L-2009-091, Steam Generator Tube Inspection Report

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Steam Generator Tube Inspection Report
ML091120207
Person / Time
Site: Saint Lucie NextEra Energy icon.png
Issue date: 04/13/2009
From: Katzman E
Florida Power & Light Co
To:
Document Control Desk, Office of Nuclear Reactor Regulation
References
L-2009-091
Download: ML091120207 (17)
v • d • e


Text

Florida Power & Light Company, 6501 S. Ocean Drive, Jensen Beach, FL 34957 April 13, 2009 L-2009-091 10 CFR 50.55a FIPL 10 CFR 50.36 U. S. Nuclear Regulatory Commission Attn: Document Control Desk Washington, DC 20555 Re: St. Lucie Unit 1 Docket No. 50-335 Refueling Outage SL 1-22 Steam Generator Tube Inspection Report Attached is the St. Lucie Unit 1 Technical Specification 6.9.1.12 steam generator tube inspection report for the Fall 2008 refueling outage (SL 1-22). This submittal was made within 180 days after the initial entry into hot shutdown following the completion of the steam generator inspection that was performed in accordance with TS 6.8.4.1, Steam Generator (SG) Program.

Please contact Ken Frehafer at (772) 467-7748 should you have any questions regarding this submittal.

Very truly yours, Eric S. Katzman Licensing Manager St. Lucie Plant ESK/KWF Attachment 4 - 'I-K A Co an FPL Group company

L-2009-091 Attachment I Page 1 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

BACKGROUND The St. Lucie Unit 1 steam generator (SG) tube inspection program for the fall 2008 refueling outage (SL 1-22) was conducted in accordance with St. Lucie Unit 1 Technical Specifications Section 6.8.4.1. The SL1-22 examination was the third planned inspection and the sixth refueling outage (RFO) of the first ISI period for the replacement steam generators (RSGs). SL1-22 was the last scheduled inspection in the first period and it occurred at approximately 99.7 effective full power months (EFPM) into the first period of 144 EFPM. The examinations performed during SL 1-22 met the inspection requirements of examining 100% of the tubes by the end point of the first period. The examinations also satisfied the minimum requirements of EPRI Final Report 1013706, October 2007 "Steam Generator Management Program: Pressurized Water Reactor Steam Generator Examination Guidelines: Rev 7".

The St. Lucie Unit 1 steam generators were replaced in December 1997 with Babcock & Wilcox Industries Ltd. (BWI) advanced series pressurized water reactor (PWR) RSGs.

The SL1-22 SG tube Eddy Current (ECT) inspections were conducted on both 'A' and 'B' SGs and consisted of the following:

a. The scope of inspection performed on each steam generator
  • 100% Bobbin Coil Probe
  • Screening of all dings/dents < 5.0 volts in the freespan straight lengths
  • Screening of peripheral tubes for reduced tube to tube gap spacing (increased tube proximity) in the u-bend region
  • +PointTM Rotating Probe All hot leg (H/L) and cold leg (C/L) expansion transitions along the periphery and no-tube lane were examined for foreign object ,wear to the extent of +3.0" to -

2.0", as referenced from the top of the tubesheet.

  • Examination of tight radius u-bends in Row 3 (approximately 50% in each SG).
  • Examination of tight radius u-bends in Row 2 (approximately 72% in 1A SG and 57% in lB SG).

50% of hot leg Dings/Dents > 5.0 volts in the straight freespan sections were included.

  • All Dings/Dents in the u-bends and at hot leg tube supports were included.
  • Diagnostic examinations were completed as required based on the results of the bobbin test.

Approximately 10 tubes in each SG displaying the greatest response indicative of increased tube proximity identified by the bobbin coil probe were completed.

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

L-2009-091 Attachment I Page 2 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

The visual examination completed during the SL1-22 refueling outage consisted of:

  • Visual examination of the 14 previously installed tube plugs in SG 1A for location and condition assessment was completed.
  • Visual examination of the hot leg nozzle inner radius in steam generator SG 1B was completed

" Secondary Side Inspection (SSI) which included Upper Bundle Flush, Sludge Lancing, and FOSAR (Foreign Object Search and Retrieval) was completed in both steam generators (SGs).

