CA3012784C - Stop collar - Google Patents

Abstract

Stop collars may be fixedly mounted on a liner or other tubular member. The stop collar comprises a first sleeve and a second sleeve. The sleeves are adapted to extend around the outer circumference of the tubular member and are engaged by threaded connections. The sleeves provide opposing inner thrust surfaces. The collar further comprises a radially expandable gripping member disposed between the opposing thrust surfaces. The sleeves may be drawn together by rotation about the threaded connection to cause the thrust surfaces to bear on the gripping member and expand the gripping member radially inward into frictional engagement with the tubular member.

Description

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2 FIELD OF THE INVENTION

3 The present invention relates to downhole tools used in oil and gas well drilling

4 operations and, and more particularly, to tool assemblies and stop collars that may be mounted on a liner or other tubular used in oil and gas wells.

Hydrocarbons, such as oil and gas, may be recovered from various types of 8 subsurface geological formations. The formations typically consist of a porous layer, 9 such as limestone and sands, overlaid by a nonporous layer. Hydrocarbons cannot rise io through the nonporous layer. Thus, the porous layer forms a reservoir, that is, a volume 11 in which hydrocarbons accumulate. A well is drilled through the earth until the hydrocarbon bearing formation is reached. Hydrocarbons then are able to flow from the 13 porous formation into the well.
14 In what is perhaps the most basic form of rotary drilling methods, a drill bit is attached to a series of pipe sections or "joints" referred to as a drill string. The drill string 16 is suspended from a derrick and rotated by a motor in the derrick. A drilling fluid or 17 "mud" is pumped down the drill string, through the bit, and into the bore of the well.
18 This fluid serves to lubricate the bit. The drilling mud also carries cuttings from the 19 drilling process back to the surface as it travels up the wellbore. As the drilling zo progresses downward, the drill string is extended by adding more joints of pipe.
21 A modem oil well typically includes a number of tubes extending wholly or 22 partially within other tubes. That is, a well is first drilled to a certain depth. Large 23 diameter pipes, or casings, are placed in the well and cemented in place to prevent the 24 sides of the borehole from caving in. After the initial section has been drilled, cased, and cemented, drilling will proceed with a somewhat smaller wellbore. The smaller bore is 26 lined with somewhat smaller pipes or "liners." The liner is suspended from the original 27 or "host"
casing by an anchor or "hanger." A well may include a series of smaller liners, 28 and may extend for many thousands of feet, commonly up to and over 25,000 feet.
29 The liners are cemented in the wellbore as the well is constructed. That is, the liner necessarily is smaller than the bore in which it is installed. The gap between the 31 liner and the wellbore is referred to as the annulus, and it is filled with cement after the KBCN:01 O-CA
liner has been installed. The cement helps secure the liner in the wellbore and protect it 2 against corrosion and erosion. It also supports the borehole walls from collapse. If 3 fluids will be produced through the liner, cement also helps ensure more precise control 4 over stimulation processes, such as fracturing and acidizing.
Most importantly, the cement is intended to form a continuous sheath, that is, a 6 complete seal around the liner. If the liner leaks, the cement sheath will help ensure that 7 fluids flowing through the liner do not contaminate the surrounding formation, and 8 especially water-bearing formations. The cement sheath also ensures that hydrocarbons 9 and other fluids in the formation are not able to migrate to other parts of the formation or o to the surface.
11 The liner is cemented in the wellbore by injecting a cementitious, settable slurry 12 down the liner and allowing it to flow up the annulus. The cement then is allowed to set, 13 that is, solidify and harden into what hopefully will be a continuous seal throughout the 14 annulus. There are a number of challenges, however, in ensuring that the sheath is continuous and that a complete seal is established between the bore and liner.
Some 16 issues arise from the chemical and physical nature of the cement slurry and how it 17 interacts with other fluids in the well or the formation. The position of a liner in the bore 18 also can create significant impediments to forming a complete seal.
19 That is, oil wells are commonly depicted as extending straight down into the earth with a tube running right down the middle of the bore. The truth is far from that.
21 Because it is formed with a rotating drill bit, the bore will tend to corkscrew as it is 22 extended. Moreover, in order to increase production, the bore commonly will be deviated 23 from a nominal vertical bearing to extend it along, rather than through a hydrocarbon-24 bearing formation. So-called "horizontal" wells constitute most of the wells being drilled in the United States today.
26 A liner, therefore, will not necessarily be centered within a wellbore.
It may tend 27 to rest against the side of a bore, especially in horizontal extensions.
A cement slurry 28 may not be able to flow into the area where a liner rests against the borehole. Thus, when 29 set, voids may be left in the cement sheath, or it may have thin, weak portions. Fluids from the formation may be able to migrate from one area of the formation to another or 31 may even reach the surface.

