ML20141E527
| ML20141E527 | |
| Person / Time | |
|---|---|
| Site: | Fort Saint Vrain  |
| Issue date: | 01/03/1986 |
| From: | Warembourg D PUBLIC SERVICE CO. OF COLORADO |
| To: | Berkow H Office of Nuclear Reactor Regulation |
| References | |
| P-86004, TAC-59787, NUDOCS 8601080010 | |
| Download: ML20141E527 (48) | |
Text
{{#Wiki_filter:O O. PublicService .n. s.,*. Company of Colorado P.O. Box 840 l 16805 WCR 19 1/2, Platteville, Colorado 80651 ,Dgegco 80201-0840 January 3, 1986 Fort St. Vrain Unit No. 1 P-86004 Director of Nuclear Reactor Regulation U. S. Nuclear Regulatory Commission Washington, D.C. 20555 Attention: Mr. H. N. Berkow, Project Director Standardization and Special Projects Directorate Docket No. 50-267
SUBJECT:
Confirmatory Action 6 - Inspection of High Ener.gy Piping
REFERENCES:
- 1) PSC letter, Lee to Chilk dated 11/22/85 (P-85432)
- 2) PSC Letter, Walker to Berkow, dated 12/10/85 (P-85460)
- 3) NRC letter, Berkow to Walker, date 12/26/85 (G-85504)
Dear Mr. Berkow:
In reference 1, the Public Service Company of Colorado (PSC) submitted a revised schedule extension request for the Fort St. Vrain (FSV) Environmental Qualification (EQ) Program. to reference 1 contained a list of confirmatory actions for PSC to complete and document in support of the 35 percent ' power level restriction during the. schedule extension period. PSC provided responses to these confirmatory actions in reference 2. In reference 3, the NRC requested further information on Confirmatory Action 6 on the inspection of several critical areas of the FSV high energy piping. This letter, plus attachments, provides the PSC response to this request for additional information. 8601080010 860103 7 \\ f .g .apww) 40 DR ADOCK 050 7
, __, provides a summary of PSC's position on this issue. provides the responses to the six additional information requests of reference 3. Attachments 3 and 4 provide backup information to the responses. The limited inspection plan to fulfill the intent 'of Confirmatory Action 6 will be completed by the middle of January 1986. At the present time, this issue appears to be controlling plant restart to a power level of 35 percent. The limited inspection plan, although limited as compared to a full scope ISI program, exceeds that discussed at the November 18, 1985 meeting between PSC and NRC which lead to Confirmatory Action 6. If you have any questions regarding the information provided in this letter and attachments, please call Mr. M. H. Holmes at (393) 480-6960. Very truly yours, 0 W /YuteJ D. W. Warembourg ager Nuclear Engineering Division DWW/RLC/ksc l Attachments
4 M ATTACHMENT 1 Sumary
o) Page 1 of 1 s Summary In Attachment 1 to reference 1 Confirmatory Action 6 stated " Submit a plan and perform inservice inspections on several critical areas of Fort St. Vrain's high energy piping to verify the integrity of this piping, prior to. returning the plant to operation". In reference 2, PSC presented an. inspection plan which was based on the limited inspection plan implied by Confirmatory Action 6. This PSC plan was further expanded by four additional examinations of the hot reheat (HRH) and cold reheat (CRH) systems as a result of telephone discussions with the NRC staff. In reference 3, the NRC staff has requested responses to six additional questions on the PSC inspection plan to inspect several critical areas of FSV's high energy piping. While PSC has attempted to respond to these questions to the fullest extent possible, it should be noted that the bulk of the information requested is beyond the scope of Confirmatory Action 6 and would be more relevant to a full scope inservice inspection program. As a result of numerous discussions with the NRC staff, the scope of our inspection plan has been further expanded to a total of 35 examination points of the main steam (MS), hot reheat (HRH), cold reheat (CRH) and feedwater (FW) systems. These examination points are representative of the following factors: 1. High energy service conditions for MS, HRH, CRH and FW systems. 2. The materials used in the construction of the high energy piping systems. 3. The various high energy piping fabrication methods, i.e., hollow forged, seamless and welded plate. 4. High stressed piping areas based on thermal and mechanical analysis. 5. Areas which in.the past have shown evidence of degradation at FSV. i l
,9 0 ATTACHMENT 2 PSC Responses to NRC Questions
