 C8ACZ 55 1A 01-Sep-16 63 70 PCT 3 0.16 0 P2 F05 0.52 TEC TEH 0.56 C8ACZ 51 1A 01-Sep-16 68 49 PCT 4 0.21 0 P2 F04 0.63 TEC TEH 0.56 C8ACZ 63 1A 01-Sep-16 71 62 PCT 4 0.23 0 P2 F04 -1.6 TEC TEH 0.56 C8ACZ 45 1A 01-Sep-16 77 84 PCT 3 0.25 0 P2 F05 -0.98 TEC TEH 0.56 C8ACZ 53 1A 01-Sep-16 84 87 PCT 8 0.39 0 P2 F05 -0.86 TEC TEH 0.56 CBACZ 55 1A 01-Sep-16 88 67 PCT 4 0.25 0 P2 F07 1.9 TEC TEH 0.56 C8ACZ 49 SG1B SG Date Row Col Ind Per Volts Deg Chn Locn lnch1 BegT EndT PDia PType Cal 18 01-Sep-16 42 137 PCT 5 0.21 0 P2 F06 1.16 TEC TEH 0.56 C8ACZ 81 18 01-Sep-16 45 130 PCT 7 0.29 0 P2 F05 -1.41 TEC TEH 0.56 CBACZ 81 18 01-Sep-16 52 63 PCT 7 0.23 0 P2 F05 1.2 TEC TEH 0.56 CBACZ 49 18 01-Sep-16 57 42 PCT 8 0.43 0 P2 F05 -1.53 TEC TEH 0.56 CBACZ 29 18 01-Sep-16 60 73 PCT 7 0.28 0 P2 F05 -1.9 TEC TEH 0.56 C8ACZ 45 18 01-Sep-16 65 70 PCT 6 0.42 0 P2 F06 -1.19 TEC TEH 0.56 CBACZ 47 18 01-Sep-16 68 65 PCT 6 0.23 0 P2 F05 0.4 TEC TEH 0.56 CBACZ 45 18 01-Sep-16 71 62 PCT 4 0.22 0 P2 F04 0.74 TEC TEH 0.56 CBACZ 47 18 01-Sep-16 73 102 PCT 8 0.34 0 P2 F05 1.05 TEC TEH 0.56 C8ACZ 73 18 01-Sep-16 76 73 PCT 9 0.38 0 P2 F05 -0.86 TEC TEH 0.56 CBACZ 45 18 01-Sep-16 78 57 PCT 7 0.32 0 P2 F07 -1.38 TEC TEH 0.56 CBACZ 41 18 01-Sep-16 80 71 PCT 6 0.21 0 P2 F05 1.12 TEC TEH 0.56 CBACZ 49 18 01-Sep-16 82 69 PCT 5 0.24 0 P2 F06 -1.16 TEC TEH 0.56 C8ACZ 45 18 01-Sep-16 82 79 PCT 7 0.24 0 P2 F06 1.9 TEC TEH 0.56 C8ACZ 57 18 01-Sep-16 88 69 PCT 7 0.28 0 P2 FOB 0.66 TEC TEH 0.56 C8ACZ 45 18 01-Sep-16 100 57 PCT 6 0.38 0 P2 F07 1.77 TEC TEH 0.56 C8ACZ 41 18 01-Sep-16 107 68 PCT 7 0.31 0 P2 F05 1.49 TEC TEH 0.56 C8ACZ 51 18 01-Sep-16 111 70 PCT 6 0.39 0 P2 F06 -1.32 TEC TEH 0.56 C8ACZ 47 Page 12 of 14