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In an effort to mitigate such problems, a liner typically will be provided with 2 centralizers. The centralizers are intended to maintain a minimum clearance between the 3 liner and the bore, while at the same time providing paths which allow cement slurry to 4 flow past them. "Bow-spring" centralizers are one common type of centralizer. They s have a pair of relatively short sleeves that fit around the outside of a liner. A number of 6 relatively stiff, narrow bow springs extend between the sleeves. The bow springs curve 7 away from the liner and keep the liner spaced from the walls of the bore.
The springs are 8 spaced angularly around the circumference of the sleeves so that cement slurry can flow 9 around and through the centralizer.
io "Spiral-blade" centralizers are another common type. They incorporate a single ii longer sleeve. The sleeve has raised, rounded blades that extend along the sleeve in a 12 loose helix. The blunt blades maintain clearance with the bore while providing channels 13 through which cement may flow. Centralizers, therefore, can greatly reduce or eliminate 14 contact between a liner and the bore, and help ensure that the cement sheath will have is sufficient thickness throughout the annulus to provide an effective seal.
16 Centralizers may be mounted on a liner in a fixed position. For example, U.S.
17 Pat. Pub. No. 2013/0160993 of J. Davilla et al. discloses a spiral-blade centralizer that is is fixedly mounted on a liner. It generally comprises a body and a pair of wedge rings. The 19 body is generally cylindrical and fits around a liner. Blunt blades are provided around its zo circumference to keep the liner spaced from the bore and provide channels for cement 21 flow. Each end of the centralizer body has internal threads. The threads are opposed.
22 That is, the threads on one end of the body are right-hander and those at the other end are 23 left-handed. The internal threads on the body engage external threads on a tapered 24 surface of the wedge rings. Thus, the body may be rotated to draw the wedge rings 25 together. As they draw together, teeth on the inner surface of the wedge rings bite into 26 the liner, securing the centralizer in place.
27 Providing a centralizer with some freedom of movement, however, can make it 28 much easier to run a liner into a well. Thus, other centralizers, including bow-spring and 29 spiral-blade type centralizers, are mounted such that they are free to rotate and travel a 30 certain distance along a liner. Sliding centralizers are widely available on the market, 31 including slip-on bow-spring and spiral-blade centralizers distributed by Top-Co, ZI3C1\1:010-CA
Houston, Texas, and MSIS-B bow spring centralizers available from Weatherford.
2 Movement of the centralizer along a liner will be limited by what are referred to as thrust 3 or stop collars. A stop collar will be placed above and below the centralizer as a joint of 4 liner is run into the well. The stop collars are securely mounted to the liner to provide mechanical stops limiting travel of the centralizer along the liner.
6 Stop collars may simply comprise a collar which is slid on a liner and secured in 7 place with set screws. Other designs utilize a hinged collar or a split collar. The collar is 8 opened to place it around a liner. The ends then are brought together and latched or 9 otherwise secured. Such designs may have metal gripping features which bite into the io liner, or they may have an elastomeric layer concentrically disposed within the collar.
ii Some designs incorporate both metal gripping features and elastomers, such as the stop 12 collars disclosed in U.S. Pat. 3,652,138 to C. Collett. Other designs rely on a layer of 13 swellable elastomer disposed on the inside surface of the collar, such as those disclosed 14 in U.S. Pat. 7,942,199 to P. Angman. The collar is dipped into an activating solution and then slipped onto the liner. The elastomer swells and grips the liner.
16 The statements in this section are intended to provide background information 17 related to the invention disclosed and claimed herein. Such information may or may not 18 constitute prior art. It will be appreciated from the foregoing, however, that there 19 remains a need for new and improved systems and apparatus for mounting stop collars and other tool assemblies in a fixed position on liners and other tubular members. Such 21 disadvantages and others inherent in the prior art are addressed by various aspects and 22 embodiments of the subject invention.

