ML19200A029

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Spring 2019 - 180 Day Steam Generator Report
ML19200A029
Person / Time
Site: Calvert Cliffs Constellation icon.png
Issue date: 07/16/2019
From: Laura Smith
Exelon Generation Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
Download: ML19200A029 (24)
v • d • e


Text

    • r w* ..
~ Exelon. Generation~::> . lari:y o; Smith

. . . ManagersRe_gulat_ory Assuraoce : : : : : . : .

Calvert Cliffs NudearJ'ower Plant 1650 Calvert Cliffs'Parkway .

. Lustiv, MD 20657 .

  • 4i0 495 52:t9 Office.
  • l':'ww.ex_eloncorp;coin:
  • l~rryim)th2@exeloncorp.com
  • TS:S.6:9 ..
1:uJy 16, 2019 U; $:Nuclear Regulatory:Commission ATIN: Document . Coritr'cil besk. .

Washington, pp'. 20555 Calvert Cliffs Nuclear Pow~r :P:l~nt, Unit No.* 12::

  • . Renewed :Facility Operating License No. DPR-69 .

... :: ..NRC Docket No.

50,.318

Subject:

  • ... :. Spring 2019 ~ 180 .

Day Steam Generator. . .Report

Reference:

1. .. Calyert Cliffs Nuciear Power Plant Units 1 arid? Technical Specif1eation 5.6.9

In accordarice With:Referenc.e 1;'Attachment (1) provides the;result~ of the ste:am' generator tube 1hspec~ion.

conducted on CalvertCliffaUnit 2 in 2019. This report includes:the.riumber and exten:t:oftubes examined: .:

. and ind1eatiortsidentified... . . . . .. . . . .. .. . .. .. . .. . ....

There are no regulatory c~mmitments contairi~d fo this corresporidemee.

Should you ha:Vci:questions regardin~ this matter, please ~ontact Mr. Larry.D.:~mith at (410)495-52.19.

  • . R~sP:~tfullyA, *. : .. \:

~_

. . .... .~ .- . .~

LarryD. Smith * : .. :>:

. Regulatory }\s5:urance Manager

.Ll)S{KLG/lmd

)tD(

Attachment:

. .(1) Calvert Cliffs CC2R23 180~Day S,team Generator Tub~ Inspection Report :*. *. *

.fV/~

.NRC:Project Manager, Calvert Cliffs.  :: <NRC ResidenUnspector, Calvert.Cliffs NRC.Regional.Admin1strator; Region I D.. A Tancabel

. ' . - ' MD-:DNR. , '

ATTACHMENT (1)

Calvert Cliffs CC2R23 180-Day Steam Generator Tube Inspection Report Calvert Cliffs Nuclear Power Plant July 16, 2019

Exelon Generation Company, LLC Calvert Cliffs Nuclear Power Plant 1650 Calvert Cliffs Parkway Lusby, MD 20657 Calvert Cliffs Unit 2 STEAM GENERATOR TUBE INSPECTION REPORT REFUELING OUTAGE 23 March 2019 Rev.a Page 1 of 22

Revisions Page 2 of 22

TABLE OF CONTENTS

1.0 INTRODUCTION

........................................................................................................................ 4 2.0 THE SCOPE OF THE INSPECTIONS PERFORMED ON EACH SG (5.6.9.A} ................. 5 3.0 DEGRADATION MECHANISMS FOUND (5.6.9.B} .............................................................. 6 4.0 . NONDESTRUCTIVE EXAMINATION TECHNIQUES UTILIZED FOR EACH DEGRADATION MECHANISM (S.6.9.C) ........................................................................................... 6 Table 1 NDE Techniques Utilized for Sizing Identified Degradation ........................................................................... 7 5.0 LOCATION, ORIENTATION (IF LINEAR}, AND MEASURED SIZES (IF AVAILABLE) OF SERVICE INDUCED INDICATIONS (5.6.9.D} .................................................. 7 5.1 FAN BAR WEAR ........................................................................................................................................................ 7 Table 2 - Fan Bar Wear Indication Summary .................................................................................................................. 8 Figure 1 - Distribution of Fan Bar Wear Depth .............................................................................................................. 8 Figure 2 - SG21 Fan Bar Wear Map ............................................................................................................................... 9 Figure 3 SG22 Fan Bar Wear Map ............................................................................................................................... 9 5 .2 LATTICE GRID SUPPORT WEAR .............................................................................................................................. 10 Table 3 -Summary of Lattice Grid Support Wear Indications ...................................................................................... 10 5.3 FOREIGN OBJECT WEAR ......................................................................................................................................... 10 Table 4 Summary of Foreign Object Wear .................................................................................................................. 11 6.0 NUMBER OF TUBES PLUGGED DURING THE INSPECTION OUTAGE FOR EACH ACTIVE DEGRADATION MECHANISM (5.6.9.E) ........................................................................ 11 7.0 TOTAL NUMBER AND PERCENTAGE OF TUBES PLUGGED TO DATE AND THE EFFECTIVE PLUGGING PERCENTAGE IN EACH STEAM GENERATOR (5.6.9.F} ............ 11 Table 5 -Tube Plugging Summary ................................................................................................................................ 12 8.0 THE RESULTS OF CONDITION MONITORING, INCLUDING RESULTS OF TUBE PULLS AND IN-SITU TESTING (5.6.9.G) ........................................................................................ 12 8.1 FAN BAR WEAR ...................................................................................................................................................... 12 8.2 FOREIGN OBJECT WEAR ......................................................................................................................................... 12 8.3 LATTICE GRID WEAR ............................................................................................................................................. 13 Figure 4 Condition Monitoring Results for Fan Bar Wear ......................................................................................... 13 Figure 5 - Condition Monitoring for Foreign Object Wear .......................................................................................... 14 Figure 6 - Condition Monitoring for Lattice Grid Wear ............................................................................................... 15 8.4 OPERATIONAL LEAKAGE CRITERION AND VALIDATION OF PREVIOUS OA ............................................................. 15 APPENDIX A - TYPICAL U-BEND SUPPORT SYSTEM ............................................................. 16 APPENDIX B CALVERT CLIFFS U-2 TUBE SUPPORT LAYOUT ............................................ 17 APPENDIX C - CC2R23 FAN BAR WEAR

SUMMARY

................................................................ 18 TABLEC-1: SG21 FAN BAR WEAR

SUMMARY

.................................................................................................................... 18 TABLEC-2: SG22FANBAR WEAR

SUMMARY

.................................................................................................................... 20 Page 3 of 22

Calvert Cliffs Nuclear Power Plant Unit 2 CC2R23 Spring 2019 Steam Generator Inspection 1.0 Introduction Calvert Cliffs Nuclear Power Plant Unit 2 (CCNPP2) has two recirculating steam generators designed and fabricated by Babcock and Wilcox (B&W) of Cambridge, Ontario, Canada.

