CA2752398C - Friction bite with swellable elastomer elements - Google Patents
Friction bite with swellable elastomer elements Download PDFInfo
- Publication number
- CA2752398C CA2752398C CA2752398A CA2752398A CA2752398C CA 2752398 C CA2752398 C CA 2752398C CA 2752398 A CA2752398 A CA 2752398A CA 2752398 A CA2752398 A CA 2752398A CA 2752398 C CA2752398 C CA 2752398C
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- Prior art keywords
- swellable element
- friction
- swellable
- area
- downhole apparatus
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Links
- 229920001971 elastomer Polymers 0.000 title abstract description 19
- 239000000806 elastomer Substances 0.000 title abstract description 17
- 239000000463 material Substances 0.000 claims abstract description 32
- 239000002245 particle Substances 0.000 claims abstract description 27
- 238000001125 extrusion Methods 0.000 claims abstract description 16
- 239000012530 fluid Substances 0.000 claims description 19
- 238000000034 method Methods 0.000 claims description 10
- 239000013536 elastomeric material Substances 0.000 claims description 5
- 229910001220 stainless steel Inorganic materials 0.000 claims description 3
- 230000008961 swelling Effects 0.000 claims description 3
- 239000000126 substance Substances 0.000 claims 2
- 239000007864 aqueous solution Substances 0.000 claims 1
- 230000001965 increasing effect Effects 0.000 description 9
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 230000004888 barrier function Effects 0.000 description 3
- 238000012856 packing Methods 0.000 description 3
- 229920002943 EPDM rubber Polymers 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000012267 brine Substances 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- JOYRKODLDBILNP-UHFFFAOYSA-N Ethyl urethane Chemical compound CCOC(N)=O JOYRKODLDBILNP-UHFFFAOYSA-N 0.000 description 1
- 244000043261 Hevea brasiliensis Species 0.000 description 1
- 150000001408 amides Chemical class 0.000 description 1
- 238000004873 anchoring Methods 0.000 description 1
- 230000000712 assembly Effects 0.000 description 1
- 238000000429 assembly Methods 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- HQQADJVZYDDRJT-UHFFFAOYSA-N ethene;prop-1-ene Chemical group C=C.CC=C HQQADJVZYDDRJT-UHFFFAOYSA-N 0.000 description 1
- 238000003780 insertion Methods 0.000 description 1
- 230000037431 insertion Effects 0.000 description 1
- 238000002955 isolation Methods 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 229920003052 natural elastomer Polymers 0.000 description 1
- 229920001194 natural rubber Polymers 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 229920002554 vinyl polymer Polymers 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/1208—Packers; Plugs characterised by the construction of the sealing or packing means
- E21B33/1216—Anti-extrusion means, e.g. means to prevent cold flow of rubber packing
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Extrusion Moulding Of Plastics Or The Like (AREA)
- Vibration Prevention Devices (AREA)
- Manufacture Of Macromolecular Shaped Articles (AREA)
Abstract
A friction-enhancing material is applied to an outer surface of a swellable element of a downhole tool. The friction-enhancing material helps prevent axial extrusion of the elastomer of the swellable element. The friction-enhancing material may include particles, a mesh, and wickers, among other kinds of friction-enhancing material, and may be disposed on or embedded in all or a portion of an outer surface of the swellable element.
Description
2 TECHNICAL FIELD
3 The present invention relates to the field of downhole tools, and in particular
4 to swellable packers.
BACKGROUND ART
6 In the field of hydrocarbon exploration and production, various tools are used 7 to provide fluid seals between two components in a wellbore. Annular barriers have been 8 designed for preventing undesirable flow of wellbore fluids in the annulus between a 9 wellbore tubular and the inner surface of a surrounding tubular or the borehole wall. In many cases, the annular barriers provide a fluid seal capable of holding a significant 11 pressure differential across its length. In one application, a wellbore packer is formed on the 12 outer surface of a completion string that is run into an outer casing in a first condition having 13 a particular outer diameter. When the packer is in its desired downhole location, it is inflated 14 or expanded into contact with the inner surface of the outer casing to create a seal in the annulus. Similar wellbore packers have been designed for use in openhole environments, to 16 create a seal between a tubular and the surrounding wall of the wellbore.
17 Conventional packers are actuated by mechanical or hydraulic systems. A
18 force or pressure is applied from the wellhead to move a mechanical packer element radially 19 into contact with the surrounding surface. In an inflatable packer, fluid is delivered from the wellhead to inflate a chamber defined by a bladder around the tubular body.