24 The subject invention, in its various aspects and embodiments, relates generally to assemblies and stop collars that may be mounted in a fixed position on tubular members, 26 such as liners, that are used in oil and gas wells. It encompasses various embodiments 27 and aspects, some of which are specifically described and illustrated herein.
28 One broad embodiment of the subject invention provides a collar for mounting on 29 a tubular member. The collar comprises a first member and a second member. The two members are adapted for lateral displacement relative to each other and provide opposing 31 inner thrust surfaces. The collar also comprises a radially expandable gripping member which is disposed between the opposing thrust surfaces. The members may be drawn laterally 2 together to cause the thrust surfaces to bear on the gripping member. As the thrust surfaces 3 bear on the gripping member that will expand it radially inward into frictional engagement 4 with the tubular member.
Other broad embodiments and aspects are directed to a collar that is mountable on a 6 tubular member. The collar comprises a first sleeve and a second sleeve.
The two sleeves are 7 adapted to extend around the outer circumference of the tubular member.
The sleeves are engaged with each other by threaded connections and provide opposing inner thrust surfaces.
9 The collar also comprises a radially expandable gripping member which is disposed between io the opposing thrust surfaces. The sleeves may be drawn together by rotating them relative to ii each other about the threaded connection. The relative rotation will cause the thrust surfaces 12 to bear on the gripping member and expand the gripping member radially inward into 13 frictional engagement with the tubular member.
14 In other aspects, the invention provides for such collars where the gripping member is engages the tubular member without penetrating the member, where it engages the tubular 16 member without creating electrolytic contact between the collar and tubular member, or where 17 it engages the tubular member without penetration and without creating electrolytic contact.
18 Other aspects are directed to such collars where the first sleeve is provided with 19 external threads engaging internal threads on the second sleeve and the gripping member is zo disposed between the inner end of the first sleeve and an annular shoulder in the second 21 sleeve. Still other embodiments are directed to such collars where the second sleeve provides 22 radial support for the gripping member. Yet other embodiments provide such collars where 23 the gripping member is carried in an expanded diameter portion of the second sleeve.
24 Additional embodiments and aspects provide such collars where the gripping member 25 is a compressible band, preferably an elastomer band.
26 In still other embodiments, the invention provides such collars having a mechanism to 27 restrict loosening of the threaded engagement between the sleeves. In some embodiments, the 28 mechanism comprises a pawl on one sleeve and detents angularly spaced along the inner end 29 of the other sleeve. The pawl selectively engaging the detents to restrict loosening of the 30 threaded engagement between the sleeves. In other embodiments, the mechanism is a set 31 screw extending through one sleeve and frictionally engaging the other sleeve.

5 = 84396958 The subject invention also is directed to stop collars and other tools for mounting on a 2 tubular. Broad embodiments of the novel tools comprise a novel collar.
Other broad 3 embodiments are directed to a centralizing assembly. The assembly comprises a centralizer 4 tool. The centralizer tool comprises spacing members which extend radially outward beyond the tubular member and define lateral channels. The assembly further comprises a novel stop

6 collar. Still other broad embodiments are directed to tubular assemblies.
The tubular

7 assemblies comprise a novel centralizing assembly or other novel tool.

8 The subject invention also provides novel methods for conducting well operations.

9 Such methods include methods for centralizing liners or other tubulars in a well. The methods io comprise installing a novel centralizing assembly on the tubular and running the tubular into ii the well.
12 The subject invention also is directed to a collar for mounting on a tubular member, 13 said mountable collar comprising: (a) a first sleeve and a second sleeve, said sleeves: i) being 14 adapted to extend around the outer circumference of said tubular member;
ii) being engaged is by threaded connections; and iii) providing opposing inner thrust surfaces; (b) a radially 16 expandable gripping member disposed between said opposing thrust surfaces; (c) wherein said 17 sleeves are capable of being drawn together by rotation about said threaded connection to is cause said thrust surfaces to bear on said gripping member and expand said gripping member 19 radially inward into frictional engagement with said tubular member.
20 The subject invention also is directed to a collar for mounting on a tubular member, 21 said mountable collar comprising: (a) a first member and a second member, said members 22 being: i) adapted for lateral displacement relative to each other; and ii) providing opposing 23 inner thrust surfaces; and (b) a radially expandable gripping member disposed between said 24 opposing thrust surfaces; (c) wherein said members are capable of being drawn laterally 25 together to cause said thrust surfaces to bear on said gripping member and expand said 26 gripping member radially inward into frictional engagement with said tubular member, 27 (d) wherein said gripping member engages said tubular member without penetrating said 28 tubular member.
29 Finally, still other aspects and embodiments of the invention will have various 30 combinations of such features as will be apparent to workers in the art.

1 Thus, the present invention in its various aspects and embodiments comprises a 2 combination of features and characteristics that are directed to overcoming various 3 shortcomings of the prior art. The various features and characteristics described above, as 4 well as other features and characteristics, will be readily apparent to those skilled in the art upon reading the following detailed description of the preferred embodiments and by 6 reference to the appended drawings.
7 Since the description and drawings that follow are directed to particular embodiments, 8 however, they shall not be understood as limiting the scope of the invention. They are 9 included to provide a better understanding of the invention and the way it may be practiced.
o The subject invention encompasses other embodiments consistent with the claims set forth ii herein.
6a BRIEF DESCRIPTION OF THE DRAWINGS