Page 1 of 12 PSC Responses to NRC Questions NRC Question 1 ~ Describe the criteria used to determine the critical areas selected for inservice inspection in the steam, feedwater, and cold and hot reheat lines. In particular, how are the effects of phenomena such as thermal and mechanical fatigue, creep-rupture, corrosion and erosion consideration in this selection? PSC Response Examination points were chosen so that there is at least one examination point representing the various possible combinations of the following systems, piping fabrication methods, materials of construction and degradation phenomena: Systems: Main Steam (MS) Feedwater (FW) Hot Reheat (HRH) Cold Reheat (CRH) Fabrication Methods: Seamless Hollow Forged Welded Plate Material Composition: 2-1/4% Cr - 1% Mo ASTM A335 Gr P22 2-1/4% Cr - 1% Mo ASTM A165 (A691) Carbon Steel A106, Gr B or C (grade dependent on pipe size) Carbon Steel 'A155 (A671, Gr CB60) Degradation Phenomena: Thermal Fatigue Mechanical Fatigue Corrosion Erosion An example of the prt.;ess used in the selection of examination points for the main steam system is as follows: Table A3-1 in Attachment 3 indicates that the main steam system piping has two types of fabrication, seamless and hollow forged and one type of material, 2-1/4% Cr - 1% Mo A335. Combining this with the four degradation phenomena results in eight examination points for the main steam system piping. The examination points for the other three systems were selected in this manner except for-feedwater where corrosion is not considered to be a contributing factor - since feedwater piping normally remains solid with deoxygenated water during plant shutdown.
Page 2 of 12 4 All welds uncovered at the examination point will be examined. A 4 conservative estimate is that there will be two welds per examination point. The following.information is presented to demonstrate how the effects of the degradation phenomena are factored into the selection of the examination points. } 4 i I r i l j i i i i i 4 i i l 1 i i } i l 1 -.-,-,n ~. - - -. .--~.-,,.-_,,,,.e ,,,-n.- .,.,-,-..-.n., ,,er-. n.m ,,...ns._n--..,, n,,w
Page 3 of 12 Thermal Fatigue Thermal fatigue is caused by the stresses created by thermal expansion and contraction as the pipe heats up and cools down. The critical areas are assumed to be those that see high stress values during each thermal cycle. These areas are identified using the thermal stress analyses for each system. Mechanical Fat';ue - The mechanical fatigue suffered by the pipe material is caused primarily by the continuous low amplitude vibration from fluid flow and equipment operation. Since this type of cyclic stress analysis was not required for this vintage plant, the assumption is made that the response of the pipe to ,small vibrations is similar to the response to large vibrations such as those created by seismic events. Using this basis, the critical areas for mechanical fatigue are selected based on the high stress areas in the Operating Basis Earthquake (0BE) analysis for each system. Corrosion The high purity and low oxygen content of the water in the high energy piping systems result in a very low rate of generalized corrosion. The primary concern then becomes identifying areas of localized corrosion. The critical areas for localized corrosion are those portions of the steam lines where water may pocket during shutdown conditions. Pipe low points and potential water pockets are identified as inspection points by reference to the isometric drawings showing the piping arrangement. Erosion - Erosion damage to the pipe can be caused by a number of mechanisms. Those of concern are from water velocity and cavitation in the feedwater system, entrained water in the cold reheat system, and solid particles in the main steam and hot reheat systems. Regardless of mechanism, the areas of the pipe subject to erosion are primarily where changes in direction occur. Inspection points are then selected by referring to the isometric drawings for each system. Creep Rupture - Note that creep rupture was not considered in the selection of examination points. The reason for this -is that creep damage is a function of the time spent at temperature while under stress. The allowable stress levels established by the design codes are intended to limit creep damage to acceptable levels over the total design life of the plant. Variations in material properties and operating conditions have made advisable the examination of piping in older units for creep damage. Since the estimated operating time at temperature for the main steam and hot reheat lines is less than two years, which is a small fraction of the plant design life, creep rupture is not considered a significant concern at this time.