1 More recently, wellbore packers have been developed which include a mantle 2 of swellable material formed around the tubular. The swellable material is selected to 3 increase in volume on exposure to at least one predetermined fluid, which may be a 4 hydrocarbon fluid or an aqueous fluid or brine. The swellable packer may be run to a downhole location in its unexpanded state, where it is exposed to a wellbore fluid and 6 caused to increase in volume. The design, dimensions, and swelling characteristics are 7 selected such that the swellable packer element expands to create a fluid seal in the annulus 8 to isolate one wellbore section from another. Swellable packers have several advantages 9 over conventional packers, including passive actuation, simplicity of construction, and robustness in long-term isolation applications.
11 In addition, swellable packers may be designed for compliant expansion of 12 the swellable mantle into contact with a surrounding surface, such that the force imparted on 13 the surface prevents damage to a rock formation or sandface, while still creating an annular 14 barrier or seal. Swellable packers therefore lend themselves well to openhole completions in loose or weak formations.
16 The materials selected to form a swellable element in a swellable packer vary 17 depending on the specific application. Swellable materials are elastomeric (i.e. they display 18 mechanical and physical properties of an elastomer or natural rubber).
Where the swellable 19 mantle is designed to swell in hydrocarbons, it may comprise a material such as an ethylene propylene diene monomer (EPDM) rubber. Where the swellable mantle is required to swell 21 in aqueous fluids or brines, the material for example may comprise an N-vinyl carboxylic 22 acid amide-based cross-linked resin and a water swellable urethane in an ethylene propylene 1 rubber matrix. In addition, swellable elastomeric materials may be designed to increase in 2 volume in both hydrocarbon fluids and aqueous fluids.
3 One failure mode of packing elements that seal in an annular space is 4 extrusion. Mechanical backups have been used to bridge off the extrusion gap and help retain the swellable packing element, but these are not always practical or possible.
7 In one embodiment, a downhole apparatus is disclosed. The downhole tool 8 comprises a swellable element. The swellable element comprises a swellable elastomeric 9 material selected to increase in volume on exposure to at least one predetermined fluid; and a first area, disposed with the swellable element and operable to increase friction between 11 the swellable element and a surrounding surface upon swelling of the swellable element.
12 In another embodiment, a swellable element for a downhole tool is disclosed.
13 The swellable element comprises a swellable elastomeric material selected to increase in 14 volume on exposure to at least one predetermined fluid; and a friction-enhancing material, disposed on a first annular area of an outer surface of the swellable elastomeric material.
16 In yet another embodiment, a method of reducing axial extrusion of a 17 swellable element of a downhole tool is disclosed. The method comprises disposing a 18 friction-enhancing material on a portion of an outer surface of the swellable element.
2 The accompanying drawings, which are incorporated in and constitute a part 3 of this specification, illustrate an implementation of apparatus and methods consistent with 4 the present invention and, together with the detailed description, serve to explain advantages and principles consistent with the invention. In the drawings, 6 Figure 1 is a cutaway view of a downhole tool according to one embodiment.
7 Figure 2 is a cutaway view of a downhole tool according to another 8 embodiment.
9 Figure 3 is a cutaway view of a downhole tool according to yet another embodiment.
DESCRIPTION OF EMBODIMENTS
11 In the following description, for purposes of explanation, numerous specific 12 details are set forth in order to provide a thorough understanding of the invention. It will be 13 apparent, however, to one skilled in the art that the invention may be practiced without these 14 specific details. In other instances, structure and devices are shown in block diagram form in order to avoid obscuring the invention. References to numbers without subscripts or suffixes 16 are understood to reference all instance of subscripts and suffixes corresponding to the 17 referenced number. Moreover, the language used in this disclosure has been principally 18 selected for readability and instructional purposes, and may not have been selected to 19 delineate or circumscribe the inventive subject matter, resort to the claims being necessary to determine such inventive subject matter. Reference in the specification to "one embodiment"
21 or to "an embodiment" means that a particular feature, structure, or characteristic described 1 in connection with the embodiments is included in at least one embodiment of the invention, 2 and multiple references to "one embodiment" or "an embodiment" should not be understood 3 as necessarily all referring to the same embodiment.
4 FIG. 1 is a cutaway view of a portion of a swellable packer 100 according to one embodiment. Some common features of the swellable packer known to the art are 6 omitted for clarity of the drawing. The swellable packer 100 comprises a central body 110, 7 such as a tubular or mandrel, about which is disposed a swellable elastomer mantle 120. The 8 swellable mantle 120 may be formed of one or more sections as desired, using any known 9 technique for forming a swellable mantle about a central body. In one embodiment, the swellable mantle 120 may be bonded or otherwise attached to the body 110. The swellable 11 mantle 120 is formed of an elastomer designed to swell when exposed to an aqueous 12 solution, such as water or brine, or a hydrocarbon fluid.