These replacement steam generators (RSG's), SG21 and SG22 were installed in 2003.

Each RSG contains 8471 tubes. Three tubes were plugged in SG21 during manufacturing.

The tubing material is thermally treated lnconel 690 having a nominal outer diameter (OD) of

0. 75 inches and a nominal wall thickness of 0.042 inches. The RSG's were designed and fabricated to the ASME Boiler and Pressure Vessel Code, Section Ill, subsection NB (Class 1), 1989 Edition with no Addenda. All tubes with a bend radius of 12 inches or less (the first 18 rows) were thermally stress-relieved following bending to reduce the residual stress imparted during bending.

The straight section of the tube bundle is supported by seven 410 stainless steel (SA-240 Type 41 OS) lattice grid supports. The fan Bar U-Bend support system incorporates sets of SA-240 Type 41 OS stainless steel Fan Bars on each side of the bundle as shown in Appendix A.

Appendix B shows the tube support layout and identification for the CCNPP2 Steam Generators.

Technical Specification (TS) 5.5.9.d provides the requirements for SG inspection frequencies and requires periodic tube inspections be performed. TS 5.5.9.d requires that 100% of the Unit-2 tubes be inspected at sequential periods of 144, 120, 96, and thereafter 72 effective full power months (EFPM).

During the CCNPP2 spring 2019 refueling outage (CC2R23) both Unit 2 steam generators (SG21 and SG22) were inspected in accordance with CCNPP TS 5.5.9. This was the fifth in-service inspection of the replacement steam generators. The SG's had been in operation for 13.145 effective full power years (EFPY) at the time of the inspection.

The next section summarizes the results of the inspection in accordance with the 180-Day reporting requirements of TS 5.6.9. Bold wording restates the TS requirement, followed by the required CC2R23 information.

A report shall be submitted within 180 days after the initial entry into Mode 4 following completion of an inspection performed in accordance with the Specification 5.5.9, Steam Generator (SG) Program. CCNPP2 reached Mode 4 returning from CC2R23 on March 14th, 2019.

The report shall include:

Page 4of22

2.0 The Scope of the inspections performed on each SG (5.6.9.a) o Eddy Current Bobbin probe examinations (both SG's)

  • 100% Full Length (FL) of all in-seivice tubes with a bobbin coil probe for tube-to-support wear at the fan bars and lattice grids and for potential foreign objects and associated wear o Eddy Current Array Probe (both SG's)
  • 100% Array probe examination of all in-setvice tubes from the bottom end of the tube to the 1st lattice grid on both the hot and cold legs for potential foreign objects and associated wear
  • In addition to the 100% of the in-setvice tubes that were examined by Array Probe as mentioned above, the following Array probe examinations were performed, if not already covered by the baseline Array probe scope:
  • Inspect all previous Possible Loose Parts indications (PLPs) (part not removed) plus a one tube bounding examination of such tubes at the elevation of interest
  • Inspect a one-tube border region around all tubes previously plugged for Loose Part Wear (LPW)
  • Inspect a one-tube border region around all tubes previously plugged for PLPs o Special Interest inspection of Bobbin indications and/or Secondary Side Visual conditions with Array probe
  • All new PLPs and foreign object wear indications plus a one-tube bounding examination if the locations are outside the baseline Array probe examination range
  • All foreign objects identified by secondary side visual inspection plus a one-tube bounding examination of tubes surrounding the foreign object if it falls outside the baseline Array probe examination range
  • Twenty deepest Fan Bar Wear (FBW) bobbin indications in each SG.
  • Ten deepest wear indications detected at lattice supports in each SG (or all if there are less than ten)
  • A sample of Manufacturing Burnish Marks (MBMs), Dents (DNTs}, and Dings (DNGs) as directed by BWXT or CCNPP Engineering o All bobbin probe I-codes o Special Interest inspection with +Point'
  • All newly-reported array probe PLPs o Visual Examination
  • Visual inspection of all installed tube plugs in both SGs in accordance with the EPRI PWR Steam Generator Examination Guidelines, Rev 8 (section 6.10). This included both welded and mechanical plugs.

Page 5 of22

  • Visual inspections of the hot and cold leg channel heads including the divider plate/tubesheet interface, the entire bowl per NSAL 12-1 methods for evidence of cladding degradation and/or cracking.

o The following secondary side inspections were performed (both SG's unless otherwise stated)

  • Secondary side visual inspection of tubesheet, the annulus, and the no-tube lane regions looking in-bundle into the high flow regions.
  • Secondary side visual inspection of the 1st lattice grid support
  • Targeted top of tube sheet inspection locations identified as PLP by eddy current
  • Visual Upper Bundle U-bend inspection (SG22 only)
  • Feedring, J-Nozzles, Primary Moisture Separators inspection (SG22 only)
  • Visual inspection of secondary moisture separators (SG22 only)
  • Laser profilometry of the secondary moisture separator baseplates (SG22 only) 3.0 Degradation mechanisms found (5.6.9.b)

Three degradations mechanisms were confirmed to be present in the CCNPP U2 SG's.

These are: 1) fan bar wear, 2) lattice grid support wear, and 3) foreign object wear. No other degradation mechanisms, including tube-to-tube wear, were detected.

The visual inspectio.n of the cladding, previously installed plugs, and divider plate found no degradation.

The secondary side visual inspections of the upper bundle, 1st lattice grid support, and SG22 steam drum and primary moisture separators found no degradation.

4.0 Nondestructive examination techniques utilized for each degradation

-mechanism (5.6.9.c)

The bobbin probe was used as the primary means of detecting tube degradation except for loose parts/wear located between the Top of Tubesheet (TTS) and the first lattice support. At this location, the Array probe was used for the primary means of detection, along with detection of TTS expansion transition IGA/SCC and pitting (proactive examinations). The rotating coil probe was used primarily as a diagnostic tool for indication characterization.