1A is a schematic illustration of a liner assembly 10 being cemented in 3 a bore 4 of a well 1, which liner assembly 10 includes first preferred embodiments 20 of 4 centralizing assemblies of the subject invention.
FIG. 1B is a schematic illustration showing liner assembly 10 after it has been 6 cemented in bore 4.
7 FIG. 2 is an isometric view of a centralizing assembly 20 shown schematically in s FIGS.
1, which centralizing assembly 20 is assembled on a portion of liner 10 and 9 includes a pair of first embodiments 30 of the stop collars of the subject invention.
io FIG. 3 is an isometric view of stop collar 30.
11 FIG. 4 is an exploded, isometric view of stop collar 30 showing a male sleeve 34, 12 a compressible band 33, and a female sleeve 35 from which stop collar 30 is assembled.
13 FIG. 5 is an axial cross-sectional view of stop collar 30 in its set or installed state.
14 In the drawings and description that follows, like parts are identified by the same reference numerals. The drawing figures are not necessarily to scale. Certain features of 16 the embodiments may be shown exaggerated in scale or in somewhat schematic form and 17 some details of conventional design and construction may not be shown in the interest of is clarity and conciseness.

The subject invention relates generally to tool assemblies and stop collars that 21 may be mounted on a liner or other tubular member in a fixed position and encompasses various embodiments and aspects. Some of those embodiments are described is some 23 detail herein. For the sake of conciseness, however, all features of an actual implementation may not be described or illustrated. In developing any actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve a developers' specific goals.
Decisions usually will be made consistent within system-related and business-related constraints, 28 and specific goals may vary from one implementation to another. Development efforts 29 might be complex and time consuming and may involve many aspects of design, fabrication, and manufacture. Nevertheless, it should be appreciated that such ,RFICN:0 1 0-CA
development projects would be a routine effort for those of ordinary skill having the 2 benefit of this disclosure.
3 Overview of Cementing Operations 4 The novel centralizing assemblies may be used, for example, to help improve the quality of a cement sheath that will be formed around a liner. Thus, a first preferred 6 centralizing assembly 20 incorporating a first preferred stop collar 30 will be described 7 by reference to FIGS. 1. FIGS. 1 are schematic depictions of a liner assembly 10 being 8 cemented in an oil and gas well 1. Liner assembly 10 incorporates a number of 9 centralizing assemblies 20.
Referring first to FIG. 1A, well 1 is serviced by a derrick 2 and various surface ii and downhole equipment for pumping cement and circulating fluids (not shown). The 12 upper portion of well 1 is provided with a casing 3, while the lower portion is an open 13 bore 4 extending generally horizontally through a hydrocarbon bearing formation 5.
14 Liner assembly 10 has been suspended from casing 3 by a liner hanger 11 and is extends through open bore 4. Liner assembly 10 includes various tools, including a toe 16 valve 12 and a float assembly 13. Float assembly 13 typically includes various tools that 17 assist in running liner 10 into well 1 and cementing it in bore 4, such as a landing collar 18 14, a float collar 15, and a float shoe 16. Centralizing assemblies 20 are mounted around 19 liner 10 and serve to maintain clearance between liner 10 and bore 4.
FIG. 1A depicts well 1 as liner 10 is being cemented in bore 4. A quantity or 21 "pad" of cement 6 is being pumped into liner 10, out its lower end, and into the annulus 22 between liner 10 and bore 4. As cement 6 is pumped, it displaces drilling fluids 7 already 23 present in liner 10 and the annulus. Cement 6 and fluids 7 are able to flow through the 24 annulus and past centralizing assemblies 20.
A wiper plug 17 is being pumped behind cement 6. It follows the pad of cement 26 as it flows through liner 10. Wiper plug 13 will help clean and remove cement 6 from the 27 inside of liner 10. It will pass through toe valve 12 and eventually seat on landing collar 28 14 in float assembly 13. Pumping will continue until cement 6 completely fills the 29 annulus between liner 10 and bore 4.
FIG. 1B shows well 1 after completion of the cementing operation. Cement 6 has 31 been allowed to set. Centralizing assemblies 20 have enabled cement 6 to form a sheath ,RBCN:010-CA
I completely around liner 10. Derrick 2 and the cementing equipment have been replaced 2 by well head 8 and other surface equipment (not shown). The equipment may be used, 3 for example, to perforate liner 10 and to penetrate cement sheath 6 in selected areas to 4 allow hydrocarbons to flow from formation 5 into liner 10.
The terms "upper" and "lower" and "uphole" and "downhole" as used herein to 6 describe location or orientation are relative to the well and to the tool as run into and 7 installed in the well. Thus, "upper" and "uphole" refers to a location or orientation 8 toward the upper or surface end of the well. "Lower" or "downhole" is relative to the 9 lower end or bottom of the well. It also will be appreciated that the course of the wellbore may not necessarily be as depicted schematically in FIGS. 1.
Depending on the ii location and orientation of the hydrocarbon bearing formation to be accessed, the course 12 of the wellbore may be more or less deviated in any number of directions. "Axial,"
13 "radial," "angularly," and forms thereof reference the central axis of the tools. For 14 example, axial movement or position refers to movement or position generally along or parallel to the central axis. "Lateral" movement and the like also generally refers to up 16 and down movement or positions up and down the tool. "Radial" will refer to positions 17 or movement toward or away from the central axis.
18 Overview of Preferred Centralizing assemblies 19 As noted above, the novel centralizing assemblies may be used to ensure that there is sufficient clearance between a liner and a wellbore so that a continuous sheath of 21 cement may be formed. Broad embodiments incorporate a centralizer and one or more 22 novel stop collars. For example, centralizing assembly 20 is shown in greater detail in 23 FIG. 2. As illustrated therein, centralizing assembly 20 comprises a centralizer 21 which 24 is mounted between a pair of first preferred embodiments 30 of the stop collars of the subject invention.
26 Centralizer 21 is a spiral-blade type centralizer. It has a generally cylindrical 27 body 22 that may be mounted on a portion of liner 10, for example, by sliding it over a 28 joint of liner 10 as it is made up and run into well 1. The outer surface of body 22 is 29 provided with raised features to space liner 10 from bore 4, such as four rounded, rather blunt blades 23. Blades 23 extend laterally between the two ends of body 22, generally 31 along the line of a loose helix. The height of blades 23 is greatest in their mid-region and ,RBCN:010-CA
tapers toward both ends of body 22. Blades 23 serve to maintain clearance between liner 2 10 and bore 4 while at the same time allowing cement 6 to flow laterally past and around 3 body 22.
4 Centralizer 21 is not fixedly carried on liner 10. It is free to rotate about liner 10 and to move laterally along liner 10. A first stop collar 30a is mounted above centralizer 6 21, and a second stop collar 30b is mounted below centralizer 21. Stop collars 30 are 7 fixedly mounted to liner 10. Lateral movement of centralizer 21 along liner 10, therefore, 8 is limited by stop collars 30. Allowing such freedom of movement helps minimize the 9 risk that centralizer 21 will hang up in casing 3 or wellbore 4 as liner