13 Upon insertion into the well, the elastomer of the mantle 120 swells upon 14 exposure to the fluid surrounding the packer 100 in the wellbore. As the elastomer of the mantle 120 swells, it expands radially outwardly, engaging a surrounding casing or open 16 hole wellbore (not shown in FIG. 1) sealing the packer 100 in an annular space around the 17 packer 100, typically to the casing or wellbore. The elastomer of the mantle 120 may also 18 swell axially, and if not prevented from doing so, may extrude axially around the other 19 elements disposed at the ends of the mantle 120, reducing the pressure that is exerted by the expanded mantle 120 on the surrounding casing or wellbore.
21 To prevent this extrusion, mechanical backup units 130 may be provided.
22 Axial expansion of the mantle 120 is limited by the backup units 130, which typically 23 expand under axial pressure, reducing extrusion around the expanded backup units.
BACKGROUND ART
6 In the field of hydrocarbon exploration and production, various tools are used 7 to provide fluid seals between two components in a wellbore. Annular barriers have been 8 designed for preventing undesirable flow of wellbore fluids in the annulus between a 9 wellbore tubular and the inner surface of a surrounding tubular or the borehole wall. In many cases, the annular barriers provide a fluid seal capable of holding a significant 11 pressure differential across its length. In one application, a wellbore packer is formed on the 12 outer surface of a completion string that is run into an outer casing in a first condition having 13 a particular outer diameter. When the packer is in its desired downhole location, it is inflated 14 or expanded into contact with the inner surface of the outer casing to create a seal in the annulus. Similar wellbore packers have been designed for use in openhole environments, to 16 create a seal between a tubular and the surrounding wall of the wellbore.
17 Conventional packers are actuated by mechanical or hydraulic systems. A
18 force or pressure is applied from the wellhead to move a mechanical packer element radially 19 into contact with the surrounding surface. In an inflatable packer, fluid is delivered from the wellhead to inflate a chamber defined by a bladder around the tubular body.
1 More recently, wellbore packers have been developed which include a mantle 2 of swellable material formed around the tubular. The swellable material is selected to 3 increase in volume on exposure to at least one predetermined fluid, which may be a 4 hydrocarbon fluid or an aqueous fluid or brine. The swellable packer may be run to a downhole location in its unexpanded state, where it is exposed to a wellbore fluid and 6 caused to increase in volume. The design, dimensions, and swelling characteristics are 7 selected such that the swellable packer element expands to create a fluid seal in the annulus 8 to isolate one wellbore section from another. Swellable packers have several advantages 9 over conventional packers, including passive actuation, simplicity of construction, and robustness in long-term isolation applications.
11 In addition, swellable packers may be designed for compliant expansion of 12 the swellable mantle into contact with a surrounding surface, such that the force imparted on 13 the surface prevents damage to a rock formation or sandface, while still creating an annular 14 barrier or seal. Swellable packers therefore lend themselves well to openhole completions in loose or weak formations.
16 The materials selected to form a swellable element in a swellable packer vary 17 depending on the specific application. Swellable materials are elastomeric (i.e. they display 18 mechanical and physical properties of an elastomer or natural rubber).
Where the swellable 19 mantle is designed to swell in hydrocarbons, it may comprise a material such as an ethylene propylene diene monomer (EPDM) rubber. Where the swellable mantle is required to swell 21 in aqueous fluids or brines, the material for example may comprise an N-vinyl carboxylic 22 acid amide-based cross-linked resin and a water swellable urethane in an ethylene propylene 1 rubber matrix. In addition, swellable elastomeric materials may be designed to increase in 2 volume in both hydrocarbon fluids and aqueous fluids.
3 One failure mode of packing elements that seal in an annular space is 4 extrusion. Mechanical backups have been used to bridge off the extrusion gap and help retain the swellable packing element, but these are not always practical or possible.
7 In one embodiment, a downhole apparatus is disclosed. The downhole tool 8 comprises a swellable element. The swellable element comprises a swellable elastomeric 9 material selected to increase in volume on exposure to at least one predetermined fluid; and a first area, disposed with the swellable element and operable to increase friction between 11 the swellable element and a surrounding surface upon swelling of the swellable element.
12 In another embodiment, a swellable element for a downhole tool is disclosed.
13 The swellable element comprises a swellable elastomeric material selected to increase in 14 volume on exposure to at least one predetermined fluid; and a friction-enhancing material, disposed on a first annular area of an outer surface of the swellable elastomeric material.
16 In yet another embodiment, a method of reducing axial extrusion of a 17 swellable element of a downhole tool is disclosed. The method comprises disposing a 18 friction-enhancing material on a portion of an outer surface of the swellable element.