Page 4 of 12 NRC Question 2 Provide the bases for sample size selected considering that the sample size must be sufficient to detect inservice degradation and the examination methods. must be effective to identify service - induced flaws, if present. Information about the high energy piping systems: The' FSAR has Figure 10.1-1 "Overall Flow Diagram, Secondary Coolant and Power Conversion System". For the Main Steam, Hot Reheat, Cold Reheat and Feedwater Systems, define the regions of these systems that are physically accessible for RT or UT if insulation were removed. The piping in the turbine crossover lines and the piping and vessels in the turbine bypass lines (desuperheaters and flash tank) should be included. In the regions that are physically accessible for inspection, provide the following information: A) Isometric drawings and tables showing the identification of circumferential and longitudinal welds, the diameter and wall thickness of the piping runs, and the material specification of the pipe and vessels (desuperheaters and flash tank). B) General description of the insulation, 'i.e., lagging or removable. C) Location of RT or UT to be conducted. D) General description of the weld crowns, i.e., "as-welded" or ground. 4 The objective of the staff's_ question is to identify welds and base metal in accessible locations with similar material properties, configurations and operating conditions as in inaccessible locations.
Page 5 of 12-PSC Response Determination of the number of inspection points (samples) necessary to provide a high level of confidence of detecting service induced ' flaws includes consideration of two different types of potential flaws. ' One type of flaw is caused by the identifiable mechanisms discussed in the response to Question 1. Inspection points for this type of flaw are selected. based on the assumption that the flaws are most likely where the initiating conditions are most extreme and that if no flaws are detected in these locations, flaws are unlikely elsewhere in the pipe where conditions are less extreme. The second type of flaw is considered random in nature, with no identifiable i cause. Since confidence in detecting these flaws cannot be developed on an analytical basis as with the first type of flaw, a statistical basis is used. The Fort St. Vrain high energy piping, main steam, hot and cold reheat and feedwater, has a population of about 2000 welds. Of these, approximately 60 welds are identified for 3 inspection, resulting in a confidence level of 95 percent that the error rate is less than 5 percent based on Table X of the Department of Air Force, Table of Probabilities for use in stop or go sampling. This confidence level is considered adequate to provide reliable detection of flaws. The effectiveness of the examination methods in identifying flaws is discussed in the PSC response to Question 3. l The selection of inspection points in the main steam, hot re3 eat, cold reheat and feedwater
- systems, was made to encoroass representative samples of all material types in these sytems. bhile much of the high energy piping in a typical light water reactor is i
inaccessible for inspection because of radiation levels, the only limitations at Fort St. Vrain are due to local interferences. Where such local interferences restrict access, other inspection points are i selected which meet the selection criteria. The desuperheaters and flash tank are accessible for inspection. However, no inspaction points were selected for these vessels since these components were inspected as part of routine maintenance activity. The bypass flash tank, T-5201, was visually inspected internally by PSC Maintenance during the 1984 outage. No inservice degradation was found. Desuperheater, S5202, was inspected internally, by PSC Maintenance during a spray nozzle replacement. No internal degradation was found. The turbine crossover lines have been inspected within the past two years during turbine overhaul and no degradations noted. 1 1 4 .n n +, .nn-
Page 6 of 12 The following information is provided in accordance with the NRC staff request:
