WO2010118136A1 - Reduced drag centralizer - Google Patents
Reduced drag centralizer Download PDFInfo
- Publication number
- WO2010118136A1 WO2010118136A1 PCT/US2010/030243 US2010030243W WO2010118136A1 WO 2010118136 A1 WO2010118136 A1 WO 2010118136A1 US 2010030243 W US2010030243 W US 2010030243W WO 2010118136 A1 WO2010118136 A1 WO 2010118136A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- tubular
- centralizer
- stand
- circumferential
- degrees
- Prior art date
Links
- 238000000034 method Methods 0.000 claims description 4
- 230000008901 benefit Effects 0.000 description 2
- 239000004593 Epoxy Substances 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000002788 crimping Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 230000007704 transition Effects 0.000 description 1
- 238000003466 welding Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/10—Wear protectors; Centralising devices, e.g. stabilisers
- E21B17/1014—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well
- E21B17/1021—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well with articulated arms or arcuate springs
- E21B17/1028—Flexible or expansible centering means, e.g. with pistons pressing against the wall of the well with articulated arms or arcuate springs with arcuate springs only, e.g. baskets with outwardly bowed strips for cementing operations
Definitions
- Oilfield tubulars are disposed in wellbores to perform various tasks.
- a centralizer may be disposed with (e.g., on) a tubular string to position the tubular string within the wellbore (e.g., wall of the borehole, inner wall of an outer tubular such as the casing, liner, etc.).
- the centralizer is commonly utilized to maintain separation between the tubular string and the wellbore.
- Centralizers commonly comprise a pair of collars that are interconnected with bows. The centralizers are positioned on the tubular string with the tubular extending through the respective bores of the collars and the bows extending outward from the tubular string. Centralizers may be fastened to the tubular in various manners.
- centralizers are attached to a tubular such that centralizer is axially moveable along a length of the tubular, for example between stop collars, or one end (e.g., collar) is fixedly attached at an axial position and the other collar being free to move axially.
- the centralizer is rotationally moveable relative to the tubular.
- At least one of the ends e.g., centralizer collars
- FIG. 1 is a schematic of a centralizer disposed in a wellbore.
- Centralizer 3 comprises opposing cylindrical collars 4, 5 and a plurality of bow members 6 attached between the opposing collars 4, 5.
- a plurality of bows 6 are provided so as to form a 360 degree circumferential diameter to provide 360 degrees of standoff from the wellbore wall.
- Opposing collars 4, 5 receive tubular 7 (e.g., tubular string) therein and are axially and rotationally moveable relative to tubular 7.
- Stop collars 8, 9 attached (e.g., fastened) on opposing sides of collars 4, 5 and spaced apart such that centralizer 3 can move axially between stop collars 8, 9.
- Stop collars 8, 9 may be attached to tubular 7 in various manners so as to be fixed at least axially relative to tubular 7.
- stop collars 8, 9 may be secured in via clamping (e.g., set screws, nuts, bolts), adhesives (e.g., epoxy), welding, crimping, and interference fits.
- Centralizer 3 and tubular 7 are disposed in a (e.g., substantially cylindrical) wellbore 10 defined by wall 12.
- wall 12 is depicted as a tubular (e.g., casing, liner, tubing).
- Figure 2 illustrates a centralizer being passed through a restriction in the wellbore.
- Figure 2 depicts wellbore 10 having a restriction 14.
- Restriction 14 is used generally herein to describe a reduced inside diameter portion of wellbore 10.
- the restriction 14 may be formed intentionally (e.g., a transition) or unintentionally (dogleg, turn, sloughing, etc.).
- restriction 14 is a tubular having an inside diameter less than the tubular section depicted at the left side of Figure 2.
- the running force In order to move through restriction 14, the running force must be sufficient to overcome the collapse load (e.g., stand-off force) of the centralizer and the factional forces of running the tubular string. Typically, this requires that the running forces (e.g., collapse and friction) must be less than the weight of the tubular string.
- the running forces e.g., collapse and friction
- a low collapse force e.g., low restore force, low stand-off force
- bows 6 of centralizer 3 may not have a sufficient restoring or stand-off force to position the tubular string in the wellbore (e.g., centralize) after passing through the restriction.
- the lack of sufficient stand-off force may be amplified in high-angle and horizontal wellbore sections.
- an apparatus comprises opposing collars spaced apart from one another along a longitudinal axis, each of the opposing collars adapted to be fixedly secured to a tubular with a holding force; and a bow extending between the opposing collars, the bow having an apex and a stand-off force.