2 The accompanying drawings, which are incorporated in and constitute a part 3 of this specification, illustrate an implementation of apparatus and methods consistent with 4 the present invention and, together with the detailed description, serve to explain advantages and principles consistent with the invention. In the drawings, 6 Figure 1 is a cutaway view of a downhole tool according to one embodiment.
7 Figure 2 is a cutaway view of a downhole tool according to another 8 embodiment.
9 Figure 3 is a cutaway view of a downhole tool according to yet another embodiment.
DESCRIPTION OF EMBODIMENTS
11 In the following description, for purposes of explanation, numerous specific 12 details are set forth in order to provide a thorough understanding of the invention. It will be 13 apparent, however, to one skilled in the art that the invention may be practiced without these 14 specific details. In other instances, structure and devices are shown in block diagram form in order to avoid obscuring the invention. References to numbers without subscripts or suffixes 16 are understood to reference all instance of subscripts and suffixes corresponding to the 17 referenced number. Moreover, the language used in this disclosure has been principally 18 selected for readability and instructional purposes, and may not have been selected to 19 delineate or circumscribe the inventive subject matter, resort to the claims being necessary to determine such inventive subject matter. Reference in the specification to "one embodiment"
21 or to "an embodiment" means that a particular feature, structure, or characteristic described 1 in connection with the embodiments is included in at least one embodiment of the invention, 2 and multiple references to "one embodiment" or "an embodiment" should not be understood 3 as necessarily all referring to the same embodiment.
4 FIG. 1 is a cutaway view of a portion of a swellable packer 100 according to one embodiment. Some common features of the swellable packer known to the art are 6 omitted for clarity of the drawing. The swellable packer 100 comprises a central body 110, 7 such as a tubular or mandrel, about which is disposed a swellable elastomer mantle 120. The 8 swellable mantle 120 may be formed of one or more sections as desired, using any known 9 technique for forming a swellable mantle about a central body. In one embodiment, the swellable mantle 120 may be bonded or otherwise attached to the body 110. The swellable 11 mantle 120 is formed of an elastomer designed to swell when exposed to an aqueous 12 solution, such as water or brine, or a hydrocarbon fluid.
13 Upon insertion into the well, the elastomer of the mantle 120 swells upon 14 exposure to the fluid surrounding the packer 100 in the wellbore. As the elastomer of the mantle 120 swells, it expands radially outwardly, engaging a surrounding casing or open 16 hole wellbore (not shown in FIG. 1) sealing the packer 100 in an annular space around the 17 packer 100, typically to the casing or wellbore. The elastomer of the mantle 120 may also 18 swell axially, and if not prevented from doing so, may extrude axially around the other 19 elements disposed at the ends of the mantle 120, reducing the pressure that is exerted by the expanded mantle 120 on the surrounding casing or wellbore.
21 To prevent this extrusion, mechanical backup units 130 may be provided.
22 Axial expansion of the mantle 120 is limited by the backup units 130, which typically 23 expand under axial pressure, reducing extrusion around the expanded backup units.
5 1 Although backup units 130 are disposed at both ends of the swellable mantle 120 as 2 illustrated in FIG 1, in some embodiments, the backup unit 130 may be disposed at only one 3 end of the mantle 120, or a different technique for reducing extrusion may be employed at 4 the end of the mantle 120 axially distal from the backup unit 130. Although mechanical backups 130 have been used to bridge off the extrusion gap and help retain the swellable
6 packing element, these are not always practical or possible. Furthermore, some extrusion
7 may occur around the backup units 130.
8 By increasing the friction factor between the mantle 120 and the bore, the
9 extrusion resistance is increased, and thus the pressure holding capability of the packer 100.
Various embodiments disclosed herein use implanted mechanical components disposed on 11 or embedded into the outer surface of the swellable mantle 120 to increase the friction or 12 gripping capability of the mantle 120. These mechanical components may include particles, 13 slip segments, wire-mesh sheet, etc. that would either bite into the bore, or provide a 14 rougher, stronger surface than the swellable rubber. These mechanical components may increase the tensile holding capability of the element, as well as increasing the pressure 16 holding capability of the packer 100.
17 There are different ways of increasing the friction coefficient of the surface of 18 the mantle 120. In FIG 1, the friction enhancement is achieved by disposing particles 140 19 onto the outer surface of the mantle 120, or embedding the particles 140 into the outer surface. The particles 140 provide an increased friction coefficient for the entire surface of 21 the mantle 120. As illustrated in FIG 1, the particles 140 are randomly distributed across the 22 surface of the mantle 120. In other embodiments, the particles 140 may be randomly 23 distributed across one or more portions of the outer surface of the mantle 120, preferably at 1 least in areas proximal to the ends of the mantle 120, where extrusion of the elastomer 2 around the backup units 130 may occur.
3 In yet other embodiments, the friction-enhancing particles 140 may be 4 patterned across the entire or portions of the outer surface of the mantle 120, using any desired pattern.