ATTACHMENT A Fan Bar Wear Indications SG 1C SG Date Row Col Ind Per Volts Deg Chn Locn lnch1 BegT EndT PDia PType Cal 1C 01-Sep-16 35 70 FCT 8 0.38 0 P2 F05 1.85 TEC TEH 0.56 CBACZ 41 1C 01-Sep-16 49 74 FCT 6 0.28 0 P2 F05 0.51 TEC TEH 0.56 CBACZ 37 1C 01-Sep-16 55 56 FCT 6 0.3 0 P2 F05 1.85 TEC TEH 0.56 CBACZ 63 1C 01-Sep-16 57 78 FCT 6 0.33 0 P2 F06 0.82 TEC TEH 0.56 CBACZ 37 1C 01-Sep-16 59 68 FCT 5 0.17 0 P2 F05 0.51 TEC TEH 0.56 CBACZ 43 1C 01-Sep-16 66 61 FCT 11 0.47 0 P2 F07 1.65 TEC TEH 0.56 CBACZ 61 1C 01-Sep-16 74 63 FCT 4 0.22 0 P2 F06 -1 TEC TEH 0.56 CBACZ 57 1C 01-Sep-16 74 75 FCT 6 0.24 0 P2 F05 -0.91 TEC TEH 0.56 CBACZ 39 1C 01-Sep-16 75 50 FCT 7 0.26 0 P2 F06 1.74 TEC TEH 0.56 CBACZ 65 1C 01-Sep-16 76 65 FCT 4 0.16 0 P2 F05 0.93 TEC TEH 0.56 CBACZ 61 1C 01-Sep-16 77 66 FCT 7 0.26 0 P2 F05 -0.54 TEC TEH 0.56 CBACZ 45 1C 01-Sep-16 77 68 FCT 15 0.63 0 P2 F05 -0.57 TEC TEH 0.56 CBACZ 43 1C 01-Sep-16 79 66 FCT 8 0.3 0 P2 F05 -0.57 TEC TEH 0.56 CBACZ 45 1C 01-Sep-16 79 94 FCT 10 0.59 0 P2 F06 -1.18 TEC TEH 0.56 CBACZ 33 1C 01-Sep-16 80 63 FCT 6 0.3 0 P2 F06 -1.54 TEC TEH 0.56 CBACZ 57 1C 01-Sep-16 90 79 FCT 15 0.71 0 P2 F06 1.58 TEC TEH 0.56 CBACZ 39 1C 01-Sep-16 91 72 FCT 7 0.26 0 P2 F06 0.55 TEC TEH 0.56 CBACZ 39 1C 01-Sep-16 92 57 FCT 7 0.29 0 P2 F05 1.54 TEC TEH 0.56 CBACZ 75 1C 01-Sep-16 92 69 FCT 11 0.63 0 P2 F05 -0.87 TEC TEH 0.56 CBACZ 41 1C 01-Sep-16 93 78 FCT 5 0.24 0 P2 F05 -0.7 TEC TEH 0.56 CBACZ 37 1C 01-Sep-16 94 63 FCT 6 0.36 0 P2 F05 -1.4 TEC TEH 0.56 CBACZ 57 1C 01-Sep-16 95 58 FCT 9 0.37 0 P2 F05 -0.77 TEC TEH 0.56 CBACZ 75 1C 01-Sep-16 96 57 FCT 7 0.28 0 P2 F05 0.52 TEC TEH 0.56 CBACZ 75 1C 01-Sep-16 97 86 FCT 7 0.4 0 P2 F05 1.34 TEC TEH 0.56 CBACZ 37 1C 01-Sep-16 97 88 FCT 5 0.22 0 P2 F05 1.28 TEC TEH 0.56 CBACZ 35 1C 01-Sep-16 98 59 FCT 9 0.64 0 P2 F05 1.2 TEC TEH 0.56 CBACZ 73 1C 01-Sep-16 99 84 FCT 5 0.2 0 P2 F07 0.69 TEC TEH 0.56 CBACZ 39 1C 01-Sep-16 100 75 FCT 7 0.28 0 P2 F05 -1.5 TEC TEH 0. 