TABLE 1 BASIS FOR TUBE EXAMINATIONS Technique Examination Sample Required or Basis Potential Supplemental Degradation 100% full length of all active Required Technical SpecificationWear tubes in each SG 6.8.4.I.d.2 Bobbin Screen all dings/dents < 5.0 volts Required (stress PWSCC in the freespan straight lengths unknown) Degradation Assessment ODSCC Screen U-bends periphery tubes Subject of Vendor for proximity of adjacent tubes Supplemental Bulletin None All HL & CL expansion Foreign Object transitions in peripheral high Required Procedure Commitment O Wear flow regions Tight radius u-bends -

0 50% of Row 3 in each SG

  • 72% of Row 2 in SG 1A Supplemental Supplemental None
  • 57%of Row2 in SG IB 50% of ilL Dings/Dents > 5.0 PWSCC volts in the straight freespan unknown) Degradation Assessment sections ODSCC All Dings/Dents in the u-bends Required (stress PWSCC and at HL tube supports unknown) Degradation Assessment ODSCC Test largest bobbin proximity Supplemental Subject of Vendor indications in U-bend Bulletin None

L-2009-091 Attachment 1 Page 3 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

b. Active degradation mechanisms found The SL 1-22 examination results for St. Lucie Unit 1 identified mechanical wear degradation at the following locations:
  • Fan bar and connector bar tube contact points in the u-bends
  • Horizontal lattice grid tube contact points
  • Slightly above hot leg top of tubesheet, due to presence of a foreign object (foreign object was removed)

The wear degradation at tube supports is not considered active. Wear indications due to a foreign object is also not considered active because the foreign object was removed from the steam generator.

There were no indications of tube degradation in the +PointTM rotating coil examination of the U-bends and dings/dents. There was no evidence of corrosion degradation. There was also no degradation associated with the visual inspection of tube plugs or the hot leg nozzle inner radius in SG1B.

L-2009-091 Attachment 1 Page 4 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

c. Nondestructive examinations techniques utilized for each degradation mechanism Table 2 - St. Lucie Unit 1 Examination Techniques for SL1-22 (October 2008)

Industry Damage Demonstrated Extended Depth Sizing Site-Specific Review Technique Qualification Mechanism Applicability Applicability Technique Deemed Acceptable Detection Sizing Applied Differential Mix I Bobbin 96004.1 Wear Structures None Amplitude Yes For Service Revision 11 Analysis (Using Vert-Max)

Absolute Mix Contingent 2 Bobbin 96004.2 Wear Structures None Yes Sizing of Revision 11 Analysis (Using Vert-Max) Wear Structures, Freespan Freespan AmplitudeYe Differential Mix Singo Contingent 3 +PointTM 96910.1 Wear Broached PLP Wear Analysis Yes Sizing Wear of Revsrupports (When Part (Using Vert-Max)

Present)

PLP Wear Typically 4 Bobbin 27091.2 PLP Wear PLP Wear (When Part N/A Yes Use Revision 0 (part not present) Present) Technique Present)#11 24013.1 Axial Freespan, 5 Bobbin Revision 2 ODSCC Dings None N/A Yes N/A

< 5.00 Volts Frequency Contingent Cnign 6 +PointTM 21998.1Single 6e 421998.1Volumetric Freespan None Singe Frequenc Yes Sizing of M Revision 4 Phase Analysis Wear Dent / Ding 7 +PointTM 22401.1 Axial Dented Support Freespan Single Frequency Yes For Info Revision 4 ODSCC Structures & Phase Analysis U-bend Dent / Ding Yes For Info 8 +PointTM 22842.3 Revision 5 Circ ODSCC Dented Support Structures Freespan