6 The friction increasing particles 140 in one embodiment may comprise 7 carbide particles, designed to bite into the surrounding surface of the casing or wellbore.
8 Other friction-enhancing particles 140 may be used that are not hard enough to bite into the 9 surrounding surface, but which add frictional improvement to the mantle 120, such as elastomers or plastic particles that are harder than the elastomer forming the mantle 120.
11 The particles 140 may be of any desired size, and the density of distribution 12 of the particles 140 may be any desired density. The particles 140 may be deposited on or 13 embedded into the elastomer of the mantle 120 before disposition of the mantle 120 on the 14 body 110, or may be added after the mantle 120 is disposed on the downhole tool 100.
In an alternate embodiment, instead of using particles 140 added to the outer 16 surface of the mantle 120, the outer surface of the mantle 120 may be scored or roughened 17 mechanically producing random or patterned scorings or roughened areas to increase the 18 friction coefficient of the surface of the mantle 120.
19 FIG. 2 is a cutaway view of a downhole tool 200 according to one embodiment in which, instead of discrete particles 140, a mesh 240 is disposed about the 21 mantle 120 to provide friction enhancement. The mesh 240 may be formed of wire, such as a 22 stainless steel wire, or any other desired materials. As with the embodiment of FIG 1, the 23 mesh 240 may be formed of the material hard enough to bite into the surrounding surface of 1 the casing or wellbore, but may alternately simply be harder than the elastomer used to form 2 the mantle 120. The mesh 240 may be disposed on the outer surface of the mantle 120 or 3 may be embedded into the surface of the mantle 120.
4 FIG 3 is a cutaway view of a downhole tool 300 according to yet another embodiment. In this embodiment, one or more areas of wickers 340 may be disposed 6 annularly about the outer diameter of the mantle 120 to provide the desired friction 7 enhancement. As illustrated in FIG 3, six areas of wickers 340 are provided, but the number 8 and placement of the wicker areas 340 is illustrative and by way of example only. Any 9 number of wicker areas 340 may be placed in any desired arrangement on the mantle 120.
Preferably, wicker areas 340 are placed proximal to the ends of the mantle 120 where 11 extrusion around backup units 130 may occur.
12 The wickers may be formed of stainless steel or any other material. In one 13 embodiment, the wickers may be formed of a material of sufficient hardness to bite into the 14 surrounding surface. In another embodiment, the wickers do not need to be hard enough to bite into the surrounding surface, but simply are harder than the mantle 120, thus increase 16 frictional drag on the mantle 120.
17 The wickers may have any desired shape configured to increased friction, and 18 do not need to be capable of anchoring the mantle 120 to completely prevent movement of 19 the mantle 120 relative to the surrounding surface.
Although as described above the friction-enhancing material is disposed on 21 the outer surface of the mantle 120, and other embodiments the friction-enhancing elements, 22 whether separate particles, meshes, wickers, or other forms, may be embedded into the 23 elastomer of the mantle 120 below the outer surface. Under pressure from the expanded 1 mantle 120 against the surrounding surface, the subsurface embedded friction-enhancing 2 elements may, instead of directly engaging the surrounding surface to resist movement, 3 pinch the elastomer of the mantle 120between the friction-enhancing elements 140, 240, or 4 340, enhancing friction between the mantle 120 and the surrounding surface.
By increasing friction between the mantle 120 and the surrounding surface, 6 the friction-enhancing elements 140, 240, and 340 reduce axial extrusion of the elastomer of 7 the mantle 120 around the support assemblies or backup rings 130 disposed at the ends of 8 the mantle 120. By reducing extrusion, the pressure on the surrounding surface caused by 9 the expansion of the elastomer radially outwardly may be increased.
It is to be understood that the above description is intended to be illustrative, 11 and not restrictive. For example, the above-described embodiments may be used in 12 combination with each other. Many other embodiments will be apparent to those of skill in 13 the art upon reviewing the above description. The scope of the invention therefore should be 14 determined with reference to the appended claims, along with the full scope of equivalents to which such claims are entitled. In the appended claims, the terms "including" and "in 16 which" are used as the plain-English equivalents of the respective terms "comprising" and 17 "wherein."
Various embodiments disclosed herein use implanted mechanical components disposed on 11 or embedded into the outer surface of the swellable mantle 120 to increase the friction or 12 gripping capability of the mantle 120. These mechanical components may include particles, 13 slip segments, wire-mesh sheet, etc. that would either bite into the bore, or provide a 14 rougher, stronger surface than the swellable rubber. These mechanical components may increase the tensile holding capability of the element, as well as increasing the pressure 16 holding capability of the packer 100.