- the centralizer may comprise one or more bows.
- the centralizer may include a circumferential portion of at least 180 degrees in which bows are not disposed.
- an apparatus of the present disclosure comprises opposing collars spaced apart from one another along a longitudinal axis, each of the opposing collars adapted to be fixedly secured to a tubular with a holding force; and two or more bows extending between the opposing collars, each of the two or more bows spaced apart from one another within a circumferential arc no greater than about 180 degrees.
- An apparatus comprises at least two centraiizers, each centralizer having a circumferential stand-off portion and a second circumferential portion defining 360 degrees, at least two bows extending between opposing collars within the stand-off circumferential portion; wherein the at least two centralizers are spaced axially apart and fixedly attached to the tubular with the respective circumferential standoff portions angularly offset from one another.
- Figure 1 is a schematic view of a centralizer disposed in a wellbore.
- Figure 2 is a schematic view of the centralizer of Figure 1 disposed in a restriction in the wellbore.
- Figure 3 is a perspective view of a centralizer according to one or more aspects of the present disclosure.
- Figure 3A is an end view of the centralizer of Figure 3.
- Figure 4 is a schematic view of a centralizer system according to one or more aspects of the present disclosure disposed in a wellbore.
- Figure 4A an end view of the centralizer system of Figure 4 according to one or more aspects of the present disclosure.
- Figure 5 is a schematic, end view of a centralizer according to one or more aspects of the present disclosure.
- Figure 6 is a schematic, end view of another embodiment of a centralizer according to one or more aspects of the present disclosure.
- first and second features are formed in direct contact
- additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.
- the terms “up” and “down”; “upper” and “lower”; “top” and “bottom”; and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements. Commonly, these terms relate to a reference point as the surface from which drilling operations are initiated as being the top point and the total depth of the well being the lowest point, wherein the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.
- the terms “pipe,” “tubular,” “tubular member,” “casing,” “liner,” “tubing,” “drill pipe,” “drill string” and other like terms can be used interchangeably.
- a centralizer has collars adapted to be fixedly attached (e.g., at least rotationally stationary) to a tubular and a bow extending between the opposing collars is provided.
- a centralizer is adapted to pass through a restriction (e.g., reduced diameter) without requiring collapse of the bow according to one or more aspects of the present disclosure. It is recognized that bow(s) may deflect toward the tubular when running tubular operations; however, this limited deflection is permitted and is not an example of collapse.
- FIG 3 is a schematic view of a centralizer 20 according to one or more aspects of the present disclosure.
- Centralizer 20 comprises opposing collars 21, 22 and at least one bow 24.
- Opposing collars 21, 22 comprise bores 25 for receiving and disposing a tubular 7 (See Figure 1) along the longitudinal axis "X" of centralizer 20.
- centralizer 20 comprises two bow members 24 which each have one or more apexes 28 that extend radially away from the longitudinal axis X of centralizer 20.
- centralizer 20 does not include a plurality of bows 24 spaced around collars 21, 22 to form a 360 degree circumferential diameter at the centralizer 20.
- Collars 21, 22 are adapted to fixedly attach (e.g., fasten, secure) centralizer 20 to a tubular.
- collars 21, 22 fixedly secure centralizer 20 so as to be axially and rotationally fixed relative to the tubular.
- collars 21, 22 are only rotationally fixed relative to the tubular.
- Opposing collars 21, 22 are depicted in Figure 3 as an interference fit (e.g., collet) collar having a high holding force, for example 80,000 pounds of axial force. Additional examples of collars include, without limitation to, the attachment collars disclosed in U.S. Provisional Application Nos.
- bow(s) 24 may also have a high stand-off (e.g., restoring force) relative to traditional centralizers as will be understood by those skilled in the art that have benefit of the present disclosure.
- Bows 24 may be substantially rigid relative to the collapse force of traditional centralizer bows.
- Centralizer collars 21, 22 may comprise other means and/or mechanisms for fixedly attaching to the tubular.
- FIG 3A is an end view of centralizer 20 of Figure 3.
- centralizer 20 has two bow members which are circumferential Iy spaced apart from one another.
- Bow members 24 extend outward (e.g., radially) from the longitudinal axis of the centralizer to their respective apex 28.
- the two bow members are spaced about 90 degrees from one another.