e i Page 7 of 12 A) Isometric drawings and tables showing the identification of longitudinal welds, circumferential welds, the diameter and wall thickness of the piping runs, and the material specifications of the pipe are included as Attachment 3. Only the welds selected for inspection are identified. Identification of all welds was not possible within the time constraints of this effort since approximately 500 pipe spool sheets would have to be examined in detail to locate all welds. B) Existing piping insulation consists of formed asbestos block held in place with wire and covered with aluminum lagging. Insulation thicknesses vary in accordance with Fort St. Vrain Insulation Specification IJI. Calcium silicate formed block will replace the asbestos block removed. Wiring and lagging will remain the same. Calcium silicate thicknesses will duplicate the thickness of the asbestos removed. C) The location of inspection points are shown on the drawings and l table in Attachment 3. D) The weld crowns will be left in the "as-welded" condition when i i employing PSC's shear wave ultrasonic procedure (Reference j for technique details). ] For radiographic techniques, the configuration of the weld crown is of concern only if it interferes with interpretation of the radiograph. Experience has determined that this is not a problem with the Fort St. Vrain high energy piping welds. i i o
Page 8 of 12 NRC Question 3 Define the specific nondestructive examination methods th'at will be used on the locations selected for inspection and provide a copy of the examination procedures including calibration standards and acceptance criteria. A sumary of maintenance record data should be provided where additional information supports the inspection proposal. PSC Response Degradation from thermal and mechanical fatigue appears as cracking in the weld area and adjacent base metal. Inspection for such cracks will be by shear wave ultrasonic or radiographic techniques. Shear wave ultrasonics will be used to perform a volumetric examination of both circumferential butt welds and longitudinal seam welds whenever possible. Calibration standards are established for the shear wave ultrasonic technique, and utilizes the critical flaw size acceptance criteria of ASME Section XI. Radiographic examination will be performed on welds where local interferences prevent ultrasonic testing. The radiographic technique will consist of a single wall shot with acceptance criteria to ASME Section XI. The straight beam ultrasonic technique is used to determine wall l thickness which will identify areas of wall loss caused by erosion i and/or corrosion effects. Copies of the radiographic (QCIM-30), and ultrasonic (QCIM-35), examination procedures which includes calibration standards are included in Attachment 4. Maintenance history was obtained by interviewing key PSC personnel as j noted in the response to Question 6. The results of these interviews i indicated a history of pipe degradation downstream of pressure i breakdown devices. Although these areas are normally inspected when the pressure breakdown devices are repaired, for the purposes of this effort, inspection points were selected to cover these areas. 4 m +_ -~.w
Page 9 of 12 NRC Question 4 For locations that involve the examination of pipe fittings, provide the technical basis that demonstrates that the examination procedures will detect inservice degradation (i.e., cracks, corrosion and erosion) if present on the fitting side of the butt welds and the inside/outside radius of the elbow. PSC Response The angle beam ultrasonic technique will detect cracks on the fitting 1 side of butt welds if sufficient surface is available for the transducers. Where surface is not available to utilize the ultrasonic tranducers, radiography will be used. The sensitivity of these techniques is sufficient to detect the critical flaws, and will utilize the acceptance criteria, per ASME Section XI, for critical flaw size. The straight beam ultrasonic techniques used for detection of wall loss from corrosion and erosion on straight pipe are also applicable for fittings. Even where the wall configuration is irregular, this technique will provide an accurate measurement of wall thickness.