Table 1 below identifies NOE examination techniques utilized for each identified degradation mechanism.

Page 6 of 22

Table 1 - NOE Techniques Utilized for Sizing Identified Degradation Degr~dation Inspection Typt;, .EPRIETSS Mechanism * ' .

Fan Bar Wear Bobbin 1-96041.1 Foreign Object Wear* Array 17901.1**

Lattice Grid Support Wear Bobbin (%TW depth) 96004.1 Array (length) 11956.3

  • The Array probe was the primary means of detecting and sizing foreign object wear during the inspection. However, the +Point' probe was also used for further characterization and sizing of wear for trending purposes.
    • There are other EPRI techniques qualified for sizing of foreign object wear depending on the shape of the flaw. ETSS 17901.1 was selected based on the circumferential groove characteristic of the foreign object wear indications detected during the CC2R23 inspection.

5.0 Location, orientation (if linear), and measured sizes (if available) of service induced indications (5.6.9.d) 5.1 Fan Bar Wear Fan bar wear (FBW) is a mechanical degradation process which produces volumetric tube wear at the interface between the U-bend anti-vibration supports {fan bars) and the tubes. A total of 421 FBW indications were identified in the Calvert Cliffs Unit 2 RSGs during CC2R23. Fifty-nine (59) of the indications were newly reported during the CC2R23 outage. There were 13 and 46 new indications in SG21 and SG22, respectively.

It should be noted that the total quantity of indications decreased in both steam generators compared to the previous inspection in CC2R21. This decrease is attributed to the change in the reporting threshold for fan bar wear. The reporting threshold was increased from 5%TW in CC2R21 to 7%TW in CC2R23. Therefore, the indications that measured 5%TW and 6%TW in CC2R21 weren't reported again in

.CC2R23 unless they measured at least 7%TW in CC2R23. Considering only those indications greater than or equal to 7%TW, the total number of indications still increased slightly from 393 indications in CC2R21 to 421 indications in CC2R23.

Table 2 provides a summary of the fan bar wear indications from CC2R23. The maximum depth among these indications was 28% TW, which is consistent with results from previous inspections. Growth of the repeat indications was minimal and consistent with previous results.

Page 7 of 22

Figure 1 provides the distribution of fan bar wear depths for both steam generators as reported with the bobbin coil probe . As shown in the figure , SG22 contained more indications. Most of the indications in both SG 's are less than 20% TW .

Figures 2 and 3 provide tube map locations of the reported FBW . Although the tube maps shown in Figures 2 and 3 provide a view of the tubesheet primary face from the hot leg side, both the hot leg and cold leg FBW indications are included on each map.

Most of the wear continues to occur in larger U-bend radius tubes clustered towards the center-most tube columns.

Appendix C provides a complete list of FBW indications reported in CC2R23 .

Table 2 - Fan Bar Wear Indication Summary Description SG21 SG22 Total Number of In-Service Tubes Prior to CC2R21 8434 8439 Number of FBW Indications 134 287 Maximum Depth of FBW (% TW) 25% 28%

Number of TSP Wear Indications ~40% TW 0 0 Number of Newly-Reported Indications 13 46 Number of Tubes Plugged due to FBW 0 0 Figure 1 - Distribution of Fan Bar Wear Depth 80 20 0

Depth in Percent Throughwall Page 8 of 22

Figure 2 - SG21 Fan Bar Wear Map 140 120

~ 100

.0 J

J ** . .

40 .

0 0 40 80 120 140 160 Column Numl)@r Figure 3 - SG22 Fan Bar Wear Map 1'10

  • Tubes With lndic.at1ons 120 ~

~ 100

.0

  • j I 80 1

.

  • J
  • I
  • I 20 I

(I . . _ __ _ _ --+--'

I 0 20 40 60 8 100 110 140 160 Column Number Page 9 of 22

5.2 Lattice Grid Support Wear Three indications of wear related to the lattice grid supports were reported during the CC2R23 outage (two indications in SG21 and one indication in SG22). All three of these indications had been previously reported and were inspected with array probes to confirm that the morphologies of the indications were consistent with lattice grid wear and not some other damage mechanism such as foreign object wear. No new indications of lattice grid wear were reported during the CC2R23 inspections. Table 3 provides a listing of these indications.

Table 3 - Summary of Lattice Grid Support Wear Indications

  • Bobbin SG **Row Col Location Axial Extent Depth SG21 131 65 07H +0.52 11%TW 0.28" SG21 137 91 03H -1.50 11%TW 0.26" SG22 102 30 02C-1.43 13%TW 0.28" 5.3 Foreign Object Wear During the CC2R23 inspection, 22 foreign object wear indications were detected in 18 tubes.

These indications were reported as LPW (Loose Part Wear) in the eddy current database.

One of the indications (R121-C117 in SG21) was newly reported. Both eddy current and visual inspections of the surrounding locations concluded that the part that caused the wear is no longer present. The other 21 indications had been reported in the previous inspection during the CC2R21 outage. These legacy indications also have no part present based on eddy current and/or visual inspections of the affected and surrounding tubes.

All these indications were sized with array data using EPRI ETSS 17901 .1. This was the first use of the array technique for sizing of foreign object wear at Calvert Cliffs Unit 2. In the previous CC2R21 outage, foreign object wear indications were depth sized using +Point' ETSS 27901.1. To do a valid growth rate comparison, the array data from the CC2R21 outage were reviewed to determine the array depths from CC2R21 to use to compare to the array depth found in CC2R23. Since the parts were no longer present, as expected, there was no noticeable change in the depths of these indications.

All these LPW indications were sized below the site plugging limit. Since no objects were present to cause further wear and all LPW %TW were less than the 40%TW Tech Spec.

plugging limit (5.5.9.c), all 18 tubes were returned to service.

Table 4 provides a summary of the foreign object wear indications detected in the Unit 2 RSGs.