10 is run into well io 1. It will be appreciated that for some applications only a single stop collar 30 may be ii required to restrict lateral movement of centralizer 21. For example, centralizer 21 may 12 be mounted on liner 10 between a single stop collar 30 and a threaded box or other 13 enlarged portion of a liner joint.
14 It will be appreciated that the novel centralizing assemblies may incorporate any conventional centralizer requiring the use of stop collars. Such centralizers include not 16 only spiral blade centralizers, such as centralizer 21, but also slip-on bow spring 17 centralizers. Many different centralizers are available from Top-Co, Weatherford, and is other manufacturers and suppliers.
19 Overview of First Preferred Stop Collar As noted above, the novel stop collars may be mounted on a liner or other tubular 21 member and used, for example, to limit the lateral movement of a tool such as a 22 centralizer. Broad embodiments of the novel stop collars comprise first and second 23 members which may be displaced laterally relative to each other. A
radially expandable 24 gripping member is disposed between opposing thrust surfaces on the displaceable members. The members may be drawn together to expand the gripping member radially 26 inward into frictional engagement with a liner.
27 Stop collar 30, for example, is incorporated into centralizing assembly 20 to limit 28 the lateral movement of centralizer 21. Stop collar 30 is shown in greater detail in FIGS.
29 3-5. As shown therein, stop collar 30 generally comprises a male sleeve 34, a compressible band 33, and a female sleeve 35. Compressible band 33 is carried within 31 stop collar 30 between male sleeve 34 and female sleeve 35. Stop collar 30 may be slid over liner 10 (not shown in FIGS. 3-5). Male sleeve 34 and female sleeve 35 may be 2 threaded together to compress band 33 and expand it radially inward into frictional 3 engagement with liner 10.
4 More specifically, male sleeve 34 has a generally cylindrical body 41. The inner diameter of body 41 is substantially uniform and is slightly larger than the outer diameter of 6 liner 10. Male sleeve 34 will fit closely, but still loose enough that it can slide easily along 7 liner 10. The outer end 42 of male body 41 has a radial thickness and provides an annular 8 surface normal to the circumference of liner 10. As will be appreciated from FIG. 2, stop 9 collar 30 preferably will be mounted on liner 10 such that outer end 42 of male body 41 io provides a stop surface limiting travel of centralizer 21 along liner 10. The inner end of body ii 41 has a reduced outer diameter and terminates in an annular thrust surface 43 extending 12 radially and normal to the outer circumference of liner 10. A
substantial portion of the 13 reduced diameter portion of the inner end of body 41 is provided with external threads 44.
14 Female sleeve 35 also has a generally cylindrical body 51. The inner diameter of body is 51 is sized to allow female sleeve 35, like male sleeve 34, to slide easily along liner 10. The 16 outer end 52 of female body 51 preferably is chamfered to provide stop collar 30 with a 17 tapered leading edge to reduce the risk of centralizing assembly 20 hanging up as liner 10 is 18 run into or out of well 1. The inner end of body 51 has an area of increased inner diameter 19 forming an internal, inward-facing annular shoulder or thrust surface 53. The inner end of 20 body 51 is provided with internal threads 54.
21 Compressible band 33 is an annular body which, in its uncompressed, as-assembled 22 state, is sized to fit loosely around liner 10. Band 33 is carried radially within the enlarged 23 inner diameter portion of body 51 of female sleeve 35. It is disposed axially between thrust 24 surface 43 in male sleeve 34 and thrust surface 53 in female sleeve 35.
Male sleeve 34 is 25 assembled to female sleeve 35 by the engagement of their respective threads 44 and 54. Thus, 26 when male sleeve 34 and female sleeve 35 are relatively loosely engaged and compressible 27 band 33 is relatively uncompressed, stop collar 30 may be slid over liner 10 for installation.
28 Once it is slid around liner 10, stop collar 30 may be fixedly mounted to liner 10 by 29 rotating the threaded connection to draw male sleeve 34 and female sleeve 35