17 There are different ways of increasing the friction coefficient of the surface of 18 the mantle 120. In FIG 1, the friction enhancement is achieved by disposing particles 140 19 onto the outer surface of the mantle 120, or embedding the particles 140 into the outer surface. The particles 140 provide an increased friction coefficient for the entire surface of 21 the mantle 120. As illustrated in FIG 1, the particles 140 are randomly distributed across the 22 surface of the mantle 120. In other embodiments, the particles 140 may be randomly 23 distributed across one or more portions of the outer surface of the mantle 120, preferably at 1 least in areas proximal to the ends of the mantle 120, where extrusion of the elastomer 2 around the backup units 130 may occur.
3 In yet other embodiments, the friction-enhancing particles 140 may be 4 patterned across the entire or portions of the outer surface of the mantle 120, using any desired pattern.
6 The friction increasing particles 140 in one embodiment may comprise 7 carbide particles, designed to bite into the surrounding surface of the casing or wellbore.
8 Other friction-enhancing particles 140 may be used that are not hard enough to bite into the 9 surrounding surface, but which add frictional improvement to the mantle 120, such as elastomers or plastic particles that are harder than the elastomer forming the mantle 120.
11 The particles 140 may be of any desired size, and the density of distribution 12 of the particles 140 may be any desired density. The particles 140 may be deposited on or 13 embedded into the elastomer of the mantle 120 before disposition of the mantle 120 on the 14 body 110, or may be added after the mantle 120 is disposed on the downhole tool 100.
In an alternate embodiment, instead of using particles 140 added to the outer 16 surface of the mantle 120, the outer surface of the mantle 120 may be scored or roughened 17 mechanically producing random or patterned scorings or roughened areas to increase the 18 friction coefficient of the surface of the mantle 120.
19 FIG. 2 is a cutaway view of a downhole tool 200 according to one embodiment in which, instead of discrete particles 140, a mesh 240 is disposed about the 21 mantle 120 to provide friction enhancement. The mesh 240 may be formed of wire, such as a 22 stainless steel wire, or any other desired materials. As with the embodiment of FIG 1, the 23 mesh 240 may be formed of the material hard enough to bite into the surrounding surface of 1 the casing or wellbore, but may alternately simply be harder than the elastomer used to form 2 the mantle 120. The mesh 240 may be disposed on the outer surface of the mantle 120 or 3 may be embedded into the surface of the mantle 120.
4 FIG 3 is a cutaway view of a downhole tool 300 according to yet another embodiment. In this embodiment, one or more areas of wickers 340 may be disposed 6 annularly about the outer diameter of the mantle 120 to provide the desired friction 7 enhancement. As illustrated in FIG 3, six areas of wickers 340 are provided, but the number 8 and placement of the wicker areas 340 is illustrative and by way of example only. Any 9 number of wicker areas 340 may be placed in any desired arrangement on the mantle 120.
Preferably, wicker areas 340 are placed proximal to the ends of the mantle 120 where 11 extrusion around backup units 130 may occur.
12 The wickers may be formed of stainless steel or any other material. In one 13 embodiment, the wickers may be formed of a material of sufficient hardness to bite into the 14 surrounding surface. In another embodiment, the wickers do not need to be hard enough to bite into the surrounding surface, but simply are harder than the mantle 120, thus increase 16 frictional drag on the mantle 120.
17 The wickers may have any desired shape configured to increased friction, and 18 do not need to be capable of anchoring the mantle 120 to completely prevent movement of 19 the mantle 120 relative to the surrounding surface.
Although as described above the friction-enhancing material is disposed on 21 the outer surface of the mantle 120, and other embodiments the friction-enhancing elements, 22 whether separate particles, meshes, wickers, or other forms, may be embedded into the 23 elastomer of the mantle 120 below the outer surface. Under pressure from the expanded 1 mantle 120 against the surrounding surface, the subsurface embedded friction-enhancing 2 elements may, instead of directly engaging the surrounding surface to resist movement, 3 pinch the elastomer of the mantle 120between the friction-enhancing elements 140, 240, or 4 340, enhancing friction between the mantle 120 and the surrounding surface.
By increasing friction between the mantle 120 and the surrounding surface, 6 the friction-enhancing elements 140, 240, and 340 reduce axial extrusion of the elastomer of 7 the mantle 120 around the support assemblies or backup rings 130 disposed at the ends of 8 the mantle 120. By reducing extrusion, the pressure on the surrounding surface caused by 9 the expansion of the elastomer radially outwardly may be increased.
It is to be understood that the above description is intended to be illustrative, 11 and not restrictive. For example, the above-described embodiments may be used in 12 combination with each other. Many other embodiments will be apparent to those of skill in 13 the art upon reviewing the above description. The scope of the invention therefore should be 14 determined with reference to the appended claims, along with the full scope of equivalents to which such claims are entitled. In the appended claims, the terms "including" and "in 16 which" are used as the plain-English equivalents of the respective terms "comprising" and 17 "wherein."