39 1C 01-Sep-16 101 60 FCT 5 0.32 0 P2 F05 1.49 TEC TEH 0.56 CBACZ 73 1C 01-Sep-16 101 84 FCT 8 0.34 0 P2 F07 0.65 TEC TEH 0.56 CBACZ 39 1C 01-Sep-16 102 61 FCT 10 0.43 0 P2 F05 0.95 TEC TEH 0.56 CBACZ 75 1C 01-Sep-16 104 63 FCT 8 0.53 0 P2 F05 1.38 TEC TEH 0.56 CBACZ 73 1C 01-Sep-16 105 72 FCT 7 0.25 0 P2 F03 -0.63 TEC TEH 0.56 CBACZ 45 1C 01-Sep-16 106 59 FCT 8 0.56 0 P2 F05 0.95 TEC TEH 0.56 CBACZ 73 1C 01-Sep-16 107 70 FCT 9 0.38 0 P2 F05 1.44 TEC TEH 0.56 CBACZ 47 1C 01-Sep-16 107 76 FCT 4 0.16 0 P2 F05 -1.58 TEC TEH 0.56 CBACZ 45 1C 01-Sep-16 107 80 FCT 7 0.21 0 P2 F05 1.41 TEC TEH 0.56 CBACZ 43 1C 01-Sep-16 111 88 FCT 5 0.19 0 P2 FOB 1.84 TEC TEH 0.56 CBACZ 43 Page 13 of 14
ATTACHMENT A Fan Bar Wear Indications SG1D SG Date Row Col Ind Per Volts Deg Chn Locn lnch1 BegT EndT PDia PType Cal 10 10 01-Sep-16 01-Sep-16 ill=@ 12 5
0.3 0.15 0
0 P2 P2 F05 F05 1.29 1.26 TEC TEC TEH TB-i 0.56 0.56 CBACZ CBACZ 39 55 10 01-Sep-16 72 71 FCT 7 0.26 0 P2 F06 0.97 TEC TB-i 0.56 CBACZ 23 10 01-Sep-16 B1 70 FCT 13 0.5B 0 P2 F06 -1.32 TEC TB-i 0.56 CBACZ 23 10 01-Sep-16 85 68 FCT 10 0.36 0 P2 F07 1.43 TEC TEH 0.56 CBACZ 55 10 01-Sep-16 85 70 FCT 16 0.75 0 P2 F06 -1.3B TEC TB-i 0.56 CBACZ 23 10 01-Sep-16 B6 67 FCT 6 0.32 0 P2 F06 0.66 TEC TB-i 0.56 CBACZ 53 10 01-Sep-16 B6 69 FCT 13 0.55 0 P2 F07 -1.25 TEC TEH 0.56 CBACZ 55 10 01-Sep-16 B7 64 FCT 11 0.41 0 P2 F06 1.26 TEC TB-i 0.56 CBACZ 55 10 01-Sep-16 93 70 FCT 11 0.47 0 P2 F06 -1.0B TEC TB-i 0.56 CBACZ 23 10 01-Sep-16 95 6B FCT 10 0.37 0 P2 F05 -1.31 TEC TB-i 0.56 CBACZ 55 10 01-Sep-16 95 6B FCT 13 0.52 0 P2 F06 1.24 TEC TB-i 0.56 CBACZ 55 10 01-Sep-16 96 69 FCT 12 0.47 0 P2 FOB 0.53 TEC TB-i 0.56 CBACZ 55 10 01-Sep-16 97 72 FCT 7 0.54 0 P2 F06 0.49 TEC TB-i 0.56 CBACZ 21 10 01-Sep-16 97 74 FCT 10 0.37 0 P2 FOB -0.67 TEC TB-i 0.56 CBACZ 23 10 01-Sep-16 99 64 FCT B 0.2B 0 P2 F05 -1.41 TEC T8-i 0.56 CBACZ 55 10 01-Sep-16 100 67 FCT 3 0.12 0 P2 FOB 1.32 TEC T8-i 0.56 CBACZ 53 10 01-Sep-16 103 6B FCT 9 0.32 0 P2 F07 -1.25 TEC T8-i 0.56 CBACZ 55 10 01-Sep-16 104 53 FCT 7 0.33 0 P2 F05 1.45 TEC T8-i 0.56 CBACZ 59 10 01-Sep-16 104 77 FCT 7 0.45 0 P2 F06 -1.33 TEC T8-i 0.56 CBACZ 21 Page 14 of 14