& Phase Frequency Single Analysis U-bend 96701.1 Circ PWSCC Expansion Dents Single Frequency Yes For Info 9 +PointM Revision 12 i WTransition Dings Phase Analysis 10 +Point TM 96703.1 Axial Dents Freespan Single Frequency Phase Analysis Yes For Info Revision 17 PWSCC 27901.1 27902.1 27903.1 PLP Wear TM nt 27904.1 Morphology PLP Wear 11 +Poin 27905.1 PLP Wear Dependent None Morphology Yes For Service (part not present) Dependent 27906.1 27907.1 (All Rev. 0) 96511.2 Axial & Circ Low Row Single Frequency 12 +PointTM Revision 16 PWSCC U-bends None Phase Analysis Yes For Info

L-2009-091 Attachment 1 Page 5 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

d. Location orientation (if linear) and measured sizes (if available) of service induced indications St. Lucie Unit 1 SG IA SL1-22 Wear at U-bend Fan bar and Lattice nrid locations Indications 1-19% TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 71 100 0.16 140 P3 TWD 16 F05 +0.82 TEH TEC 64 COLD 610UL 71 112 0.12 124 P3 TWD 8 F06 -1.63 TEC TEH 7 HOT 610UL 77 92 0.19 100 P3 TWD 16 F09 -2.31 TEH TEC 1 COLD 61OUL 79 92 0.15 127 P3 TWD 13 F09 -2.16 TEH TEC 1 COLD 610UL 84 99 0.14 134 P3 TWD 13 F06 +1.29 TEH TEC 1 COLD 610UL 88 93 0.13 118 P3 TWD 12 F04 -0.60 TEH TEC 1 COLD 610UL 91 78 0.24 129 P3 TWD 18 CBC +1.89 TEH TEC 1 COLD 610UL 92 77 0.12 113 P3 TWD 11 CBC +0.40 TEH TEC 1 COLD 61OUL 95 92 0.18 104 P3 TWD 15 F09 -1.96 TEH TEC 1 COLD 610UL 97 92 0.13 120 P3 TWD 12 F09 -1.98 TEH TEC 1 COLD 61OUL 97 144 0.10 155 P3 TWD 7 01C -1.24 TEC TEH 15 HOT 610UL 0.21 76 P3 TWD 14 02C -1.50 TEC TEH 15 HOT 61OUL 99 78 0.25 161 P3 TWD 19 CBC +1.93 TEH TEC 1 COLD 610UL 102 111 0.14 98 P3 TWD 12 F06 -1.06 TEH TEC 1 COLD 610UL 103 92 0.14 100 P3 TWD 12 F09 -2.02 TEH TEC 1 COLD 61OUL 107 106 0.13 128 P3 TWD 10 F05 +1.30 TEC TEH 6 HOT 610UL 109 122 0.14 150 P3 TWD 10 F05 +1.55 TEC TEH 13 HOT 610UL 113 88 0.26 129 P3 TWD 18 F06 +0.75 TEH TEC 10 COLD 610UL 0.18 122 P3 TWD 14 F06 +1.10 TEH TEC 10 COLD 610UL 114 75 0.22 118 P3 TWD 17 F06 -0.93 TEH TEC 1 COLD 61OUL 115 78 0.13 138 P3 TWD 12 F10 +2.07 TEH TEC 1 COLD 61OUL 115 82 0.20 130 P3 TWD 16 F05 +0.91 TEH TEC 1 COLD 610UL 119 58 0.14 119 P3 TWD 12 F06 -0.68 TEH TEC 5 COLD 610UL 128 51 0.10 84 P3 TWD 9 F10 +0.58 TEH TEC 4 COLD 61OUL Total Tubes  : 22 Total Records: 24 NOTE: There are no wear indications measuring > 20%, or other indications that meet the reporting criteria in SG IA St. Lucie Unit 1 SG 1B SL1-22 Wear at U-bend Fan bar and Lattice grid locations Indications 1-19% TWD ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 2 127 0.13 82 P3 TWD 10 05C +0.69 TEC TEN 66 HOT 610UL 28 5 0.09 129 P3 TWD 10 F05 +1.56 TEH TEC 36 COLD 610UL 73 68 0.16 140 P3 TWD 11 F05 -1.03 TEH TEC 37 COLD 610UL 81 102 0.18 120 P3 TWD 16 F04 -1.98 TEH TEC 36 COLD 610UL 97 '144 0.10 145 P3 TWD 8 05H +1.42 TEH TEC 48 COLD 610UL 110 91 0.11 63 P3 TWD 11 F06 -1.37 TEH TEC 36 COLD 61OUL 114 51 0.12 141 P3 TWD 12 F05 -1.32 TEH TEC 36 COLD 61OUL Total Tubes  : 7 Total Records: 7 NOTE: There are no wear indications measuring > 20% in SG lB. Other indications (Loose Part Indications) that meet the reporting criteria in SG lB are listed in the next table.