t e Page 10 of 12 NRC Question 5 f j Provide an engineering drawing for each of the locations selected showing dimensions and material specifications and whether the welds i are "as-welded" or prepared for ISI. Define the volume or surface of l each location subject to ISI with the examination method superimposed. PSC Response Included 'in Attachment 3 are the isometrics for the four high energy piping systems which are to be inspected. These isometrics show the location of the welds, pipe dimensions and pipe class. The table in , lists each of the welds to be inspected, the pipe material specifications, reference to isometric drawing number and code number, type of inspection performed, degradation mechanism inspected for, and total length of weld inspected. The combined use of the table and the appropriate isometric drawings will provide the required pipe inspection information. All the welds will be inspected in the as-welded state as discussed under Question 20. Surface preparation of the area adjacent to the weld (i.e., removal of mill scale, rust, etc.) will be done as required to permit proper ultrasonic examination. l 4 J i 4 r 4 - -,, _, -, -,, - + . ~. -,,.,.,,.,
'a Page 11 of 12 NRC Question 6 In the MS, HRT, CRT and FW systems identify any r'epair by welding of piping or components 4 inch or greater. A brief description should be provided of the mechanism of failure and the method of detection. i Identify any inservice failure of bolted connections with bolt diameters 1/2 inch or greater. i PSC Response The Station Service Request (SSR) system addresses any plant repair i including the repair records for piping and components in the high energy systems. There is presently no way to electronically separate 4 out the repair records for the high energy systems. A manual review of the entire SSR system to separate out the desired information would be impossible in the time frame allotted for this response Therefore, historical information was gathered by interviewin i oxperienced personnel in the PSC Production, Engineering and Q departments who are involved in plant repair efforts. The repairs identified by these interviews are listed in table 6-1. i l As can be seen from this table, these interviews reported only l repairs to piping immediately downstream of pressure breakdown 1 devices due to cavitation induced erosion. It should be noted that in general this type of type erosion is initiated subsequent to the deterioration of the associated pressure breakdown device. System performance characteristics change appreciably as a result of any i wearing of the pressure breakdown device. Such changes in performance characteristics will be noted by plant operations, who in turn will issue an SSR. When maintenance is performed on the pressure breakdown device, the downstream piping is visually inspected for erosion and repairs made if necessary. The interviews i did not report any repairs due to inservice degradation in other pressure boundary areas of the high energy piping. I i
3 TABLE 6-1 Page 12 of 12 i s 4 COMPONENT OR PIPING l IDENTIFICATION TYPE OF REPAIR CAUSE 1. L-21219-D2A Downstream of PV-21243 Degradation of the valve (10.75"0.D.) was replaced. seat causing downstream t erosion. 2. L-31157-016 Replaced reheat bypass Erosion of nozzles i (4"0.D.) line downstream of causing downstream ) nozzles with new erosion of nozzle. l l nozzles installed. J f 3. L-3190-D2A (4" 0.D.) Replaced pressure Erosion of orifice i breakdown orifice plates. plates. 4. L-52265-D9, Replaced bypass Pressure differential i L-52266-D9 (3" 0.D.) desuperheater drain allowing flushing in i j lines. lines, thus causing erosion in line, t \\ \\ l 5. Marnon Flanges Installed spool piece Leakage across flange l l (HRH from steam in place of flange, gasket surface. Not generators). due to inservice { degradation. 6. L-3173-D1(10"0.0.) Cut and rewelded Excessive nozzle loading l l L-3188-D2A piping to stress on pump inlet and (11,75" 0.0.) relieve. outlet. ] C Boiler feed pump suction and ) discharge piping 1 respectively. 4 j 7. H-2253(22.25"0.D.) Weld repair crack in Manufactuier defect. l j valve body. [ 8. H-2254 (22.25" 0.D.) New valve slat Erosion of valve seat. l J installed. I 9. H-2251(16"0.D.) Valve seat repaired. Erosf ori of valve seat. i
- 10. H-2223 (16.25" 0.D.) Valve seat repaired.
Erosion of valve seat. i l
- 11. H-2224 (16.25" 0.D.) Valve seat repaired.
Erosion of valve s%at. I i
- 12. V-53118 (4" 0.D.)
Valve replaced line Valve degradation. l l L-5339(4"0.D.) removed and re-installed due for l j valve installation. } l t l l } } t e