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I together. As male sleeve 34 and female sleeve 35 are drawn together, they will begin to 2 compress compressible band 33. Band 33 is radially supported along its width by the 3 enlarged diameter portion of female sleeve 35. Thus, as compressible band 33 is 4 compressed between thrust surfaces 43 and 53, it will tend to expand radially inward and into engagement with liner 10, gripping it and fixedly securing stop collar 30 on liner 10.
6 The gripping member preferably will establish non-corrosive contact between the 7 stop collar and liner. The contact may be non-corrosive in the sense that it is non-8 penetrating. That is, the gripping member does not significantly abrade or score the liner.
9 It may be non-corrosive in the sense that it does not create electrolytic contact between lo the stop collar and liner. That is, the gripping member will not create significant ii electrolysis between the stop collar and liner. Preferably, the contact will be both non-

12 penetrating and non-electrolytic.

13 Compressible band 33, for example, may be made from any material capable of

14 radially expanding into a state of elastic compression. Preferably, however, band 33 is fabricated from elastomers, such as nitrile butadiene rubber (NBR), hydrogenated nitrile 16 butadiene nitrile rubber (HNBR), and fluoroelastomers such as Vitont, or 17 polytetrafluoroethylene. Such materials may allow stop collar 30 to be securely mounted 18 without damaging the surface of liner 10 and potentially shortening its service life.
19 That is, it will be appreciated that conventional collars may employ set screws, or they may have metal teeth or other gripping features that bite into liner 10.
Liner 10 21 typically will be made of very hard, durable steel, but nevertheless, it will be exposed to 22 harsh fluids, potentially from within and without, and potentially over a long service life.
23 Abrasion and scoring of the metal may make liner 10 more susceptible to corrosion and, 24 if there is contact between dissimilar metals, to electrolytic corrosion. When compressible band 33 is fabricated from elastomers, such issues may be avoided. Other 26 materials, however, may be used to establish non-penetrating or non-electrolytic contact 27 between the stop collar and liner.
28 In some applications, it may be acceptable to use soft, ductile metals such as brass 29 and aluminum alloys to fabricate gripping members. Such materials generally are not preferred. While they typically will be non-penetrating and may not significantly score 31 or otherwise damage a liner during installation, they still create issues of electrolytic ,RBCM010-CA
1 corrosion. Thus, as a general matter, gripping members, like an elastomer band, which 2 establish non-electrolytic contact between the liner and the stop collar as well as non-3 penetrating contact are preferred.
4 An elastomeric band 33 also may provide stop collar 30 with a "self-energizing"
grip on liner 10. That is, as centralizer 21 bears on bottom end 42 of male sleeve 34 it 6 will tend to urge stop collar 30 to travel along liner 10. Male sleeve 34 and female sleeve 7 35 fit loosely around liner 10. They may be displaced fairly easily, especially if 8 significant torque is not created through stop collar 30. Elastomeric band 33, however, is 9 frictionally engaged with liner 10 and will resist displacement. Thrust surface 54 on o female sleeve 35, therefore, may pull away from band 33. Thrust surface 44, however, ii will bear on band 33, compressing it, further expanding it radially inward, and increasing 12 its coefficient of friction. The load on stop collar 30, of course, may become so high that 13 it will force elastomer band 33 to skip or extrude. Until it reaches that point, however, 14 the grip on liner 10 will increase with load. Such dynamics also can provide a shock is absorbing effect, and help minimize the risk of damage to centralizer 21 and stop collar 16 30 as liner 10 travels through the well.
17 A band, such as band 33, also may be preferred as it provides a relatively large 18 area of contact around liner 10 and correspondingly more frictional resistance to 19 movement. Band 33 also may be provided with various features, such as raised nubs, 20 ridges, or other embossments to facilitate a frictional engagement between band 33 and 21 liner 10. The gripping member, however, may have various other configurations. For 22 example, a plurality of discrete gripping members also may be provided and arrayed 23 angularly about the inner circumference of the stop collars.
24 Similarly, the threaded connection between male sleeve 34 and female sleeve 35 25 provide a simple, effective mechanism for drawing their thrust surfaces 43 and 53 26 together to compress and radially expand band 33 radially inward. Other mechanisms, 27 however, may be used. For example, the stop collars may incorporate a pair of terminal 28 or end sleeves, each having a threaded end. The threads on the end sleeves may spiral in 29 opposite directions ¨ the threads on one sleeve being right-handed, and the threads on the 30 other being left-handed. A central or connection sleeve may be provided with opposing 31 internal threads on each end. The connection sleeve may be used to connect and draw the two end sleeves together. Other conventional means of drawing opposing thrust surfaces 2 together may be used.