L-2009-091 Attachment 1 Page 6 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

St. Lucie Unit 1 SG 1B SL1-22 Loose Part Indications (LPI) (Confirmed as WAR bv +PointTM rotatina vrobe)

ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 137 78 0.26 101 2 WAR TSH +0.42 TSH TSH 29% 27901.1 62 HOT 610PP 0.28 123 P1 LPI TSH +0.44 TEH TEC LAR 17 COLD 61OUL 0.69 49 7 PLP TSH +0.64 TEH TEC LAR 17 COLD 610UL 138 77 0.58 99 2 SVI TSH +0.12 TSH TSH 62 HOT 610PP 0.22 83 7 PLP TSH +0.24 TSH TSH LAR 62 HOT 610PP 0.68 75 2 WAR TSH +0.72 TSH TSH 49% 27901.1 62 HOT 610PP 0.90 269 7 PLP TSH +0.73 TEH TEC LAR 16 COLD 61OUL 0.37 116 P1 LPI TSH +0.75 TEH TEC LAR 16 COLD 610UL 139 78 0.14 103 2 WAR TSH +0.62 TSH TSH 22% 27901.1 62 HOT 610PP 0.20 142 P1 LPI TSH +0.53 TEH TEC LAR 17 COLD 61OUL 0.35 247 7 PLP TSH +0.70 TEH TEC LAR 17 COLD 61OUL Note: The Util 1 field shows the estimated loose part wear depth using the qualified rotating +PointTM sizing technique shown in the Util 2 field.

St. Lucie Unit 1 SG 1B SL1-22 Tubes Plulged Listing ROW COL VOLTS DEG CHN IND %TW LOCATION EXT EXT UTIL 1 UTIL 2 CAL # LEG PROBE 138 77 0.58 99 2 SVI TSH +0.12 TSH TSH 62 HOT 610PP 0.22 83 7 PLP TSH +0.24 TSH TSH LAR 62 HOT 610PP 0.68 75 2 WAR TSH +0.72 TSH TSH 49% 27901.1 62 HOT 610PP 0.90 269 7 PLP TSH +0.73 TEH TEC LAR 16 COLD 61OUL 0.37 116 PF LPI TSH +0.75 TEH TEC LAR 16 COLD 610UL Note: Tube 138-77 was plugged due to foreign object wear. A metallic foreign object was located adjacent to this tube and removed.

e. Number of tubes plugged during the SL1-22 inspection for each active degradation mechanism Table 3 Degradation Mechanism SG A SG B Total 0 0 0 Wear at U-bend Fan bar tube contacts Wear at Lattice grids 0 0 0 Loose Part Wear 0 1 1 0 0 0 Total

L-2009-091 Attachment I Page 7 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

f. Total number and percentage of tubes plugged to date Table 4 St. Lucie Unit 1 Steam Generator Cumulative Tube Plugging Summary SL1-22 SG # Plugged  % Plugged 1A 14 0.16 1B 1 0.01
g. The results of condition monitoring including the results of the tube pulls and in-situ testing Wear indications at fan bar, connector bar and horizontal lattice grid locations were evaluated relative to structural limits as shown in Figures 1 through 4. These wear indications were shallow in depth and well below the calculated structural limits for burst and leakage. Wear indications shown as solid data points in Figures 1 to 4 were conservatively modeled with lengths and depths based on the +PointTM profiles. Open data points are based on the maximum bobbin probe depth, which is assumed for a conservative length of 0.5 inches. Note that some data points in Figures 1 to 4 overlap and, thus, the number of points shown may not match the number of indications listed in Section d of this report.