O O at s ATTACHMENT 3 Isometric Drawings and Table to Identify Examination Points
Page 1 of 1 This attachment contains the isometric drawings showing the seamed piping and the examination points. The seamed piping is indicated by the cross hatching in the nine drawings 11A-154 thru 11A-156, 11A-161 thru 11A-164, 14A-87 and 14A-88. The remaining drawings indicate the examination points. Also included in this attachment is Table A3-1 which shows the factors used in the examination point selection.
TABtE A3-1 .llNSPECIIONl llNSPECisONI CONSTRUCISON l MAllHIAL l PIPC l l l LINE l DitAWING l NODE l l PolNT l1yS1lMI toH l_ lyPI l__ _ t A>ML l CLASS l _S I /J _ l WAl l.l_NUMHIH l_NUMHfR 1,3UMBfR l l 1 l IW l In. f. I Seamless l A106, Cit. B l D2A i 11.7$ i 1.574 l L3188 l 5-99 l 20 l l 2 l rW l ih. f. l Ho l low f o rged i Alo6, CR. n' l Is/A l 17.5 I ?.34f4 l 13199 l 5-103 1 305 l l 3 l FW l M.F. l Seamless l A106, CH. C l D2A l 5 l Sch XXSl 12703 l 5-96 n 415 l l 4 I IW l H.F. I 1801 I ow I o rged i A106, CH. B* I D2A l 13 l
- 1. 7fs2 l t?201 1 5-95 585 l
l 5 l IW l Eros. 1 Seamless l A106, CH. D l D?A l 13 l 1.742 l 12202 l $-92 452-f551 4 l 6 l TW l lros. I Itollow f orged l A106, CH, H* l D2A l 13 l
- 1. 7fs? l (?201 l 5-95 585 i
l 7 i MS I Th. F. ! Ilottow forged l A33's, GH. P22 l Of i 16.25 l 2.715 l L2?21 l I fi A-9 3 l 330 l l 8 l MS I Th. F. l Seamless l A335, CH. P22 1 D1 1.8.75 l 1.462 i L2286 I IlsA-90 l 756 l l 9 l MS l M.I. I Seamless l A 3 3's, GM. P22 1 D1 1 8.75 l 1.462 1 122/1 l lisA-94 l 186 l l 10 l MS I M.I. I Hollow forged i A 3 3's, CH. P22 l 01 l 16.25 l 2.715 l L2278 l 14A-99 l 205 l l 11 l MS I Corros.l Scamless l A335, GH. PP2 1 D1 1 8.75 l 1.46? l 12271 l 14A-914 l 183-186l l 12 l MS l Corros.1 llollow f orged l A335, CH. P22 1 D1 l 20.75 1 2.996 i L5201 l 2-255 8 455 l l 13 l MS I [ros. 1 Seamless l A335, CH. I'22 l U1 l 8.7'> l 1.462 l L22/1 1 IfA-9f4 l 185 l i l 14 l MS l [ros. I Hollow f orged I.A335, CR. P22 l D1 l 16.25 l 2.715 l 12? T8 l 14A-99 l 205 l i l l 15 l CRil l Th. I. I Seamless l A106, CR. Il l D9 l 12 l Sch. 80l L2295 l 11A-159 l 335 l t 16 l Citil i Th. f. I Welded Plate l A'>15 CH. 60 i D9 l 32 l 1.268 i L5201 l 11A-164 l 990-l l IT l CitH l M.F. l Seamless I A106, CR. B l D9 1 1? l Sch. 801 L2295 l 11A-159 l 335 l l 18 l CHH l M.f. I Welded Plate l A 51 '>, CH. 60 l 09 l 26.5 l 1.088 i L22?50 l IIA-156 l 635 l l 19 l CRH l Eros. 1 Seamless l A106, CH. U l D9 l 14 l Sch. Sul t?293 ! 11A-159 l f411-415l l 20 l CRH l E ro s. I Wolded Plate i A 515, Cit. 60 l D9 l 32 l 1.268 l 15?Of l 11A-16f4 l 990 l l 21 l CRH I Corros.l Seamless l A106, CR. Is 1 09 l 14 l Sch. 801 L2293 1 11A-159 l 411-4151 1 22 l CRH l Corros.1 Welded Plate l A51 *>, CH. 60 l D9 l 32 l 1.268 I t$207 l 11A-16f4 l 990 l l 23 l Itkil I th. f. I Scamless l A335, CR. P?2 1 D3 1 11 1 0.800 l L2248 l If4A-76 I 350 l l 24 l liRil I ih. F. l Ilo l low f o rged i A335, CR. P22 1 D3 l 22.25 l 1.714 l L2252 l 14A-85 l 355 l l 25 l HRH l Th. F. l Welded Plate I A155, CR. 2 1/4 CH, CL 11 D6 l 20 l 0.896 l L5220u l 14A-87 l 970 l r l 26 l IIRH l M.f. I Seamicss l A335. CR. P22 l D6 l 22 l 1.004 i L5217 l 14A-87 l 485 l l 21 l HRH l M.F. l Hollow forged l A335, GR. P22 l D3 1 22.25 l 1.714 l L2211? l 14A-85 l ?O5-2111 l 28 l HRH l H.F. l Welded Plate l A155, Cit. 2 1/4 CH, CL 11 D6 l 20 1 0.896 l L52200 l Ils A-8 7 1 495 l l 29 l IIRH l Co rros. l Seamless l A335, CR. P22 l D3 l 11 l O.800 l L2210*> l IlsA-84 1 185 l l 30 l HRH l Co rros. l Hol low f o rged l A335, CR. P22 l D3 l 22.25 l 1.714 i L2252 l 14A-85 l 250-9861 1 31 l HRH l Co-ros. l Welded Plate l A155, CR. 2 1/4 CR, LL 11 D6 l 34 l 1.511 l L5216 l 15A-87 l 540-550l l 32 i HRH I
- t. ro s. l Scamless l A335, CH. P?2 l D3 l 11 l 0.800 l L2210*i l I f4 A-8f4 l
185-186l I 33 l HRH l f ms. l liollow Forged l A335. CH. P2P l 03 l 22.25 l 1. 71 fs l L2211? l 14A-85 l 20fs l l 34 l HRH l E ro s. I Weldad Plate l A155, CR. 2 1/4 CR, CL 11 D6 1 34 l 1.511 l L5216 l 14A-87 l 540-5501 l 35** I FW l E ro s. l Seamless i A106, CR. B l D2B l 6 l.864 l L21224 l 10A-66 l 231 l l l l 1 i l l l l l l l
- Additional Tolerances Per ASIM A530.
- This point inspected due to historical erosion problems.
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