Page 10 of22

Table 4 - Summary of Foreign Object Wear SG Row Col

  • Location %TW Axial Extent (in.) New in2019 SG21 12 66 TSH +0.10 28 0.18 No SG21 12 66 TSH +0.38 22 0.31 No SG21 12 162 TSH +0.05 30 0.15 No SG21 13 65 TSH +0.05 25 0.15 No SG21 14 66 TSH +0.44 17 0.23 No SG21 14 66 TSH +0.44 14 0.23 No SG21 72 146 TSH +0.23 34 0.23 No SG21 75 147 TSH +18.11 18 0.20 No SG21 77 147 TSH +17.63 18 0.23 No SG21 77 149 TSH +20.72 20 0.28 No SG21 121 117 TSH +0.61 21 0.28 Yes SG21 137 73 TSC +14.98 18 0.38
  • No SG21 137 75 TSC +14.43 25 0.38 No SG21 137 75 TSC +14.76 16 0.36 No SG22 14 4 TSC +0.48 26 0.38 No SG22 17 1 TSC-0.05 19 0.33 No SG22 18 2 TSC +0.18 22 0.26 No SG22 82 42 04H -1.33 26 0.20 No SG22 112 82 04H +37.85 21 0.33 No SG22 124 116 TSC +12.76 14 0.20 No SG22 126 116 TSC +12.56 18 0.23 No SG22 126 116 TSC 12.84 33 0.33 No 6.0 Number of tubes plugged during the inspection outage for each active degradation mechanism (5.6.9.e)

Zero (0) tubes were plugged during the CC2R23 outage.

7.0 Total number and percentage of tubes plugged to date and the effective plugging percentage in each steam generator (5.6.9.f)

Table 5 provides the post CC2R23 outage tube plugging status of the CCNPP2 SG's. There are currently 37 tubes plugged in SG21 and 32 tubes plugged in SG22.

Page 11 of22

Table 5 - Tube Plugging Summary SG Tubes Installed Tubes plugged to-Date SG21 8471 37 (0.437%)

SG22 8471 32 (0.378%)

Total 16,942 69 (0.407%)

There are no sleeves installed in the CCNPP2 steam generators, therefore the effective plugging percentage is the same as stated Table 5 above.

8.0 The results of condition monitoring, including results of tube pulls and in-situ testing (5.6.9.g}

The condition monitoring assessment is summarized in Figures 4 through 6. These figures provide the condition monitoring limit curves corresponding to the NOE sizing technique employed for each degradation type. All reported degradation falls below the applicable condition monitoring curve and therefore satisfies the Technical Specification structural performance criteria. No tube-pulls or in-situ pressure testing were required.

8.1 Fan Bar Wear EPRI Examination Technique Specification Sheet (ETSS) 96041.1 was used for depth sizing of fan bar wear. Based on the sizing parameters for this technique, the CM curve shown in Figure 4 was generated and documented in the CMOA. A minimum of the twenty deepest indications in each steam generator were inspected with array to validate the flaw shape and length assumptions. The longest of these deepest flaws measured 1.55 inches with array.

Most of the indications were tapered, but a few indications had relatively flat profiles.

The indications that were inspected with array were plotted at their total length as measured with array probes. All other fan bar wear indications detected by bobbin were conservatively plotted at a bounding axial length of 1.8 inches based on current and previous length sizing of the deepest indications. Since some of the indications were flat, all indications were conservatively plotted using the maximum bobbin depth as opposed to the structural (or burst-equivalent) depth. As shown, all indications lie well below the CM curve. Hence, structural integrity of the fan bar wear indications is demonstrated.

8.2 Foreign Object Wear EPRI Examination Technique ,Specification Sheet (ETSS) 17901.1 was used for depth and length sizing of all foreign object wear indications. Based on the sizing parameters for this array probe technique, the CM curve shown in Figure 5 was generated and documented in the CMOA. As shown, all 22 indications lie well below the CM curve. Hence, structural integrity of the foreign object wear indications is demonstrated.

Page 12 of22

8.3 Lattice Grid Wear EPRI Examination Technique Specification Sheet (ETSS) 96004.1 was used for depth sizing of lattice grid wear. Based on the sizing parameters for this technique , the CM curve shown in Figure 6 was generated and documented in the DA. Since all three of the lattice grid wear indications were inspected with the Array probe, the lengths measured from the Array inspections are reflected in the figure. As shown, all 3 indications lie well below the CM curve.

Hence, structural integrity of the lattice grid wear indications is demonstrated.

Figure 4 - Condition Monitoring Results for Fan Bar Wear

.100 Note: CM lim1t c1,1rve is b.tsed en slJuctur Ieng hs 90 and depths lndica *on depU,s are co servatively p tted using aximum dep hs rro bobb"n.

Indication Ieng hs are conserva ~*elyplotted as the - CM Limit (Bo in; 960.11 .1) total length for ff.aws that we1e fl.triJ y t e$ied Of a 80 bounding 1 8" for fl ws thal w re no! array t te<I.

Fan Ba r Wur lndlcat,ons 70 ii

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Page 13 of 22

Figure 5 - Condition Monitoring for Foreign Object Wear 100 90 Note* CM limit curve is bas~ on swctural lengths and depths lndica ions are conservat ly plo ed using total Ieng s and - CM m1t (Array; 7901.l) 80 m mum depths. In add, n. as d seussed In Section 5 o. al indications i ngths less than 0-25" are conservatively plotted a l 0.25".

[

  • Fcre,gn Object Wear lnd1ca ons 70 ii

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60 8

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ti 50

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.sQ. 40 0"

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Page 14 of 22

Figure 6 - Condition Monitoring for Lattice Grid Wear 100 te : CM limit curve LS ba s.ed on structural ng hs and depth s. Indica !lo ns a re conserva ti...ety p tted us* total lengths fro array and milxi um deplhs from bobbin. - CM U It !Bobbin; 96004.1) 80

  • Lattice G *d e ar Indica ions iO
.c

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0 0.2 0 .4 0.6 0.8 l 1.2 1. 1.6 18 2 8.4 Operational Leakage Crite rion and Validation of Previous OA The operational leakage criterion was also satisfied by the absence of any measureable primary to secondary leakage since the previous inspection.

The results of the 20 19 (CC2R23) inspection and the condition monitoring assessment confirm that the 2015 (CC2R21 ) operational assessment was appropriately bounding .