Four wear indications due to a foreign object were reported ih three tubes at the hot leg tubesheet of SG lB. A metallic foreign object was located adjacent to these tubes and was removed. One tube (SG lB R138 C77) contained two wear indications that met the repair criteria and was plugged. The calculated 95% lower bound burst pressure of each indication based on +PointTM profile analysis is given in Table 5.

The structural integrity for all indications reported met the NEI 97-06 structural performance criteria. None of the indications were predicted to leak under limiting accident conditions. Thus, the PSL- 1 steam generators met the structural and leakage performance criteria.

There were no tube pulls or in-situ pressure testing required/performed during SL 1-22.

Upper bundle flushing and sludge lancing removed approximately 211 pounds of material from the steam generators. Deposit accumulations are considered low, and the tube support lattice design is expected to mitigate buildup within supports. Other than the foreign object that was removed as discussed above, no abnormalities were noted during the secondary side inspections.

L-2009-091 Attachment 1 Page 8 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

Table 5 Summary of Profile Analysis Results for Loose Part Wear in S/G B Max NDE NDE 95% Lower Depth Length Bound Burst Sizing Row Line Loc (%TW) (inches) Pressure (psi) ETSS 137 78 TSH + 0.42 29 0.31 7320 27901.1 Rev 0 138 77 TSH + 0.12 43 0.45 5300 21998.1 Rev 4 138 77 TSH + 0.72 49 0.33 6740 27901.1 Rev0 139 78 TSH + 0.62 22 0.38 7770 27901.1 Rev0 Note: The depth for the indication in SG 1B R138 C77 at TSH + 0.12" is provided for condition monitoring purposes only. This indication is listed in Section d as a single volumetric indication (SVI). This tube was removed from service.

L-2009-091 Attachment I Page 9 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

PSL-1 SIG A Fan Bar Wear Screening Limits October 2008 100 I __________ "___

-I Leakage Screening Limit

'Burst Screening Limit 90 I ;I ...... TW Structural Limit e <=0.5v

[

0 >0.5v 80 o Bobbin Only 70 17, 60 0

50 EE 40 30 NOTE: All "Bobbin only" data are assigned an "assumed" length of 20 0.5" based on historical data,'

10 ETSS 96004.1 Rev. 11

  • - - - - - -T I 0

0.0 0.2 0.4 0.6 0.8 1,0 1.2- 1.4 1.6 1.8 2.0 Length, L (inches)

Figure 1 - Condition Monitoring Results for Fan Bar Wear PSL-1 S/G A October 2008 (SL1-22).

L-2009-091 Attachment 1 Page 10 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

PSL-1 SIG B Fan Bar Wear Screening Limits October 2008 100

- - - Leakage Screening Limit Burst Screening Limit 90 -...... TW Structural Limit I <=0.5v

_* >0.5v o Bobbin Only 80 70 60 50 0

S E 40 x

30 NOTE: All "Bobbin only"' data are assigned an "assumed" length of 0.5" based on historical data.

20 10 e o9 L ECTSS 96004.1 Rev.. 11 0

0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 Length, L (inches)

Figure 2 - Condition Monitoring Results for Fan Bar Wear PSL-1 S/G B - October 2008 (SL1-22).

L-2009-091 Attachment 1 Page l1 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

PSL-1 S1G A Horizontal Lattice Grid Wear Screening Limits October 2008 100 I ---- Leakage Screening Limit I - Burst Screening Limit 90 I ..... TW Structural Limit I * '::=0.5v

.... U >0.5v o Bobbin Only 80 70 I--

60 50 E

E 40 30 NOTE: All "Bobbin __only"_ _

data__I_

are _

assigned an "assumed" length of 0.5" 20 * -~ based on historical data.