3 It also will be appreciated that the novel collars may be provided with other 4 features that may make installation easier or enhance their reliability.
For example, holes 45 and 55 may be provided, respectively, on male sleeve 34 and female sleeve 35. Pins 6 on a spanner tool may be inserted into holes 45 and 55 to rotate sleeves 34 and 35 during 7 installation or to remove them from liner 10. The novel stop collars also preferably will have a mechanism to ensure that once they are installed on liner 10, the threaded 9 connection between male sleeve 34 and female sleeve 35 will not loosen to the point where stop collar 30 will slide along liner 10.
11 For example, as best seen in FIGS. 3-4, female sleeve 35 is provided with a series 12 of notches or detents 56 arrayed angularly around its inner end. Male sleeve 34 is 13 provided with one or more pivoting pawls 46 mounted in its mid-region.
Pawl 46 is 14 spring-load to bias it into detents 56. Detents 56 are shaped such that, when male sleeve 34 and female sleeve 35 are rotated to draw them together, pawl 46 will pivot into and 16 then ramp out of detents 56. Instead of a ramp, the other face of detents 56 is designed to 17 fit and catch pawl 46. Thus, once male sleeve 34 and female sleeve 35 have been drawn 18 together fully to mount stop collar 30 on liner 10, pawl 46 will catch in a detent 56 and 19 prevent significant separation of male sleeve 34 and female sleeve 35 or relaxation of band 33.
21 It will be appreciated, of course, that suitable pawl-detent mechanisms may have 22 other designs and effectively prevent loosening of stop collar 30.
Likewise, other 23 mechanisms for preventing relative rotation between male sleeve 34 and female sleeve 35 24 once they have been drawn together may be used. For example, a set screw may be threaded through female sleeve 35 and driven into frictional engagement with male 26 sleeve 34. Other designs are known in the art and may be used.
27 In general, the novel stop collars may be fabricated from materials typically used 28 in stop collars of this type. Given the extreme stress and the corrosive and abrasive fluids 29 to which they may be exposed, suitable materials will be hard and strong. For example, excepting their gripping member as discussed above, the components of novel stop 31 collars may be fabricated from 4130 and 4140 chromoly steel or from somewhat harder, ,RBCM 010-CA
stronger steel such as 4130M7, high end nickel alloys, and stainless steel.
The 2 components may be made by any number of conventional techniques, but typically and in 3 large part will be made by forging, extruding, or mold casting a blank part and then 4 machining the required features into the part.
The novel stop collars have been described as being mounted on a liner and, more 6 specifically, a production liner. A "liner," however, can have a fairly specific meaning 7 within the industry, as do "casing" and "tubing." In its narrow sense, a "casing" is 8 generally considered to be a relatively large tubular conduit, usually greater than 4.5" in 9 diameter, that extends into a well from the surface. A "liner" is generally considered to ni be a relatively large tubular conduit that does not extend from the surface of the well, and ii instead is supported within an existing casing or another liner. In essence, it is a "casing"
12 that does not extend from the surface. "Tubing" refers to a smaller tubular conduit, 13 usually less than 4.5" in diameter. The novel stop collars, however, are not limited in 14 their application to liners as that term may be understood in its narrow sense. They may be used to advantage in liners, casings, tubing, and other tubular conduits or "tubulars" as 16 are commonly employed in oil and gas wells.
17 The novel stop collars also have been described in the context of centralizing is assemblies used in cementing operations. They may be used in centralizing assemblies 19 for other applications, such as "casing-while-drilling" operations where a bit is attached at the end of a liner to drill a bore and install a liner at the same time.
They may be used 21 to limit the travel of centralizers, but they also may be incorporated into centralizers 22 which are fixedly mounted on a liner. For example, a pair of novel stop collars may be 23 joined by bow springs to provide a centralizer that may be mounted securely in a 24 particular location along a liner. A more elongated sleeve may be provided with spiral blades, and each end configured generally as is the inner end of female sleeve 35. A
26 male sleeve 34 then may be assembled to each end of the spiral-blade sleeve to mount it 27 in a fixed location on a liner.
28 Moreover, while they are particularly useful in centralizing assemblies, the novel 29 stop collars have other applications. They may be used in or with other tools, such as cement baskets and scrapers. They also may be used as guides or protectors for sucker RBCK:010-CA
1 rods and tubing. In general, they may be adapted and employed for many different 2 applications calling for a fixedly mounted collar around a tubular member.
3 While this invention has been disclosed and discussed primarily in terms of 4 specific embodiments thereof, it is not intended to be limited thereto.
Other modifications and embodiments will be apparent to the worker in the art.