Page 15 of 22

APPENDIX A - Typical U-Bend Support System CLAMPING BARS BE TUBE IN PLANE DIRECTION

'ruBE OlTT OF PL.Al FLAT BAR DIRECTION U-BEND RESTRAINTS Page 16 of 22

Appendix B Calvert Cliffs U-2 Tube Support Layout

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APPENDIX C - CC2R23 Fan Bar Wear Summary Table C-1: SG21 Fan Bar Wear Summary

-* -----~*----

'Row ;Coll% TW Support'lnch

  • -*-*-~- ___ *...,._ -- -~--**-,

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}  ; . . .,

i .. 5(_98~_. ___(_. __F05' _-1.94: [~-~~~sL:1~~-~~-. 7!

10; F05. 1.95, ; Bi. 97 87: 93: 12i rnsl 1.73/

. ,___ '",,_ __,..___ --*- ~--*- --... ,)_ ---- --* ~ --*-*+' ""' *----~--- .

9, F08 1.87

~-Fosti93i

~ 1:!:~:-~1~t~ ::: :~: :

101; 75'. 19: F06: -0.63

,...... ---~*; so: --*-. sol.:---" ....... ----*>** 7, FOG, 0.61: ;

-~ *- ~*! ~ ... -~

88; 76:; . ____ ,. **;* ........ -

FOs: 1.s L101 _75'___ isl_ ___ FOi _L2si 1

  • ~--------- 73;r---***-\ 45; *-*----~-,; 8 *--~-------F06. -0.77 88'. 78 F06' 1.09 i 101\ 75( 7
    • F09; -1.41:

--~---~~---. .--~ -----*-1-* .. -*-----,.,~;

__ ?:!~J~;-------~t--------~Q.8-:***l:?.§_: ,____ s9: __1s; 1

__ 15; _________ F06'. ... -O,?i  ;.. 101_79:----9; ____J06~-0.66i

, 75' 75, . . s; FOB: a.BG, ' 89 75: 8* Fos* o.s1:  ; 101' 79, 8 F07, 1.75;

_JEtJf. _ ... t . . . . .fQ!i -0.79 i_ --~t. ?.7-'... ~i__ -~Q( J~9.;  ! 101! 791 . 10* .. F08! 0.84i i;-~*--101; sf . . ------~-"' t; ---~---F07;

' i_____77j 75;

,_____ ..................... 1: FOB',_,________

-..- ............. 0.84:, ,--- / -------~go: ..........

74:,... **-**---.*--*---*--------,------------1 9: F08: 1.88; --.~-~---; -----w -0.83 ----. j l

  • --*~-"""-~*-.--~-..

77; 79:-:--*-*,~--*- 13:.- ---*-,--*

1 Fos--,---**""'-*-~;

o.si: :1~~,..-~---~,*~*-*---_,_~.---~---:

go: 76 T --*--~~-~--,.~*"'

F07:*---"""~*-**<*"'

-0.79,  ; 101, 83. 10 F07: -0.05,

. 77; _?} ____ gi --------~2?... Q:~9.: !-_,_91:_ 75; ____ s: _____ FOB:_ 0'.79: ' 101: 83 ... lOr F081 -0.18 5 i 79; 45\ 12: F06: -0.72: . 92: 78; 14; FOB 1.7i  ! 10{ 87 9] F06i -1.58;

  • ~~::--- .:'.--~~: -:~:~~ r ~~~, _g: -{~ -}~ r\ 102: 90: 101'. 87; 12; .. . F07; 0.75'.
. ****-*-~--,t. ... -._,.._, ______,,__ --**, "' -~- ___ ,,.., ___ ;---*-"~"---;
10. FOG: -0.75.

soi 76;

. 10f

-** ~....... ~~, -* -"~- ...-~: ~.

F07~ -0.83:

~-----~-- ~"~ ' " --~-- .~

  • -*-93 --87______

1

-*Fos' -i.1ii: !__103'._79: _______ 9

  • _

1

. FOB;. O.T!__;

80
78: li F08: 1.83' , 94 74. 9: FOG; -1.67; i 103 83' 11: F06' 0.5 i ___ s1f _s1~ ____ 7~- .. Fo(-1.1E  ; __ 94;_1s;_____ 16; _____ FOs: _1.s3; i 103 87: 9'. FOG' -1.67
.......?.1
'_J_t __ *--~: -*-- F081_0. 78  ; 94. 82 11 F06* -1.74.  !*1oi1 8l
  • 14'.
' - - - * - *
* .- --: ~ -,~,.,., *--~~ '. = .._.

F07; o.63:

,,-,--,*-"t-~w*~*-,-*-- ~

. 81; 79, 14, FOB: 0.76'. l_... 95r_77!. . __ s; _______FOGi-1.69: '. 104; 78' r------~-------: -**--**+----*-*-------. *-*-*-*-'

9, F07; 0.82

. 81
97: 7'. FOB: 1.82; ;____95 _83: ___ 9+- ___ F08i__ -0:59 i 104' 78; _ 7 ___ F08, 1.89:

.k~-~.-..-~--..-~--*: --- .....""~ ,--.,..--~--~t. . **~*-*-*-",

,_:__s2. !!?.>-** !~: ----~9§1.....!: s~; i gs 87, 20 Fos:;~,--,..._..~,..,.,-'i

""*--~~~,-- ..-.....- ; *nes*--"**'~""'t..,_.._,*~--*"""'-*,___,..

1.71; !r-~**-*-*

104.--"-.84 1

~*-+--~----..- 9\,---,~ ***~-~***---"*--*+* Fosi ..-----.. -0.61 *

\

'. 83 1 Gi FOS -1.31 1

'---;---; ~----T:--***-~-***--*--*---*: F08 0.79'

        • -*---< i 95 87 li F09; 0.79 1 104; 88' 13' i 83: 79
83'. 97 i - - - , ~ ~ " ' ~ - ; - ~ - . -..

1 84: 761 13' s:

F08i 0.77' l.__96;J( __

. FOB: 1.85: ,

  • 97: 67

-~**---- (-~-~ . . .------ ~ .~---~ ..---~

lOi F07l -0. 7fr [ 'JJ7'. 75~------1~ ---- F06\ ____ -0. 71 7L *-*--

1ol Fo~ __ 1.si Fas: o.79  :~:[-:!.~ ~-~

!: ____105'. 79;

,. . . . . ,.___,_.............. 91

~~-r---..<,,-0,.-~~*-*1---~<"'

~~}-~:~~

---*F07:

. . ~*"*--l 1.85:

1 -ss!-*1si-*--s;*----*-Fo11--1.66; i 97: 751

~-*<"~'Y'-<<*--~-.