- the number of bows 24 and/or the spacing between bows 24 may be selected such that the positive outside diameter (e.g., the diameter of the uncompressed bows across an apex)of the centralizer is less than a known or expected restriction 14 ( Figure 1 ) and is not limited to the depicted embodiments.
- the positive outside diameter of centralizer 20 is depicted by the dashed line and the numeral 30 in Figure 3 A.
- FIG 4 is a schematic view of the centralizers of Figures 3 and 3A utilized in a wellbore.
- two or more centralizers 20 are attached axially along a section 7b of tubular string 7 and oriented such that the plurality of bows 24 are spaced 360 degrees circumferentially around section 7b to provide 360 degrees of standoff from the wellbore wall.
- centralizers 20a, 20b of Figure 4 each comprise two bows 24 as depicted in Figures 3 and 4 which are spaced approximately 90 degrees from one another.
- Centralizers 20a, 20b are fixedly attached along section 7b and offset angularly so that the four bows are spaced 360 degrees around tubular 7.
- the centralizer 20a on the left side of Figure 4 is oriented with its one bow 24a positioned approximately 180 degrees from the bow marked 24a on the centralizer 20b shown on the right side of the Figure.
- the centralizer 20a comprises a second bow that is hidden behind tubular 7 and about 180 degrees from bow 24b on the right centralizer 20b.
- Figure 4 depicts a restriction 14 in wellbore 10 that is positioned between the left and the right centralizers 20a, 20b illustrating that the right centralizer 20b has passed through restriction 14.
- the bow members are each depicted contacting wall 12 and substantially centering tubular 7, in particular section 7b, in wellbore 10 to provide 360 degrees of standoff from the wellbore wall 12.
- the positive outside diameter of the centralizer must be less than the inside diameter of restriction 14.
- the positive outside diameter 30 ( Figure 3A) of each individual centralizer 20 has a positive outside diameter approximate to or less than the inside diameter of restriction 14, although the total positive outside diameter of the two or more centralizers around tubular section 7b may be greater than the inside diameter of restriction 14.
- Figure 4A is a schematic end view of the apparatus of Figure 4.
- the total or effective positive outside diameter of the two or more centralizers 20a, 20b ( Figure 4) is depicted by the dashed line 32.
- the inside diameter of restriction 14 is depicted by a dashed line circumscribed by the total effective positive outside diameter 32.
- the individual centralizer positive outside diameter 30 as depicted in Figure 3A is less than the inside diameter of restriction 14.
- each centralizer may comprise a single bow.
- single bow centralizer embodiments it may be desired for example to axially space three centralizers with their respective bows angularly offset from one another approximately 120 degrees.
- FIG. 5 is a schematic, end view of another centralizer 20 in accordance with one or more aspects of the present disclosure.
- centralizer 20 comprises two bows 24a, 24b which are circumferentially spaced no more than 180 degrees apart.
- the positive outside diameter of the individual centralizer 20 is denoted by the dashed line 30.
- a combination of two centralizers 20 of Figure 5 may be secured to a tubular in a spaced about and angularly offset manner similar to the embodiments depicted in Figures 4 and 4 A to provide 360 degree circumferential offset.
- limiting the bows to a circumferential stand-off arc, and or dividing the number of bows required to achieve 360 degrees of stand-off among two or more centralizers facilitates lowering the running force of the tubular string relative to the running force for a tubular string utilizing 360 degrees of stand-off on a single centralize all of which must be compressed to pass through a restriction.
- Figure 6 is a schematic, end view of another centralizer according to one or more aspects of the present disclosure.
- the depicted embodiment has four bows 24a, 24b, 24c, 24d circumferentially spaced apart within a circumferential stand-off portion of a centralizer 20 denoted by the numeral 40.
- circumferential stand-off portion 40 is approximately 180 degrees.
- circumferential stand-off portion 40 is not greater than about 180 degrees.
- circumferential stand-off portion 40 may be less than 180 degrees as depicted for example in Figures 3, 3A.
- circumferential stand-off portion 40 Corresponding to the limitation of bows 24 being disposed within the circumferential stand-off portion 40 (e.g., arc) is a second circumferential portion 42 (e.g., arc) in which bows 24 are not disposed. Circumferential stand-off portion 40 and second circumferential portion 42 without bows total the 360 degree circumference of centralizer 20.
- a combination of two centralizers 20 of Figure 6 may be secured to a tubular in an axially spaced apart and angularly offset manner similar to the embodiments depicted in Figures 4 and 4A to provide 360 degree circumferential stand-off.