Claims (20)

CLAIMS:

1. A collar for mounting on a tubular member, said mountable collar comprising:
(a) a first sleeve and a second sleeve, said sleeves:
i) being adapted to extend around the outer circumference of said tubular member;
ii) being engaged by threaded connections; and iii) providing opposing inner thrust surfaces;
(b) a radially expandable gripping member disposed between said opposing thrust surfaces;
(c) wherein said sleeves are capable of being drawn together by rotation about said threaded connection to cause said thrust surfaces to bear on said gripping member and expand said gripping member radially inward into frictional engagement with said tubular member.

2. The collar of claim 1, wherein said gripping member engages said tubular member without penetrating said member.

3. The collar of claim 1 or 2, wherein said gripping member engages said tubular member without creating electrolytic contact between said collar and said tubular member.

4. The collar of any one of claims 1 to 3, wherein said first sleeve is provided with external threads engaging internal threads on said second sleeve and said gripping member is disposed between the inner end of said first sleeve and an annular shoulder in said second sleeve.

5. The collar of any one of claims 1 to 4, wherein said second sleeve provides radial support for said gripping member.

6. The collar of any one of claims 1 to 5, wherein said gripping member is carried in an expanded inner diameter portion of said second sleeve.

7. The collar of any one of claims 1 to 6, wherein said gripping member is a compressible band.

8. The collar of any one of claims 1 to 7, wherein said compressible band is fabricated from an elastomer.

9. The collar of any one of claims 1 to 8, wherein said collar comprises means for restricting loosening of said threaded engagement between said sleeves.

10. The collar of claim 9, wherein said first sleeve comprises a pawl and said second sleeve comprises detents angularly spaced along the inner end of said second sleeve, said pawl selectively engaging said detents to restrict loosening of said threaded engagement between said sleeves.

11. The collar of claim 9, wherein a set screw is provided to restrict loosening of said threaded engagement between said sleeves.

12. A collar for mounting on a tubular member, said mountable collar comprising:
(a) a first member and a second member, said members being:
i) adapted for lateral displacement relative to each other; and ii) providing opposing inner thrust surfaces; and (b) a radially expandable gripping member disposed between said opposing thrust surfaces;
(c) wherein said members are capable of being drawn laterally together to cause said thrust surfaces to bear on said gripping member and expand said gripping member radially inward into frictional engagement with said tubular member, (d) wherein said gripping member engages said tubular member without penetrating said tubular member.

13. The collar of claim 11 or 12, wherein said gripping member engages said tubular member without creating electrolytic contact between said collar and said tubular member.

14. The collar of any one of claims 11, 12, and 13, wherein one of said first or second members provides radial support for said gripping member.

15. The collar of any one of claims 11-12 and 13-14, wherein said gripping member is a compressible band.

16. The collar of any one of claims 11-12 and 13-15, wherein said compressible band is fabricated from an elastomer.

17. A tool for mounting on a tubular; said tool comprising a collar of any one of claims 1-12 and 13-16.

18. The tool of claim 17, wherein said tool is a stop collar.

19. A centralizing assembly for a tubular member, said assembly comprising:
(a) a centralizer tool comprising spacing members, said spacing members extending radially outward beyond said tubular member and defining lateral channels; and (b) a stop collar of claim 18.

20. A tubular assembly, said tubular assembly comprising a tubular and a centralizer assembly of claim 19.