-*---~"" '----~ -Rt*e*~*---'"*-***--*-*---~"*__....-,.,.' *-* ...,.,....._,_.. ~

10i F07; 1. 76:

~* ~. ***---'"-****J.._ ... ~----*~~-- ~-.. - *. '-*""*-****---.. ~--_.,.__. ___ .,..._,..I

! 10s: 83! 13! F07: -0.02i

~r~***- ** -~~--~*.** o,,<',,.,,__,_, __ ,fy,.-~, m,~--~----* ,.-,.,, _____ ,..

Page 18 of22

Row. Col % TW ,

Support in~h 105.. 87 11 F07 0.75 106 76 20 F06 1.2 106

.. 76 7, F07 .::1.24 ~*~ ..

106: 78 10; F07 0.77 106 90 10-** -~1 *o>

FOG -0.7, 107 75 7 F07 1.8 ..

107 83 10' FOG 0.05 107 83 12 F07, -0.02 107 87 19 F07 0.82 108 74 8 F07 0.7 108 76

..... 25 FOG 1.15 108 90 12.. ; .....

FOG .. -0.75 110 76 7 FOG,. 1.14 ,.

110 88 11

... FOG -0.68 110 90 9 FOG -0.59 111 75 17 FOG -0.7 112 90 13 F06' -0.73 113

.. 87 11 F07 0.75 114 76 15 FOG -0.88 117 89 18 FOG -1.25 119 87 15 F07 0.77 122 88 8 F09 1.81 133 91 12* F02 0.84 Page 19 of22

Table C-2: SG22 Fan Bar Wear Summary Row Col %1W Support Inch , Row Col % 1W Support Inch ; Ro_\tV _f(?I -~!'N- Support Inch

-22;
  • 6, - *- ii: -- ** Fo1 * :o:si'. . 76-i ~~: --11-- --_f_Q~: ~1.86: i 83~ 9;:. 12 F08' 1.88 i - 37* 35: F07 - 1.84 1 76 82 9 F07: 0.82 84 80 9 F06 -1.83*

r-"is~i46:-

r 44: 140' -

9

-9 *-* -

Foi F07: -

-o.s2' ;___ 7~:-~.?J---~~---------~Q~ 1__ -_!:?'.

---0~8- 1 84; __ ss' _____:~(-- _JQ.?_: __ _9:?~:

.~--*'- " . "" **~*

' 76' 82;

-** j -*-. "*;.

g:

  • --- -~- *,""*

F08! 1.93.

    • ---~--- * ......., ** ;_ *--

84; 92 17i F08 0.72!

49. 29'. 7

--* )_

F07: 1.Si;

.-~ ____ __. : ...* --~-~----' i 76 9f3, 9: F08' 0.7 20' F08; 0.79' i t '  ; ' ' -  ! .  ! - ~ - * - * * - * ~ - ,__

57: 51 8 F06' -0.5 77 1 65; 13; F08 O.J: 10' F05: 2.14

. -Gt

  • -*<<*=---*"'-*""~""'\*..

47'. - - - ---FoG* o.

~*

1? . 11'.* 69'. -i;* --Fas' **a:19- s: Fa6: -o.59; F08 1.71: : *- 1i -73'

  • -~,.,;--a*'- -., ** ~ '

1 9. Fos' o.72

61. llf 10 A***'***'" ~*-Y"*,****** -*;"' *******----:* ---"****;

1 64' 2i 10: F05 2.0i'. 77 __ 81:.... ___ § . -- ~_qh -0.87 85 79.

. , *-+- ... i' '

12 F08 0.72'

____ ...,,,, ,, -**~- ~"'""'1 64 26 11' F05: 1.97: 78 __ )_

64: 9' F08'.. "" .... ---*--*

1.89; 85 . 79' -*---=(

s;

-*--* --~ - - ---

F08.. ....

-1.24 64: 142_ 12' F05' 1.96' _78: 82_ 13 FOG: -1.85 86. 72: 8. F05 -0.87!

i 66* 36' 7, F08 -1.73 78, 88 7; i=os'.--Q.74, 86' 72 13 F06' -1.82 '

-Fo6r

'.-- . . . . . --- -*" .1 *.

  • '~-*- _67 21'

_,,. .. t., - **** ..)__

10~-*~-..-* ~o.75: 10 FOG: -0.66: 86- 74 12 FOG -1.89, 67: 141 10 F05- -0.72-  ;,_.

79 ,,,,.. _35 .*... ;.,... . 11. ._- .... ... --~*-*-- F06 .. -0.57: 86 92- 9 F08 0.79:

.F061 -0.59

    • " - \ ,-;.

_ 67143. .

9, 79. 37: 10, F06. -0.59 86. 94 16' Fas. _ o. 7!;

F08 -0.59 79 81'

~~v" ~****-,,., ** * " * * - * ' *-""

13*

F07,

-0.9

, ** -..1. ..* , ...........

  • 87*: --*"s- -.. F06 -0.52 1

70 82 8 F06' -1.85 79 91 - .7-*--- -- F08 ...... .,.1.86 __ __ -*

87, 65 15 F08 0.73 71  ; .

27: 11 F06 -0.59

      • - --*~*M *-- *
79. 93 F08' 1.49'

~--- .-~----**-

87..~-*--*83: .. *-~----

24 F07 -0.04 71 41: 7, F06; -0.66 , 80 64; Fo9: -2.02 , 87 83 18 - Fos_

o'l

71. 109
    • A * < * < < '** 0 9 F05. 0.85 80 80, 8 F06 -1.81 88 76 8 F06. 1.81 72 36' F06: -1.57- 80 82. ___ { ____ .FOG' -1.8 ____ 88 ___ 78~__ 11._: _ FOG -1.09 72 72 10, F08 1.86' 80 82 8 F05. -0.85 88 82; 13* F06 __ 1.37
  • -*-...-.,- . ..,....... --.:, -- -- -*----*---*~-----" *---*-- :

81 63 7 FOB -1.01 88' 82' 7 FOS 1.8i' 1

72 9i 1i F08 0.83 81 91' 8 F08: 1.88 88\ 84 8 F07. -0.88:

73 35 10 FOG -0.61 81125 8 FOG._ -0.7 88 90 i F09 1.97:

73 91 14* F08 1.95 82 38' 8 F06: -0.25 88 92' 10 _XOS' .. 0.7_~;

74 82 8 F07, 0.74 82. 82 8 F06 -1.88 89 65* 16 F08 0.73.