- the circumferential stand-off portions 42 of the respective centralizers are offset from one another.
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
Description
Claims
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
BRPI1014179A BRPI1014179A2 (en) | 2009-04-07 | 2010-04-07 | reduced drag centerer |
Applications Claiming Priority (10)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US16748209P | 2009-04-07 | 2009-04-07 | |
US61/167,482 | 2009-04-07 | ||
US22171609P | 2009-06-30 | 2009-06-30 | |
US61/221,716 | 2009-06-30 | ||
US23720209P | 2009-08-26 | 2009-08-26 | |
US61/237,202 | 2009-08-26 | ||
US26321809P | 2009-11-20 | 2009-11-20 | |
US61/263,218 | 2009-11-20 | ||
US28766509P | 2009-12-17 | 2009-12-17 | |
US61/287,665 | 2009-12-17 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2010118136A1 true WO2010118136A1 (en) | 2010-10-14 |
Family
ID=42825238
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2010/030243 WO2010118136A1 (en) | 2009-04-07 | 2010-04-07 | Reduced drag centralizer |
Country Status (3)
Country | Link |
---|---|
US (1) | US20100252279A1 (en) |
BR (1) | BRPI1014179A2 (en) |
WO (1) | WO2010118136A1 (en) |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US8408287B2 (en) * | 2010-06-03 | 2013-04-02 | Electro-Petroleum, Inc. | Electrical jumper for a producing oil well |
US8863832B2 (en) * | 2010-09-28 | 2014-10-21 | Schlumberger Technology Corporation | Orientable eccentric downhole assembly |
WO2024054593A1 (en) * | 2022-09-08 | 2024-03-14 | Schlumberger Technology Corporation | Through-rotary centralizer |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2594550A (en) * | 1950-03-15 | 1952-04-29 | Gist Fred Morgan | Multisection pipe protector |
US3062297A (en) * | 1960-11-25 | 1962-11-06 | Jr Robert Tyrrell | Well-casing centralizers |
GB1014736A (en) * | 1962-10-26 | 1965-12-31 | Albert Edward Atkinson | Improvements in and relating to devices for centralizing casing in boreholes |
US4794986A (en) * | 1987-11-27 | 1989-01-03 | Weatherford U.S., Inc. | Reticulated centralizing apparatus |
Family Cites Families (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2555628A (en) * | 1948-03-08 | 1951-06-05 | Baker Oil Tools Inc | Casing centralizer |
US2562083A (en) * | 1948-10-01 | 1951-07-24 | Baker Oil Tools Inc | Casing centralizer |
US3196951A (en) * | 1962-04-30 | 1965-07-27 | Schlumberger Well Surv Corp | Centralizers |
US3566965A (en) * | 1968-07-22 | 1971-03-02 | B & W Inc | Variable size,multi-hinge centralizer |
US4363360A (en) * | 1981-01-15 | 1982-12-14 | Richey Vernon T | Apparatus for use in maintaining a well pipe centered within a well bore |
US5575333A (en) * | 1995-06-07 | 1996-11-19 | Weatherford U.S., Inc. | Centralizer |
US7156171B2 (en) * | 2000-09-06 | 2007-01-02 | Casetech International, Inc. | Dual diameter and rotating centralizer/sub |
US6679325B2 (en) * | 2002-02-08 | 2004-01-20 | Frank's International, Inc. | Minimum clearance bow-spring centralizer |
-
2010
- 2010-04-07 BR BRPI1014179A patent/BRPI1014179A2/en not_active Application Discontinuation
- 2010-04-07 WO PCT/US2010/030243 patent/WO2010118136A1/en active Application Filing
- 2010-04-07 US US12/755,876 patent/US20100252279A1/en not_active Abandoned
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2594550A (en) * | 1950-03-15 | 1952-04-29 | Gist Fred Morgan | Multisection pipe protector |
US3062297A (en) * | 1960-11-25 | 1962-11-06 | Jr Robert Tyrrell | Well-casing centralizers |
GB1014736A (en) * | 1962-10-26 | 1965-12-31 | Albert Edward Atkinson | Improvements in and relating to devices for centralizing casing in boreholes |
US4794986A (en) * | 1987-11-27 | 1989-01-03 | Weatherford U.S., Inc. | Reticulated centralizing apparatus |
Also Published As
Publication number | Publication date |
---|---|
US20100252279A1 (en) | 2010-10-07 |
BRPI1014179A2 (en) | 2016-04-05 |
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