Claims (26)
1. A downhole apparatus, comprising:
a swellable element comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid; and a first area, disposed with the swellable element and operable to increase friction between the swellable element and a surrounding surface upon swelling of the swellable element.
a swellable element comprising a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid; and a first area, disposed with the swellable element and operable to increase friction between the swellable element and a surrounding surface upon swelling of the swellable element.
2. The downhole apparatus of claim 1, wherein the downhole apparatus is a swellable packer.
3. The downhole apparatus of claim 1 or 2, wherein the first area comprises a plurality of particles disposed on a surface of the first area, the particles selected for friction enhancement.
4. The downhole apparatus of claim 3, wherein the plurality of particles are dispersed randomly on the surface of the first area.
5. The downhole apparatus of claim 3, wherein the plurality of particles are patterned onto the surface of the first area.
6. The downhole apparatus of claim 1 or 2, wherein the first area comprises a mesh disposed about an outer diameter of the first area, the mesh selected for friction enhancement.
7. The downhole apparatus of claim 6, wherein the mesh is composed of stainless steel wire.
8. The downhole apparatus of claim 1 or 2, wherein the first area comprises a plurality of wickers, formed of material selected for friction enhancement.
9. The downhole apparatus of claim 1 or 2, wherein the first area comprises a plurality of wickers, formed of material selected to be harder than the surrounding surface.
10. The downhole apparatus of any one of claims 1 to 9, wherein the first area comprises:
a roughened radially outward surface of a portion of the swellable element.
a roughened radially outward surface of a portion of the swellable element.
11. The downhole apparatus of any one of claims 1 to 9, wherein the first area comprises the entire outer surface of the swellable element.
12. The downhole apparatus of any one of claims 1 to 11, further comprising:
a backup member, configured to resist axial extrusion of the swellable element, disposed at an end of the swellable element.
a backup member, configured to resist axial extrusion of the swellable element, disposed at an end of the swellable element.
13. The downhole apparatus of claim 12, wherein the first area is proximal to the backup member.
14. A swellable element for a downhole tool, comprising:
a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid; and a friction-enhancing material, disposed on a first annular area of an outer surface of the swellable elastomeric material.
a swellable elastomeric material selected to increase in volume on exposure to at least one predetermined fluid; and a friction-enhancing material, disposed on a first annular area of an outer surface of the swellable elastomeric material.
15. The swellable element of claim 14, wherein the friction-enhancing material comprises a plurality of particles disposed on the outer surface of the first annular area.
16. The swellable element of claim 15, wherein the plurality of particles are formed from a material selected to have a hardness sufficient to bite into a surrounding surface when deployed in a casing or wellbore.
17. The swellable element of claim 15, wherein the plurality of particles are randomly dispersed in the first annular area.
18. The swellable element of claim 15, wherein the plurality of particles are patterned on the first annular area.
19. The swellable element of claim 14, wherein the friction-enhancing material comprises a mesh, disposed about an outer diameter of the first annular area.
20. The swellable element of claim 14, wherein the friction-enhancing material comprises a plurality of wickers, disposed about an outer diameter of the first annular area.
21. The swellable element of any one of claims 14 to 20, wherein the predetermined fluid is an aqueous solution.
22. A method of reducing axial extrusion of a swellable element of a downhole tool, comprising:
disposing a friction-enhancing material on a portion of an outer surface of the swellable element.
disposing a friction-enhancing material on a portion of an outer surface of the swellable element.
23. The method of claim 22, wherein the act of disposing a friction-enhancing material comprises:
disposing particles of a substance harder than the swellable element on the portion of the outer surface of the swellable element.
disposing particles of a substance harder than the swellable element on the portion of the outer surface of the swellable element.
24. The method of claim 22, wherein the act of disposing a friction-enhancing material comprises:
disposing a plurality of wickers about the portion of the outer surface of the swellable element.
disposing a plurality of wickers about the portion of the outer surface of the swellable element.
25. The method of claim 22, wherein the act of disposing a friction-enhancing material comprises:
disposing a mesh formed of a substance harder than the swellable element about the portion of the outer surface of the swellable element.
disposing a mesh formed of a substance harder than the swellable element about the portion of the outer surface of the swellable element.