10 ETSS 96004.1Re.1 0

0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 Length, L (inches)

Figure 3 - Condition Monitoring Results for Horizontal Lattice Grid Wear PSL-1 S/G A - October 2008 (SL1-22).

L-2009-091 Attachment I Page 12 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

PSL-1 SIG B Horizontal Lattice Grid Wear Screening Limits October 2008 100 "I I

--- Leakage Screening Limnit I -Burst Screening Limit 90 I7. .... TW Structural Limit

_ __ <=0.Sv U '0.Sv 80 0o Bobbin Only 70 60 50 E

E 40

.Ra 30 F NOTE: All "Bobbin only" data are assigned an "assumed" length of 20 _ 0.5" based on historical data.

10 ETSS 96004.1 Rev. 11 0

0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8 2.0 Length, L (inches)

Figure 4 - Condition Monitoring Results for Horizontal Lattice Bar Wear PSL-1 S/G B - October 2008 (SL1-22).

L-2009-091 Attachment I Page 13 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

h. The effective plugging percentage for all plugging in each steam generator No tube repair methods (i.e. sleeving) are approved for St. Lucie Unit 1 that would have an affect on the effective plugging percentages. Therefore, the applicable effective plugging percentage is synonymous with the % Plugged in item f. above.

ADDITIONAL INFORMATION The following information is included to assist the staff in their review of the information provided in this report.

Abbreviations CSI - Component Support and Inspections SG - Steam Generator ISI - In-service Inspection ECT - Eddy Current Testing NEI - Nuclear Energy Institute EPRI - Electric Power Research Institute Acronyms H/L - Hot Leg C/L - Cold Leg VOL - Volumetric Indication SVI - Single Volumetric Indication PIT - Pit Indication PLP - Possible Loose Part WAR - Mechanical Wear TWD - Through Wall Depth TSH - Tubesheet Hot Leg TEH - Tube End Hot Leg TSC - Tubesheet Cold Leg TEC - Tube End Cold The last three pages of this document show a side view of the installed St. Lucie Unit 1 RSGs, a detailed view of the fan bar arrangement, and a table showing the distances between the support structures in the SGs.

L-2009-091 Attachment I Page 14 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

ST. LUCIE UNIT 1 B,&W ADVANCED SERIES PWR REPLACEMENT STEAM GENERATOR (RSG)

L-2009-091 Attachment 1 Page 15 of 16 St. Lucie Unit 1 "Steam Generator Tube Inspection Report" (For SL1-22)

Detailed Fan Bar View LatficeGnd Hot Leg 07K ILaffice Grid Cold Leg 07CI

PSL-1 STEAM GENERATOR ELEVATIONS AND STRUCTURE ACRONYMS INCREMENTAL CUMULATIVE CODE DEFINITION DISTANCE DISTANCE TEH Hot Leg Tube End 0.0" 0.0" TSH Hot Leg Tube Sheet 21.WB" (Nominal) 21.88" 01H #1 Lattice Grid Hot Leg TSH- 01H 24.0" 45.8'"

02H #2 Lattice Grid Hot Leg 01H - 02H 35.125:' 81.0" 03H #3 Lattice Grid Hot Leg 02h - 03,H 41.625" 122.6" 04H #4 Lattice Grid Hot Leg 03H - 04H 41.625" 164.25" 05H #5 Lattice Grid Hot Leg 04H - 05H 41.625" 205.88"'

06:H #6 Lattice Grid Hot Leg 05H - 061H 41.625" 247.51" 07H #7 Lattice Grid Hot Leg 06H - 07H 41.625" 289.13" CBH Connector Bar Hot Leg Variable F01 #1 Fan Bar Variable F02 #2 Fan Bar Variable F03 #3 Fan Bar Variable F04 #4 Fan. Bar Variable F05 #5 Fan Bar Variable F06 #6 Fan Bar Variable F07 #7 Fan, Bar Variable FD8 #8 Fan, Bar Variable F09 #9 Fan Bar Variable FID #10 Fan Bar Variable CBC Connector Bar Cofd Leg Variable

  • DISTANCE MEASUREMENTS ARE CENTER TO CENTER
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