.. -. -**-**--- ~---. - -----~ -*-- ---*, , ~--*- - --- *-* -

74. 82 +>,- -*

8 F08 1.93 '

--* -* \*" **----~-.

82. 82 11:

~'"*,'.*" -* **-"

F07, 1.31 ;-, . . 89- . ~-69 ', **----;....

12, F08 0.81 74 82 10 F06 -1.8 82.. '""'84. ",, 8 FOG. 1.32

_ , 89, 73:, ... ~1- -- F08 0.77:

74 94' 13 F08 0.85 82 84 9 F08 0.85. 89 81 7 F06 -0.8

-****-- - --- . ------- -------- --~*-"*+~-"**-~*-"" --

1 75 73 9 F08 0.76 8 F08 0.81 89 83,

...... . ... ---~-.---;-

8 FOG 0.48

.- ,. *-**w* **** *~**""'""-'*-*.*- .,~_., ___ _ ,- ., *-- --------,-. "'" "i 75 93 7 F08 1.79* 82 94 9' F08'__ ,. '"**--*-1 0.72' 89 83; F07 0.52 --*-'s--1 129 11 F05 -0.7 82126 9: F06' -1.7 89 83 9 F08 -0.61:

75 131

'* -** --~~'----~""_,_,..," -**- ------

7 --- ... -*-

F05 -0. 77 33' 37 £_Q6'.__-Q:.~ i __ ~~:_S,~: ___ 12___ F08: -1.25

___ 75: 139: ----~- ---* -~Q§___ :-q,§§ 83 73 20 FQ.8~ ___0.79 i 90 82 7 _JOG._ -1.85!

64' F08 1.87' F02 0.85' : 90. 112* 9: F06. 1.64, F08 1.86 83 si: 9 * --Fa1*-~1:ii' * - 91 - 65' 22*----- F08 0.1 Page 20 of22

Row Col % TW ., *1

.Support Inch Row _Col %TW Support Inch R_ow, Col % TW Support Inch 91 101. 8 F05 -0.81 100 78 8 F07 0.7 105 87 12 FOl 0.48 91103 7. Fo5** -0.9, 100 ..78 11 FOB -1.9 .... -

106 80

7 F07 1.31 ..

92 76 12 F06' 1.32 100. 82 8 F08 1.84 106 82 14 FOG -1.83 93 73 8 FOG, -0.77. 100 82 16 F07 0.74. 106 82 20 F07 0.8 93 79 ***-.,-

10 FOG

-0.83

-- 100*,? 82 17 FOG -1.29 106 90.. 21 F07.

... 1.21 93 81 8 FOG -0.79. 100 84 7 F07 1.74 ....

107 75 14 FOG -0.81 i  :

93 83 9 FOG 0.48 100 88 11 F07 1.84 107 77 10 FOG -0.81 93 ... 83 9 F07 0.44 101 77 12 F06 -0.81 107 79 8 F06 -0.89 93' 97 8 F10 -0.97 101

.~--.

79 7- '

F07 1.8 107 81 22* FOG -0.79 93 97 9 F08 1.82 101 85 8 F09 1.38 107 81 12 F08 -1.4 94 72 7 F08 1.83,. 102 76 13. F07. -1.34 107 83 12 F07 -0.04 94 .. 76 9 FOG 1.77 102 76 1.0. FOG-* - - 1.69-* .

107 85 12 F09 1.28 94 80 9 FOG -1.83 102. 82 10 F09 ***-

0.78 107 85 9 FOG 1.19- '

94 82 17 FOG -1.32 102 84 7 F07 1.75 107 93 7 F07 0.75 94 82 10 F07. '

0.79 102 86 9 F02-- 0.87 108 74 7 FOG -1.8 94 86 8 FOG- 0.74 102 88: 8 F07 1.79 108 76 7 F08 1.3 94 92 12- F08 0.77 103 77 13 FOG -0.83 108 76 8 F09 0.74 94 94 10 F08 0.72 ..103 79 9 F07 1.81 108 82 12 F09. 0.72 94 108 8 F05 1.81 103 79 10 F06. -0.78 108 82 11 F08 .

1.27 95 81 7 F07 -1.38 103 81 9 FOB -1.41 108 82 20 F07 0.74 95 83 10 F07 0.41 103 81 8 F06 -0.72 108 84 13 F07 1.78 96 80 9 F06 -1.77

... 103 83 16 FOG 0.46 108 84 11 F06 -0.74 96 82 8 FOG 1.25 103 85 10 FOB 1.25 108 86 15 F07 1.2

...96 84 18 F07 1.24 ..

103 87. 10 F07 0.72 ..108 86 25 FOG -1.2 96 86 1 FOG a 103 87 7 F09 0.75 109 75 14 F06 -0.79 97 . 73 ,

7 FOG.. -0.79 104 82 11

.. FOG -1.92 109 77 21 FOG -0.77 97 75 1 FOG -0.84 104 82. 8 F09 ,,0.78 109 79 23 FOG

' .. -0.75 97 77 9 FOG -0.85 104 82 11 F07 0.76 109 81 16 FOG -0.81 97 79 8 FOG

-0.83 104 84 11 F07 1.76 .. 109 81 9 F07 -1.38 97 81 10 F07 -1.31 104 94 18 FOG -1.32 .. 109 81 16 FOB -1.18 98 72 8 FOB 1.85 105 67 10 F07 -1.34 109 85 19 F07. -1.23 98 76 9 F06 1.67 105 ' -

75 10 FOG -0.83 109 87 12 F07 0.75 98 78 7 F07 0.66 105

.. 77 13 FOG -0.81 "

110 78 11 F07 0.75 98 78 13 ....

FOB 1.77 105 79 12 F07 1.84

..110.

82 9 F07 0.75

..98 82 8 F07 0.72 105 79 19 FOG -0.78 110 90 7 FOB -1.45.