26. The method of claim 22, wherein the act of disposing a friction-enhancing material comprises:
embedding the friction-enhancing material into the portion of the outer surface of the swellable element.
embedding the friction-enhancing material into the portion of the outer surface of the swellable element.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US12/892,084 US20120073834A1 (en) | 2010-09-28 | 2010-09-28 | Friction Bite with Swellable Elastomer Elements |
| US12/892,084 | 2010-09-28 |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2752398A1 CA2752398A1 (en) | 2012-03-28 |
| CA2752398C true CA2752398C (en) | 2013-11-26 |
Family
ID=44905742
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2752398A Expired - Fee Related CA2752398C (en) | 2010-09-28 | 2011-09-15 | Friction bite with swellable elastomer elements |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US20120073834A1 (en) |
| EP (1) | EP2434089A3 (en) |
| AU (1) | AU2011224004A1 (en) |
| CA (1) | CA2752398C (en) |
| RU (1) | RU2011139422A (en) |
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| US9970249B2 (en) | 2014-12-05 | 2018-05-15 | Baker Hughes, A Ge Company, Llc | Degradable anchor device with granular material |
| WO2018147833A1 (en) * | 2017-02-07 | 2018-08-16 | Halliburton Energy Services, Inc. | Packer sealing element with non-swelling layer |
| US11255148B2 (en) | 2017-04-27 | 2022-02-22 | Halliburton Energy Services, Inc. | Expandable elastomeric sealing layer for a rigid sealing device |
| US11174700B2 (en) * | 2017-11-13 | 2021-11-16 | Halliburton Energy Services, Inc. | Swellable metal for non-elastomeric O-rings, seal stacks, and gaskets |
| GB2583661B (en) | 2018-02-23 | 2022-09-14 | Halliburton Energy Services Inc | Swellable metal for swell packer |
| CN110671074B (en) * | 2018-07-02 | 2021-11-26 | 中国石油化工股份有限公司 | Well cementation rubber plug rubber part and reinforcing method thereof |
| CA3119178C (en) | 2019-02-22 | 2023-08-08 | Halliburton Energy Services, Inc. | An expanding metal sealant for use with multilateral completion systems |
| US11261693B2 (en) | 2019-07-16 | 2022-03-01 | Halliburton Energy Services, Inc. | Composite expandable metal elements with reinforcement |
| CA3137939A1 (en) | 2019-07-31 | 2021-02-04 | Halliburton Energy Services, Inc. | Methods to monitor a metallic sealant deployed in a wellbore, methods to monitor fluid displacement, and downhole metallic sealant measurement systems |
| US11035197B2 (en) * | 2019-09-24 | 2021-06-15 | Exacta-Frac Energy Services, Inc. | Anchoring extrusion limiter for non-retrievable packers and composite frac plug incorporating same |
| US11519239B2 (en) | 2019-10-29 | 2022-12-06 | Halliburton Energy Services, Inc. | Running lines through expandable metal sealing elements |
| US11761290B2 (en) | 2019-12-18 | 2023-09-19 | Halliburton Energy Services, Inc. | Reactive metal sealing elements for a liner hanger |
| US11828131B1 (en) * | 2020-03-09 | 2023-11-28 | Workover Solutions, Inc. | Downhole plug with integrated slip cover and expansion element |
| US11761293B2 (en) | 2020-12-14 | 2023-09-19 | Halliburton Energy Services, Inc. | Swellable packer assemblies, downhole packer systems, and methods to seal a wellbore |
| US11572749B2 (en) | 2020-12-16 | 2023-02-07 | Halliburton Energy Services, Inc. | Non-expanding liner hanger |
| US11578498B2 (en) | 2021-04-12 | 2023-02-14 | Halliburton Energy Services, Inc. | Expandable metal for anchoring posts |
| US11879304B2 (en) | 2021-05-17 | 2024-01-23 | Halliburton Energy Services, Inc. | Reactive metal for cement assurance |
| WO2023209442A1 (en) | 2022-04-26 | 2023-11-02 | Downhole Products Limited | Slimline stop collar with seal to prevent micro-annulus leakage |
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- 2010-09-28 US US12/892,084 patent/US20120073834A1/en not_active Abandoned
-
2011
- 2011-09-13 AU AU2011224004A patent/AU2011224004A1/en not_active Abandoned
- 2011-09-15 CA CA2752398A patent/CA2752398C/en not_active Expired - Fee Related
- 2011-09-27 EP EP11250823A patent/EP2434089A3/en not_active Withdrawn
- 2011-09-27 RU RU2011139422/03A patent/RU2011139422A/en unknown
Also Published As
| Publication number | Publication date |
|---|---|
| AU2011224004A1 (en) | 2012-04-12 |
| US20120073834A1 (en) | 2012-03-29 |
| EP2434089A3 (en) | 2013-03-27 |
| CA2752398A1 (en) | 2012-03-28 |
| RU2011139422A (en) | 2013-04-10 |
| EP2434089A2 (en) | 2012-03-28 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| MKLA | Lapsed |
Effective date: 20190916 |