98 104 7 FOG 1.35 105 81 14 FOB 1.32 111 73 27 FOG -1.34 99 71 13 F08 -0.76 105 81 7 F07' 1.8 111 75 22 FOG -0.83 99 77 19 FOG -0.79 105 '

81' 9 FOG -0.8 111 77 27 FOG -0.83 99 81 8 FOG -0.76, 105 83 14 F07. 0.44 111 79 10 F07 1.73 100 76 9 FOG -1.93 105 83 8 FOG 0.48 111.

79 17 FOG -0.79 Page 21 of22

RoW . TW\Support ':Inch . fRow :Col.t% TW~$uppdrt 1i~ch j

-~~ * - - ~ .~~-,-- l _,, - ,w,"'"""1:*- *- ---~*-- ,_ * - - .,..,_ -

i 111i 81! . 14 1 F06 1 -0.83: lrm~ 123; 83; 7; FOG! 0.68:

. . . . . ,__._.,....,~,-----1 -~-----,~~,~~ ......... --.--.. . .-----* }~"~,-*----*. . *!

--*- *--' ***--*~*- .... "-***!*-- -*-******-L-........... ;

1 11i 72: 8: F08' 1.76: l 123 1 83' 27i

-- _., __,_, -,--.s-; -~-*--* -*-t-** **n-**----*-J *~------****~'

F07i 0.1Si

! 112; 78: ... 10! . F07; 0.68: i: 124:i 76;*; Bi, F06; 0. 73'.

r  ;

i:*--.112: 86( 11! F06: -1.16, j 124: 82,

>*.P""-:"-~~ . . . . . **, ~ --**--*,,-f...,-,n*-*-**----'-**!- -~--~ :, f ---t . ' -< . ~- -t - . -"' ,..- ,.._ *- -i

='"

7 F09, -1.36:

!; 113: ,_ ~

75i 11!

~ i - " ;** -* ..............._._ ; . __. ----*{

FOG; -0.79: ! 124; 82, 14j F06: -1.36:

t 113: 77; 28: FOG, -0.81; j 12i,- 82~ _____12f_____ F08: -1.47j 1113) _81). ___ 8[ _____ F08t _}.36! , __ 124; 92; ___ 7L. -* FOGi .-o.sG;

\*. ------.

113! **-*- 81 11..... ......... 15:r.. -* -- ......FOfr -1.27: ! 12s! 91!

-r--* -*-" f " i ~

11\' . F03:~ -2.osl; 1

113 83 7: FOG: 0 461 ir----*~1---~*----~+¥---~

." ___ ....,, ....,~.....-+--~-,...,_.'""'.*-**"-*""'""'"'""'~-I,..,,..."""""'_,._ . _.....,.,,":-*~- ,. _.......i 1261 82; . lOi

. . . . 4 ***--ffff _____F07, 1.12:

,,..... ~,-~ 1-.. --~-~--~:

l 113' 83: 11' F07: 0.46!

~- --~~*-** '-- --"~---\... --~----~-/-,., --- -----~~-' ... -~*'"- ---- 1 127; 83'. 7; F07: 0.07:

! ~-113'._:-

91i( .

201*; _,,..

FOi---}**

-2.26'.

~_1281--92; ____ 121 ___ JosL-1.29{

114. 7S: 8i F07i 0.71 l 130, 92 12l FOG; 1.8:

-~~:\ '".?2 ;' __ ~ )Q!' ______£CI~L-~:_??.i l  :

L_131\_1s1 __ 9: ______ FoGi_-1.01 1

,; 114. 84: 15;t FOG; -1.2. i 131( 103 1 9' F03: -0.42;

__,,,,....... , .. ,,., ;*** . ' y* -~  : ---*--*-- '" --*r"**~-* .,. __ ; .._. _ -*--"'~-----~~-:------*-*\

114, 88. 17: FOS' 1.34: 1 13i 761 7;. FOB: -1.27)
- 1 . i  ! ,- . 1

, 114, 92, 8 FOG; -0. 75 j 132; 92' 10 F03: -2.03'

~ -~~: _~~~ - :;-_~_ :~~:

i 115: 81 l '

7:

l

-:~:~

FOG 1.19.

1 135; 83;. 11L__ . F07: __ 0.01;

\ 11s: 83; 9' F06; OA6

'"' ~- --.... -,..,~-; ~---~- ,~ -"*---****--~-.-**** '

l 115' 83 9'.

\----~--*---~*--*** - -----~---.* '****-->>s*-.-*-----*-*-* _______ , __..,..., '

FOi 0.44:

!_ us; . .93:.. ..11; ...... Jo1;_ a. 1s:

!__ u6; __ 8?, . ____ 21t __ ~Q?., .1.*.?~.

116 84: 11 F08* -1.96' u~~:- ~c . ~i ~:~ -o-~:
111* 83'. 18:

t-**'"'-"--* }-*-*-- ;~-*"""*-*-;-*----*-*~-----; --**------**i FOG: -0.04

'.. --*-~*,*--~.

1171 *-- --~' 83 .......-~. 7, FOT 0.48

.-~* -------- --*---*,--. -~ __ *-*---.

.,._ ~~

117l 91) lt F07; ____ 1.35 1
118' 80; / F06' 0.77

(. _11R . 84; ... -1;____ _F07~ ___l.64:

i 119, 81. 12, FOG, -0.75:

-*-*.s.-~-,..,;--*, ~~*-

  • u., .. , - , , c u - , .. -*~**-c,,-..,_.,.,,_,.-,,,...*..;f;.-.,,~-*~-' ... ~,*

11' 1

120; 88: F08: -1.2

,*--- ~.-~--;-. **---**
***-* --*--* -:- .. **-* **-'"---~

l 121: 83. 10: FOB' 0.44 ir------121i -r -*-* i 87: . 8: FOJ'. . 0.77;

    • -----* ___ ,, ** - -~--... -, ...---~-~- 1 .. -**--~-~...--,

/122 .. 74; _____ 8_; __ ... FOT 0.66~

lt*-"*****122l 76; 10, FOs' -0.12'

~*~-- '""' -- *~ -'~"'*--.-.-,~,,.. ;,,,_..,._,~--.,..,.,,.-,~,-,,, w_,_._.,.,,...,_.h; i 123; 77, 8; FOG'- -0.81:

L 123; __ si: ____ 11:. ___ _Fo11_).54; Page 22 of22

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